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As filed with the Securities and Exchange Commission on
September 8, 2006
Registration
No. 333-136978
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Amendment No. 1
to
Form S-4
REGISTRATION STATEMENT UNDER THE SECURITIES ACT OF 1933
ALLIS-CHALMERS ENERGY INC.
(Exact name of registrant as specified in its charter)
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Delaware |
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1389 |
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39-0126090 |
(State or other jurisdiction of |
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(Primary Standard Industrial |
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(I.R.S. Employer |
incorporation or organization) |
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Classification Code Number) |
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Identification No.) |
Co-Registrants
(See next page)
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5075 Westheimer, Suite 890
Houston, Texas 77056
(713) 369-0550
(Address, including zip code, and telephone number,
including area code, of registrants principal executive
offices) |
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Victor M. Perez
Chief Financial Officer
5075 Westheimer, Suite 890
Houston, Texas 77056
(713) 369-0550
(Name, address, including zip code, and telephone
number,
including area code, of agent for service) |
Copy to:
Andrews Kurth LLP
600 Travis, Suite 4200
Houston, Texas 77002
(713) 220-4200
Attn: Henry Havre
Christopher
S. Wade
Approximate date of commencement of proposed sale to the
public: As soon as practicable following the effectiveness
of this registration statement.
If the securities being registered on this Form are being
offered in connection with the formation of a holding company
and there is compliance with General Instruction G, check
the following box. o
If this Form is filed to register additional securities for an
offering pursuant to Rule 462(b) under the Securities Act,
please check the following box and list the Securities Act
registration statement number of the earlier effective
registration statement for the same
offering. o
If this Form is a post-effective amendment filed pursuant to
Rule 462(d) under the Securities Act, check the following
box and list the Securities Act registration statement number of
the earlier effective registration statement for the same
offering. o
CALCULATION OF REGISTRATION FEE
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Proposed Maximum |
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Proposed Maximum |
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Title of Each Class of |
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Amount to be |
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Offering Price Per |
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Aggregate Offering |
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Amount of |
Securities to be Registered |
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Registered |
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Unit(1) |
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Price(1) |
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Registration Fee(1) |
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9.0% Senior Notes due 2014
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$255,000,000 |
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100% |
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$255,000,000 |
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$27,285(2) |
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Guarantees of 9.0% Senior Notes due 2014(3)
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Total
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$255,000,000 |
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100% |
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$255,000,000 |
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$27,285(2) |
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(1) |
The registration fee was calculated pursuant to Rule 457(f)
under the Securities Act of 1933. For purposes of this
calculation, the offering price per note was assumed to be the
stated principal amount of each original note that may be
received by the registrant in the exchange transaction in which
the notes will be offered. |
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(2) |
Such amount was previously paid. Of such amount, $4,471 was
previously paid in connection with unsold securities registered
under Registration No. 333-133874 initially filed on
May 8, 2006 by the registrant hereunder (which such amount
was offset against the total filing fee paid for this
registration statement pursuant to Rule 457(p) of the
General Rules and Regulations under the Securities Act of 1933,
as amended). |
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(3) |
No separate consideration will be received for the Guarantees,
and, therefore, no additional registration fee is required. |
The registrant hereby amends this registration statement on
such date or dates as may be necessary to delay its effective
date until the registrant shall file a further amendment which
specifically states that this registration statement shall
thereafter become effective in accordance with Section 8(a)
of the Securities Act of 1933 or until the registration
statement shall become effective on such date as the Securities
and Exchange Commission, acting pursuant to said
Section 8(a), may determine.
Co-Registrants
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State or Other | |
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Primary Standard | |
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I.R.S. | |
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Jurisdiction of | |
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Industrial | |
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Employer | |
Exact Name of Co-Registrant as |
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Incorporation or | |
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Classification | |
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Identification | |
Specified in its Charter |
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Organization | |
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Code Number | |
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Number | |
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AirComp L.L.C.
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Delaware |
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1389 |
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01-0784140 |
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Allis-Chalmers GP, LLC
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Delaware |
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1389 |
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20-4002547 |
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Allis-Chalmers LP, LLC
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Delaware |
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1389 |
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20-4002534 |
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Allis-Chalmers Management, LP
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Texas |
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1389 |
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20-4002561 |
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Allis-Chalmers Production Services, Inc.
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Texas |
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1389 |
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75-2956148 |
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Allis-Chalmers Rental Tools, Inc.
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Texas |
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1389 |
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74-2005637 |
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Allis-Chalmers Tubular Services, Inc.
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Texas |
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1389 |
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74-2212869 |
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Mountain Compressed Air, Inc.
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Texas |
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1389 |
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84-1574665 |
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OilQuip Rentals, Inc.
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Delaware |
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1389 |
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76-0632145 |
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Rogers Oil Tool Services, Inc.
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Louisiana |
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1389 |
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72-0849723 |
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Strata Directional Technology, Inc.
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Texas |
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1389 |
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76-0490913 |
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Target Energy, Inc.
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Delaware |
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1389 |
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52-2259046 |
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The information
in this prospectus is not complete and may be changed. We may
not sell these securities until the registration statement filed
with the Securities and Exchange Commission is effective. This
prospectus is not an offer to sell these securities and it is
not soliciting an offer to buy these securities in any state
where the offer or sale is not permitted.
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SUBJECT TO COMPLETION, DATED
SEPTEMBER 8, 2006
PROSPECTUS
$255,000,000
Allis-Chalmers Energy Inc.
Offer to Exchange
All Outstanding 9.0% Senior Notes due 2014
for
9.0% Senior Notes due 2014
THE EXCHANGE OFFER WILL EXPIRE AT 5:00 P.M.,
NEW YORK CITY TIME,
ON ,
2006, UNLESS EXTENDED
The Notes
We are offering to exchange all of our outstanding
9.0% Senior Notes due 2014, which we refer to as the old
notes, for our new 9.0% Senior Notes due 2014, which we
refer to as the new notes. We refer to the old notes and new
notes collectively as the notes.
Terms of The Exchange Offer:
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The terms of the new notes will be substantially identical to
the old notes, except that the new notes will not be subject to
transfer restrictions or registration rights relating to the old
notes. The new notes will represent the same debt as the old
notes, and will be issued under the same indenture. |
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The old notes are, and the new notes will be, guaranteed on a
senior unsecured basis by all of our current and future domestic
restricted subsidiaries, other than certain immaterial
subsidiaries. The old notes are not, and the new notes will not
be, guaranteed by our current or future foreign subsidiaries. |
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Interest on the new notes will accrue from July 15, 2006 at
the rate of 9.0% per annum, payable on January 15 and
July 15 of each year, beginning on January 15, 2007. |
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We will exchange an equal principal amount of all old notes for
new notes that you validly tender and do not validly withdraw
before the exchange offer expires. We do not currently intend to
extend the exchange offer. |
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You may withdraw tenders of the old notes at any time prior to
the expiration of the exchange offer. |
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The exchange of old notes for new notes will not be a taxable
event for United States federal income tax purposes. |
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We will not receive any proceeds from this exchange offer. |
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There is no existing market for the new notes to be issued, and
we do not intend to apply for their listing on any securities
exchange or arrange for them to be quoted on any quotation
system. |
See the section entitled Description of Notes that
begins on page 102 for more information about the notes.
This investment involves risks. See the section entitled
Risk Factors that begins on page 14 for a
discussion of the risks that you should consider in connection
with your investment in the notes.
Neither the Securities and Exchange Commission nor any state
securities commission has approved or disapproved of these
securities or determined if this prospectus is truthful or
complete. Any representation to the contrary is a criminal
offense.
Each broker-dealer that receives new notes for its own account
pursuant to the exchange offer must acknowledge that it will
deliver a prospectus in connection with any resale of such new
notes. The letter of transmittal states that by so acknowledging
and by delivering a prospectus, a broker-dealer will not be
deemed to admit that it is an underwriter within the
meaning of the Securities Act. This prospectus, as it may be
amended or supplemented from time to time, may be used by a
broker-dealer in connection with resales of new notes received
in exchange for old notes where such old notes were acquired by
such broker-dealer as a result of market-making activities or
other trading activities. See Plan of Distribution.
The date of this prospectus
is ,
2006.
TABLE OF CONTENTS
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iv |
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1 |
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14 |
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162 |
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162 |
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F-1 |
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Consent of UHY Mann Frankfort Stein & Lipp CPAs, LLP |
Consent of Gordon, Hughes and Banks, LLP |
Consent of Wright, Moore, Dehart, Dupuis & Hutchinson, LLC |
Consent of Curtis Blakely & Co., PC |
Consent of Accounting & Consulting Group, LLP |
Consent of UHY Mann Frankfort Stein & Lipp CPAs, LLP |
Consent of Sibille |
ABOUT THIS PROSPECTUS
The information in this prospectus is not complete and may be
changed. You should rely only on the information contained in
this prospectus or any other documents to which we have referred
you. We have not authorized anyone to provide you with
information that is different. If anyone provides you with
different or inconsistent information, you should not rely on
it. We are not making an offer to sell these securities in any
jurisdiction where the offer or sale is not permitted. You
should assume that the information appearing in this prospectus
is accurate only as of the date on the front cover of this
prospectus. Our business, financial condition, results of
operations and prospects may have changed since that date.
This prospectus is part of a registration statement that we have
filed with the Securities and Exchange Commission, or SEC. You
should read this prospectus together with the registration
statement, the exhibits thereto and the additional information
described under the headings Where You Can Find More
Information.
i
SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS
This prospectus contains forward-looking statements within the
meaning of Section 27A of the Securities Act of 1933, as
amended, or the Securities Act, regarding our business,
financial condition, results of operations and prospects. Words
such as expects, anticipates, intends, plans, believes, seeks,
estimates and similar expressions or variations of such words
are intended to identify forward-looking statements. However,
these are not the exclusive means of identifying forward-looking
statements. Although forward-looking statements contained in
this prospectus reflect our good faith judgment, such statements
can only be based on facts and factors currently known to us.
Consequently, forward-looking statements are inherently subject
to risks and uncertainties, and actual outcomes may differ
materially from the results and outcomes discussed in the
forward-looking statements. Further information about the risks
and uncertainties that may impact us are described in Risk
Factors beginning on page 14. You should read that
section carefully. You should not place undue reliance on
forward-looking statements, which speak only as of the date of
this prospectus. We undertake no obligation to update publicly
any forward-looking statements in order to reflect any event or
circumstance occurring after the date of this prospectus or
currently unknown facts or conditions or the occurrence of
unanticipated events.
NON-GAAP FINANCIAL MEASURES
The SEC has adopted rules to regulate the use of non-GAAP
financial measures such as EBITDA, that are derived on the
basis of methodologies other than in accordance with generally
accepted accounting principles, or GAAP. EBITDA is a non-GAAP
financial measure that complies with Securities Act regulations
when it is defined as net income (the most directly comparable
GAAP financial measure) before interest, taxes, depreciation and
amortization. We define EBITDA in this prospectus accordingly.
EBITDA has limitations as an analytical tool, and you should not
consider it in isolation, or as a substitute for analysis of our
results as reported under GAAP. For example, EBITDA:
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does not reflect our cash expenditures, or future requirements
for capital expenditures or contractual commitments; |
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does not reflect changes in, or cash requirements for, our
working capital needs; |
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does not reflect the significant interest expense, or the cash
requirements necessary to service interest or principal
payments, on our debts; and |
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does not reflect the effect of earnings or charges resulting
from matters we consider not to be indicative of our ongoing
operations. |
In addition, although depreciation and amortization are non-cash
charges, the assets being depreciated and amortized will often
have to be replaced in the future, and EBITDA does not reflect
any cash requirements for such replacements. Other companies in
our industry and in other industries may calculate EBITDA
differently from the way that we do, limiting its usefulness as
a comparative measure. Because of these limitations, EBITDA
should not be considered as a measure of discretionary cash
available to us to invest in the growth of our business. We
compensate for these limitations by relying primarily on our
GAAP results and using EBITDA only supplementally.
ii
INDUSTRY AND MARKET DATA
We have obtained some industry and market share data from
third-party sources that we believe are reliable. In many cases,
however, we have made statements in this prospectus regarding
our industry and our position in the industry based on estimates
made based on our experience in the industry and our own
investigation of market conditions. We believe these estimates
to be accurate as of the date of this prospectus. However, this
information may prove to be inaccurate because of the method by
which we obtained some of the data for our estimates or because
this information cannot always be verified with complete
certainty due to the limits on the availability and reliability
of raw data, the voluntary nature of the data gathering process
and other limitations and uncertainties. As a result, you should
be aware that the industry and market data included in this
prospectus, and estimates and beliefs based on that data, may
not be reliable. We cannot guarantee the accuracy or
completeness of any such information.
DEFINITIONS
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air drilling |
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A technique in which oil, natural gas, or geothermal wells are
drilled by creating a pressure within the well that is lower
than the reservoir pressure. The result is increased rate of
penetration, reduced formation damage, and reduced drilling
costs. |
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blow-out preventors |
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A large safety device placed on the surface of an oil or natural
gas well to control high pressure well bores. |
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booster |
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A machine that increases the pressure and/or volume of air when
used in conjunction with a compressor or a group of compressors. |
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capillary tubing |
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A small diameter tubing installed in producing wells and through
which chemicals are injected to enhance production and reduce
corrosion and other problems. |
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casing |
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A pipe placed in a drilled well to secure the well bore and
formation. |
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choke manifolds |
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An arrangement of pipes, valves and special valves on the rig
floor that controls pressure during drilling by diverting
pressure away from the
blow-out preventors and
the annulus of the well. |
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coiled tubing |
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A small diameter tubing used to service producing and
problematic wells and to work in high pressure applications
during drilling, production and workover operations. |
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directional drilling |
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The technique of drilling a well while varying the angle of
direction of a well and changing the direction of a well to hit
a specific target. |
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double studded adapter |
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A device that joins two dissimilar connections on certain
equipment, including valves, piping, and blow out preventors. |
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drill pipe |
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A pipe that attaches to the drill bit to drill a well. |
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heavy weight spiral drill pipe |
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A heavy drill pipe used for special applications primarily in
directional drilling. The spiral design increases
flexibility and penetration of the pipe. |
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horizontal drilling |
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The technique of drilling wells at a 90-degree angle. |
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laydown machines |
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A truck mounted machine used to move drill pipe, casing and
tubing onto a pipe rack (from which a derrick crane lifts the
drill pipe, casing and tubing and inserts it into the well). |
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mist pump |
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A drilling pump that uses mist as the circulation medium for
injecting small amounts of foaming agent, corrosion agent and
other chemical solutions into the well. |
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spacer spools |
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High pressure connections which are stacked to elevate the
blow-out preventors to the drilling rig floor. |
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straight hole drilling |
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The technique of drilling that allows very little or no vertical
deviation. |
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test plugs |
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A device used to test the connections of well heads and blow-out
preventors. |
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torque turn service or torque turn
equipment |
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A monitoring device to insure proper makeup of the casing. |
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tubing |
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A pipe placed inside the casing to allow the well to produce. |
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tubing work strings |
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The tubing used on workover rigs through which high pressure
liquids, gases or mixtures are pumped into a well to perform
production operations. |
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wear bushings |
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A device placed inside a wellhead to protect the wellhead from
wear. |
WHERE YOU CAN FIND MORE INFORMATION
We have filed a registration statement with the SEC under the
Securities Act that registers the issuance and sale of the
securities offered by this prospectus. The registration
statement, including the attached exhibits, contains additional
relevant information about us. The rules and regulations of the
SEC allow us to omit some information included in the
registration statement from this prospectus.
We file annual, quarterly, and other reports, proxy statements
and other information with the SEC under the Securities Exchange
Act of 1934, as amended. You may read and copy any materials we
file with the SEC at the SECs public reference room at 100
F Street, N.E., Washington, D.C. 20549. Please call the SEC
at 1-800-SEC-0330 for
further information on the public reference room. Our SEC
filings are also available to the public through the SECs
website at http://www.sec.gov. General information about us,
including our annual reports on
Form 10-K,
quarterly reports on
Form 10-Q and
current reports on
Form 8-K, as well
as any amendments and exhibits to those reports, are available
free of charge through our website at http://www.alchenergy.com
as soon as reasonably practicable after we file them with, or
furnish them to, the SEC. However, information on our website
and our other SEC filings mentioned above are not incorporated
into this prospectus and are not a part of this prospectus.
iv
PROSPECTUS SUMMARY
This summary is not complete. It highlights selected
information contained elsewhere in this prospectus. You should
read this entire prospectus carefully, including the information
under the heading Risk Factors, our financial
statements and the notes to those financial statements. Unless
the context requires otherwise, references in this prospectus to
Allis-Chalmers, we, us,
our or ours refer to Allis-Chalmers
Energy Inc., together with its subsidiaries, but not including
DLS. In this prospectus, we present pro forma as adjusted
financial information giving effect to the DLS transactions and
the Specialty transactions. When we refer to the DLS
transactions, we mean our acquisition of DLS Drilling, Logistics
& Services Corporation, or DLS, and the related financing of
that acquisition and repayment of obligations outstanding under
a subordinated note payable to M-I LLC with the proceeds of
our offering $95.0 million principal amount of old notes
and our concurrent offering of 3,450,000 shares of our common
stock, all of which closed on August 14, 2006. When we
refer to the Specialty transactions, we mean our acquisition of
Specialty Rental Tools, Inc., or Specialty, and the related
financing of that acquisition and repayment of obligations
outstanding under our credit facility with the proceeds of our
offering of $160.0 million principal amount of old notes,
all of which closed in January 2006.
Our Company
We are a multi-faceted oilfield services company that provides
services and equipment to oil and natural gas exploration and
production companies, domestically in Texas, Louisiana, New
Mexico, Colorado, Oklahoma, Mississippi, Utah, Wyoming, offshore
in the Gulf of Mexico, and internationally in Mexico. DLS, which
we acquired on August 14, 2006, is a leading provider of
drilling, completion, repair and related services for oil and
gas wells in Argentina.
Giving pro forma as adjusted effect to the recent Specialty
transactions, our recent acquisitions of Rogers Oil Tool
Services, Inc., Delta Rental Service, Inc., Capcoil Tubing
Services, Inc., W.T. Enterprises, Inc., the minority interest of
M-I LLC in AirComp LLC and the DLS transactions, we
would have generated revenues of $281.3 million, net income
of $7.1 million and EBITDA of $68.6 million for the
fiscal year ended December 31, 2005. Giving pro forma as
adjusted effect to the recent Rogers and DLS transactions, we
would have generated revenues of $191.6 million, net income
of $18.1 million and EBITDA of $51.6 million for the
six months ended June 30, 2006.
Acquisition of DLS
On August 14, 2006, we acquired all of the outstanding
capital stock of DLS, a leading provider of drilling,
completion, repair and related services for oil and gas wells in
Argentina. For the year ended December 31, 2005, DLS had
aggregate revenues of $129.8 million and income from
operations of $12.6 million. For the six months ended
June 30, 2006, DLS had aggregate revenues of
$82.0 million and income from operations of
$11.3 million. Pursuant to the stock purchase agreement
governing the DLS acquisition, upon closing of the acquisition
we entered into an investors rights agreement, providing, among
other things, that the sellers of DLS have the right to
designate two nominees for election to our board of directors.
With approximately 1,566 employees, DLS operates a fleet of 51
rigs, including 20 drilling rigs, 18 workover rigs and 12
pulling rigs in Argentina and one drilling rig in Bolivia. We
believe that the ability to offer drilling rigs is very
important in the international marketplace, and we expect this
acquisition to further diversify our business mix by balancing
our predominately natural gas based operations in the United
States with primarily oil based drilling operations in
Argentina. The integration of DLS operations into
Allis-Chalmers will significantly expand our geographic
footprint and increase our menu
1
of service offerings, and we anticipate that it will also
increase our opportunities to cross-sell existing Allis-Chalmers
products and services.
Business Segments
Prior to our acquisition of DLS, our five business segments were:
Directional Drilling Services. We employ approximately 75
full-time directional drillers utilizing
state-of-the-art
equipment for well planning and engineering services,
directional drilling packages, downhole motor technology, well
site directional supervision, exploratory and development
re-entry drilling, downhole guidance services and other drilling
services, including, logging-while-drilling and
measurement-while-drilling services. For the year ended
December 31, 2005, our directional drilling services
segment had revenues of $43.9 million and income from
operations of $7.4 million. For the six months ended
June 30, 2006, our directional drilling services segment
had revenues of $33.4 million and income from operations of
$7.0 million.
Rental Tools. We provide specialized rental equipment,
including premium drill pipe, heavy weight spiral drill pipe,
tubing work strings, blow out preventors, choke manifolds and
various valves and handling tools, for both onshore and offshore
well drilling, completion and workover operations. For the year
ended December 31, 2005, our rental tools segment had
revenues of $5.1 million and income from operations of
$1.3 million. After giving pro forma effect to the
Specialty acquisition and our acquisition of Delta Rental
Service, Inc., for the year ended December 31, 2005, our
rental tools segment would have had revenues of
$38.6 million and income from operations of
$11.9 million. For the six months ended June 30, 2006,
our rental tools segment had revenues of $23.1 million and
income from operations of $12.3 million.
Casing and Tubing Services. We provide specialized
equipment and trained operators for a variety of pipe handling
services, including installing casing and tubing, changing out
drill pipe and retrieving production tubing for both onshore and
offshore drilling and workover operations. For the year ended
December 31, 2005, our casing and tubing services segment
had revenues of $20.9 million and income from operations of
$5.0 million. After giving pro forma effect to the Rogers
acquisition, for the year ended December 31, 2005, our
casing and tubing services segment would have had revenues of
$29.3 million and income from operations of
$5.8 million. For the six months ended June 30, 2006,
our casing and tubing services segment had revenues of
$24.0 million and income from operations of
$6.2 million. After giving pro forma effect to the Rogers
acquisition, for the six months ended June 30, 2006, our
casing and tubing services segment would have had revenues of
$26.1 million and income from operations of
$6.2 million.
Compressed Air Drilling Services. We provide compressed
air equipment, drilling bits, hammers, drilling chemicals and
other specialized drilling products for underbalanced drilling
applications. With a combined fleet of over 130 compressors
and boosters, we believe we are one of the largest providers of
compressed air or underbalanced drilling services in the United
States. For the year ended December 31, 2005, our
compressed air drilling services segment had revenues of
$25.7 million and income from operations of
$5.6 million. After giving pro forma effect to our
acquisition of W. T. Enterprises, Inc., for the year
ended December 31, 2005, our compressed air drilling
services segment would have had revenues of $27.8 million
and income from operations of $5.7 million. For the six
months ended June 30, 2006, our compressed air drilling
services segment had revenues of $20.0 million and income
from operations of $5.4 million.
Production Services. We provide specialized equipment and
trained operators to install and retrieve capillary tubing,
through which chemicals are injected into producing wells to
increase production and reduce corrosion, and workover services
with coiled tubing units. For the year ended
2
December 31, 2005, our production services segment had
revenues of $9.8 million and a loss from operations of
$99,000. After giving pro forma effect to our acquisition of
Capcoil Tubing Services, Inc., for the year ended
December 31, 2005, our production services segment would
have had revenues of $12.0 million and breakeven income for
operations. For the six months ended June 30, 2006, our
production services segment had revenues of $6.9 million
and income from operations of $618,000.
In addition to the businesses mentioned above, we recently
entered into the contract drilling and repair services business
in Argentina and Bolivia when we completed our acquisition of
DLS on August 14, 2006.
Competitive Strengths
Our competitive strengths are:
Strategic position in high growth markets. We focus on
markets we believe are growing faster than the overall oilfield
services industry. We are a leading provider of products and
services in directional drilling and air drilling, which we
believe to be two of the fastest growing segments of the
oilfield services industry.
Strong relationships with diversified customer base. We
have strong relationships with many of the major and independent
oil and natural gas producers and service companies in Texas,
Louisiana, New Mexico, Colorado, Oklahoma, Mississippi, Utah,
Wyoming, offshore in the Gulf of Mexico and Mexico. Our largest
customers include Burlington Resources, ConocoPhilips, BP,
ChevronTexaco, Kerr-McGee, Dominion Resources, Remington Oil and
Gas, Petrohawk Energy, Newfield Exploration, El Paso
Corporation, Materiales y Equipo Petroleo S.A. de C.V. and
Anadarko Petroleum.
Successful execution of growth strategy. Over the past
five years, we have grown both organically and through
successful acquisitions of competing businesses. Since 2001, we
have completed 16 acquisitions. We strive to improve the
operating performance of our acquired businesses by increasing
their asset utilization and operating efficiency.
Experienced and dedicated management team. Our executive
management team has extensive experience in the energy sector,
and consequently has developed strong and longstanding
relationships with many of the major and independent exploration
and production companies.
Business Strategy
Expand geographically to provide greater access and service
to key customer segments. We have recently opened new
locations in Texas, New Mexico, Colorado, Oklahoma and Louisiana
in order to enhance our proximity to customers and more
efficiently serve their needs. We plan to continue to establish
new locations in the United States and internationally.
Prudently pursue strategic acquisitions. To complement
our organic growth, we seek to opportunistically complete, at
attractive valuations, strategic acquisitions that will be
accretive to earnings and complement our products and services,
expand our geographic footprint and market presence, and further
diversify our customer base.
Expand products and services provided in existing operating
locations. Since the beginning of 2003, we have made
approximately $42.0 million in capital expenditures to grow
our business organically by expanding our product and service
offerings.
Increase utilization of assets. We seek to grow revenues
and enhance margins by continuing to increase the utilization of
our rental assets with new and existing customers.
3
Target services in which we have a competitive advantage.
We believe consolidation in the oilfield services industry has
created an opportunity for us to compete effectively in markets
that are underserved by the large oilfield services and
equipment companies.
Recent Developments
On August 8, 2006, we entered into an amendment to our
amended and restated credit agreement dated as of
January 18, 2006. The amendment, among other things,
amended the credit agreement to (a) allow us to
(i) issue and sell $95.0 million aggregate principal
amount of our 9.0% senior notes due 2014 and
(ii) issue and sell 3,450,000 shares of our common
stock, (b) allow us to use the net proceeds from the senior
notes offering and the common stock offering to purchase all the
outstanding capital stock of DLS, (c) exclude certain
existing indebtedness and investments of DLS and investments and
indebtedness related to the DLS acquisition from the covenants
contained in the credit agreement and (d) increase the
amount of permitted lease obligations and capital expenditures.
On August 8, 2006, we priced a public offering of
3.0 million shares of our common stock at $14.50 per
share. We granted the underwriters a
30-day option to
purchase up to an additional 450,000 shares to cover
over-allotments, if any. On August 14, 2006, we closed the
common stock offering and the underwriters elected to exercise
the over-allotment option in full. We ultimately raised
approximately $47.0 million from such registered stock
offering and applied all such amount toward the cash component
of the purchase price of DLS.
We also priced a private offering of $95.0 million
aggregate principal amount of 9.0% senior notes on
August 8, 2006. The notes were sold to investors at a price
of 100% of the principal amount thereof, plus accrued interest
from July 15, 2006. Fixed interest on the notes will be
payable on January 15 and July 15 of each year, beginning on
January 15, 2007 and the notes mature on January 15,
2014. The sale of the notes closed on August 14, 2006. We
raised net proceeds of approximately $92.7 million through
the issuance of such 9.0% senior notes, and we applied a
portion of such amount to the payment of the remainder of the
cash component of the purchase price for DLS.
On August 14, 2006, we completed the acquisition of all of
the outstanding capital stock of DLS. The purchase price of DLS
consisted of $93.7 million in cash, 2.5 million shares
of our common stock and approximately $8.6 million of
assumed debt. DLS currently operates a fleet of 51 rigs,
including 20 drilling rigs, 18 workover rigs and 12 pulling rigs
in Argentina and one drilling rig in Bolivia.
As part of the DLS acquisition, Carlos Alberto Bulgheroni and
Alejandro Pedro Bulgheroni have joined our board of directors,
filling vacancies created by the resignations of Jens H.
Mortensen, Jr. and Thomas O. Whitener, Jr. On
August 21, 2006, Thomas E. Kelly resigned from our board of
directors.
Our principal executive offices are located at
5075 Westheimer, Suite 890, Houston, Texas 77056, and
our telephone number at that address is
(800) 997-9534.
Our website address is www.alchenergy.com. However,
information contained on our website is not incorporated by
reference into this prospectus, and you should not consider the
information contained on our website to be part of this
prospectus.
4
Summary of the Terms of the Exchange Offer
|
|
|
Initial Offering of Notes |
|
On January 18, 2006, we completed a private offering of
$160,000,000 principal amount of our 9.0% senior
notes 2014. On August 14, 2006, we completed a private
offering of an additional $95,000,000 principal amount of notes
of the same series. In this prospectus, we refer to the notes
that we issued in the January 2006 and August 2006 offerings as
our old notes. We entered into a registration rights agreement
with the initial purchasers in each private offering in which we
agreed, among other things, to use our commercially reasonable
efforts to complete this exchange offer. The following summary
highlights selected information from this prospectus concerning
the exchange offer and may not contain all of the information
that is important to you. We encourage you to read the entire
prospectus carefully. |
|
Registration Rights Agreements |
|
Pursuant to the registration rights agreements among us, the
Guarantor parties thereto and the initial purchasers entered
into in connection with the private placements of the old notes,
we have agreed to offer to exchange the old notes for up to
$255,000,000 principal amount of 9.0% Senior Notes due 2014
that are being offered hereby. We refer to the notes issued for
the old notes in this exchange offer as the new notes. We have
filed the registration statement of which this prospectus forms
a part to meet our obligations under the registration rights
agreements. If we fail to satisfy these obligations, we will be
required to pay liquidated damages to holders of the old notes
under specified circumstances. |
|
The Exchange Offer |
|
We are offering to exchange all old notes for the same aggregate
principal amount of new notes, the offers and sales of which
have been registered under the Securities Act. The old notes may
be tendered only in minimum denominations of $2,000 and integral
multiples of $1,000 in excess thereof. We will exchange all old
notes for new notes that are validly tendered and not withdrawn
prior to the expiration of the exchange offer. We will cause the
exchange to be effected promptly after the expiration date of
the exchange offer. |
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|
The new notes will evidence the same debt as the old notes and
will be issued under and entitled to the benefits of the same
indenture that governs the old notes. Because we have registered
the offers and sales of the new notes, the new notes will not be
subject to transfer restrictions, and holders of old notes that
have tendered and had their outstanding notes accepted in the
exchange offer will have no registration rights. |
|
If You Fail to Exchange Your Old Notes |
|
If you do not exchange your old notes for new notes in the
exchange offer, you will continue to be subject to the
restrictions on transfer provided in the old notes and the
indenture governing those notes. In general, you may not offer
or sell your old notes without registration under the federal
securities laws or an exemption from the registration require- |
5
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ments of the federal securities laws and applicable state
securities laws. |
|
Procedures for Tendering Your Old Notes |
|
If you wish to tender your old notes for new notes, you must: |
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complete and sign the enclosed letter of transmittal
by following the related instructions, and |
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send the letter of transmittal, as directed in the
instructions, together with any other required documents, to the
exchange agent either (1) with the old notes to be
tendered, or (2) in compliance with the specified
procedures for guaranteed delivery of the old notes. |
|
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|
Brokers, dealers, commercial banks, trust companies and other
nominees may also effect tenders by book-entry transfer. |
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By executing the letter of transmittal or by transmitting an
agents message in lieu thereof, you will represent to us
that, among other things: |
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the new notes you receive will be acquired in the
ordinary course of your business; |
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you are not participating, and you have no
arrangement with any person or entity to participate, in the
distribution of the new notes; |
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you are not our affiliate, as defined in
Rule 405 under the Securities Act, or a broker-dealer
tendering old notes acquired directly from us for resale
pursuant to Rule 144A or any other available exemption
under the Securities Act; and |
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|
if you are not a broker-dealer, that you are not
engaged in and do not intend to engage in the distribution of
the new notes. |
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If your old notes are registered in the name of a broker,
dealer, commercial bank, trust company or other nominee, we urge
you to contact that person promptly if you wish to tender your
old notes pursuant to this exchange offer. See The
Exchange Offer Procedures for Tendering Old
Notes. Please do not send your letter of transmittal or
certificates representing your old notes to us. Those documents
should be sent only to the exchange agent. Questions regarding
how to tender and requests for information should be directed to
the exchange agent. See The Exchange Offer
Exchange Agent. |
|
Resale of the New Notes |
|
Except as provided below, we believe that the new notes may be
offered for resale, resold and otherwise transferred by you
without compliance with the registration and prospectus delivery
provisions of the Securities Act provided that: |
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|
the new notes are being acquired in the ordinary
course of business, |
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|
you are not participating, do not intend to
participate, and have no arrangement or understanding with any
person to participate in the distribution of the new notes
issued to you in the exchange offer, |
6
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you are not our affiliate, and |
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you are not a broker-dealer tendering old notes
acquired directly from us for your account. |
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|
Our belief is based on interpretations by the staff of the SEC,
as set forth in no-action letters issued to third parties that
are not related to us. The SEC has not considered this exchange
offer in the context of a no-action letter, and we cannot assure
you that the SEC would make similar determinations with respect
to this exchange offer. If any of these conditions are not
satisfied, or if our belief is not accurate, and you transfer
any new notes issued to you in the exchange offer without
delivering a resale prospectus meeting the requirements of the
Securities Act or without an exemption from registration of your
new notes from those requirements, you may incur liability under
the Securities Act. We will not assume, nor will we indemnify
you against, any such liability. Each broker-dealer that
receives new notes for its own account in exchange for old
notes, where the old notes were acquired by such broker-dealer
as a result of market-making or other trading activities, must
acknowledge that it will deliver a prospectus in connection with
any resale of such new notes. See Plan of
Distribution. |
|
Expiration Date |
|
The exchange offer will expire at 5:00 p.m., New York City
time,
on ,
2006, unless we decide to extend the expiration date. We do not
currently intend to extend the exchange offer. |
|
Conditions to the Exchange Offer |
|
The exchange offer is not subject to any conditions other than
that it does not violate applicable law or any applicable
interpretation of the staff of the SEC. |
|
Exchange Agent |
|
We have appointed Wells Fargo Bank, N.A. as exchange agent for
the exchange offer. You can reach the exchange agent at the
address set forth on the back cover of this prospectus. For more
information with respect to the exchange offer, you may call the
exchange agent at
800-344-5128; the fax
number for the exchange agent is
612-667-4927. |
|
Withdrawal Rights |
|
You may withdraw the tender of your old notes at any time before
the expiration date of the exchange offer. You must follow the
withdrawal procedures as described under the heading The
Exchange Offer Withdrawal of Tenders. |
|
Federal Income Tax Consequences |
|
The exchange of old notes for new notes in the exchange offer
will not be a taxable transaction for U.S. federal income
tax purposes. See Material U.S. Federal Income Tax
Considerations. |
|
Acceptance of Old Notes and Delivery of New Notes |
|
We will accept for exchange any and all old notes that are
properly tendered in the exchange offer prior to the expiration
date. See The Exchange Offer Procedures for
Tendering Old Notes. The new notes issued pursuant to the
exchange offer will be delivered promptly following the
expiration date. |
7
Summary of the Terms of the New Notes
Set forth below is a brief summary of some of the principal
terms of the new notes. You should also read the information
under the caption Description of Notes later in this
prospectus for a more detailed description and understanding of
the terms of the new notes. In describing the terms of the
notes, references to Allis-Chalmers, we,
us and our mean Allis-Chalmers Energy
Inc., and not any of its subsidiaries.
|
|
|
Issuer |
|
Allis-Chalmers Energy Inc. |
|
New Notes |
|
$255.0 million aggregate principal amount of 9.0% senior
notes due 2014. |
|
Maturity Date |
|
January 15, 2014. |
|
Interest Rate |
|
9.0% per year. |
|
Interest Payment Dates |
|
Each January 15 and July 15, beginning on
January 15, 2007. Interest will accrue from July 15,
2006. |
|
Guarantees |
|
The new notes will be fully and unconditionally guaranteed,
jointly and severally, by all of our current and future domestic
restricted subsidiaries, subject to certain materiality
exceptions. Our current and future foreign subsidiaries (such as
DLS and its subsidiaries) will not guarantee the new notes. |
|
Ranking |
|
The new notes will be senior unsecured obligations of
Allis-Chalmers, ranking equally with all of our existing and
future senior unsecured indebtedness and senior to any existing
and future subordinated indebtedness. The new notes will be
effectively subordinated to any existing or future secured
indebtedness, including under our credit agreement, to the
extent of the assets securing such indebtedness. |
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|
The guarantees will be senior unsecured obligations of the
subsidiary guarantors. The guarantees will rank equally with all
existing and future senior unsecured indebtedness of the
subsidiary guarantors and senior to any existing and future
subordinated indebtedness of the subsidiary guarantors. The
guarantees will be effectively subordinated to any existing or
future secured indebtedness of the subsidiary guarantors to the
extent of the assets securing such indebtedness. |
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|
As of June 30, 2006, after giving effect to the DLS
transactions, as if each such transaction had occurred on that
date, Allis-Chalmers, not including any of its subsidiaries,
would have had approximately $257.6 million of total
indebtedness ($130,000 of which would have been secured
indebtedness) and approximately $11.7 million of additional
secured borrowing capacity available under our credit agreement.
In addition, as of June 30, 2006, after giving effect to
the transactions described above, our subsidiary guarantors
would have had approximately $267.3 million of total
indebtedness (approximately $3.1 million of which would
have been secured indebtedness). |
8
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|
Optional Redemption |
|
We may, at our option, redeem all or part of the notes, at any
time prior to January 15, 2010 at a make-whole price, and
on or after January 15, 2010 at fixed redemption prices,
plus accrued and unpaid interest, if any, to the date of
redemption, as described under Description of
Notes Optional Redemption. |
|
Optional Redemption After Equity Offerings |
|
At any time, which may be more than once, before
January 15, 2009, we may redeem up to 35% of the
outstanding notes with money that we raise in one or more equity
offerings at a redemption price of 109.0% of the par value of
the notes redeemed, plus accrued and unpaid interest, as long as: |
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|
we redeem the notes within 180 days of
completing the equity offering; and |
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at least 65% of the aggregate principal amount of
notes issued in the January 2006 notes offering remains
outstanding after the redemption. |
|
Change of Control Offer |
|
If we experience certain kinds of changes of control, we must
give holders of the notes the opportunity to sell us their notes
at 101% of their principal amount, plus accrued and unpaid
interest. |
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However, we might not be able to pay you the required price for
the notes you present to us at the time of a change of control,
because: |
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|
we might not have enough funds at that time; or |
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the terms of our bank credit agreement may prevent
us from applying funds to repurchase the notes. |
|
Covenants |
|
The old notes were issued under an indenture among
Allis-Chalmers, the subsidiary guarantors and Wells Fargo Bank,
N.A., as trustee. The indenture will also govern the new notes.
The indenture contains covenants that, among other things, limit
our ability and the ability of our restricted subsidiaries to: |
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incur additional debt; |
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make certain investments or pay dividends or
distributions on our capital stock or purchase or redeem or
retire capital stock; |
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sell assets, including capital stock of our
restricted subsidiaries; |
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restrict dividends or other payments by restricted
subsidiaries; |
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create liens; |
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enter into transactions with affiliates; and |
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merge or consolidate with another company. |
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These covenants are subject to a number of important limitations
and exceptions that are described later in this |
9
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prospectus under the caption Description of
Notes Covenants. |
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Use of Proceeds |
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We will not receive any proceeds from the exchange of the
outstanding old notes for the new notes. See Use of
Proceeds. |
|
Transfer Restrictions; Absence of a Public Market for the Notes |
|
The new notes generally will be freely transferable, but will
also be new securities for which there is no established public
trading market. We cannot assure you that: |
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an active public market for the new notes will
develop; |
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any market that may develop for the new notes will
be liquid; or |
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holders will be able to sell the new notes at all or
at favorable prices. |
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Future trading prices of the new notes will depend on many
factors, including among other things, prevailing interest
rates, our operating results, our credit rating and the market
for similar securities. We do not intend to apply for a listing
of the old notes or the new notes on any securities exchange or
for inclusion of the old notes or the new notes in any automated
dealer quotation system. |
|
Risk Factors |
|
Investing in the new notes involves risks. See Risk
Factors beginning on page 14 of this prospectus for a
description of risks you should consider before exchanging
outstanding old notes for new notes. |
10
Summary Historical and Pro Forma Consolidated Financial
Information
The following summary historical consolidated financial
information for each of the years in the three-year period ended
December 31, 2005 has been derived from our audited
consolidated financial statements. The following summary
historical consolidated financial information for the six months
ended June 30, 2006 and 2005 has been derived from our
unaudited consolidated financial statements and, in the opinion
of our management, includes all adjustments, consisting only of
normal recurring adjustments, necessary for a fair presentation.
The summary pro forma as adjusted consolidated statement of
operations and other information for the year ended
December 31, 2005 gives effect on a pro forma as adjusted
basis to our acquisitions of Capcoil Tubing Services, Inc.,
Delta Rental Service, Inc., the minority interest of M-I LLC in
AirComp LLC, W.T. Enterprises, Inc., and Rogers Oil Tool
Services, Inc., or Rogers, and the consummation of the Specialty
transactions and the DLS transactions, as if such acquisitions
and transactions were consummated on January 1, 2005.
However, the pro forma statement of operations information
presented below for the year ended December 31, 2005 does
not give effect to our immaterial acquisition of Target Energy,
Inc., which was acquired effective August 1, 2005, and our
acquisition of certain casing and tubing assets from Patterson
Services, Inc. on September 1, 2005. The summary pro forma
as adjusted consolidated statement of operations and other
information for the six months ended June 30, 2006 gives
effect on a pro forma as adjusted basis to our acquisition of
Rogers and the DLS transactions, as if such acquisition and such
transactions were consummated on January 1, 2005. The
summary pro forma as adjusted consolidated balance sheet
information gives effect on a pro forma basis to the
consummation of the DLS transactions and our acquisition of
Rogers, as if such transactions were consummated on
June 30, 2006. This information is only a summary and you
should read it in conjunction with Managements
Discussion and Analysis of Financial Condition and Results of
Operations, which discusses factors affecting the
comparability of the information presented, and in conjunction
with our consolidated financial statements and related notes
included elsewhere in this prospectus, including the pro forma
financial statements. Our historical consolidated financial
statements have been restated for the period from July 1,
2003 through March 31, 2005, as described in the notes to
our consolidated financial statements included elsewhere herein.
Results for interim periods may not be indicative of results for
full fiscal years.
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Historical | |
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Pro Forma As Adjusted | |
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Six Months | |
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Ended | |
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Six Months | |
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Year Ended December 31, | |
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June 30, | |
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Year Ended | |
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Ended | |
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| |
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December 31, | |
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June 30, | |
|
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2003 | |
|
2004 | |
|
2005 | |
|
2005 | |
|
2006 | |
|
2005 | |
|
2006 | |
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(Unaudited) | |
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(Unaudited) | |
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(Unaudited) | |
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(In thousands, except per share amounts) | |
Statement of Operations Information:
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Revenues
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$ |
32,724 |
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|
$ |
47,726 |
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|
$ |
105,344 |
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$ |
42,922 |
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$ |
107,498 |
|
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$ |
281,317 |
|
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$ |
191,602 |
|
Cost of revenues
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|
|
24,029 |
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|
|
35,300 |
|
|
|
74,763 |
|
|
|
30,482 |
|
|
|
66,239 |
|
|
|
211,185 |
|
|
|
135,493 |
|
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Gross Profit
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|
|
8,695 |
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|
|
12,426 |
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|
|
30,581 |
|
|
|
12,440 |
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|
|
41,259 |
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|
|
70,132 |
|
|
|
56,109 |
|
Income from operations
|
|
|
2,625 |
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|
|
4,227 |
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|
|
13,218 |
|
|
|
5,161 |
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|
|
24,504 |
|
|
|
36,457 |
|
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|
36,138 |
|
Interest expense, net
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|
(2,464 |
) |
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|
(2,776 |
) |
|
|
(4,397 |
) |
|
|
(1,166 |
) |
|
|
(7,425 |
) |
|
|
(26,030 |
) |
|
|
(13,343 |
) |
Income from continuing operations
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2,927 |
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|
|
888 |
|
|
|
7,175 |
|
|
|
3,336 |
|
|
|
14,018 |
|
|
|
11,277 |
|
|
|
15,734 |
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,138 |
) |
|
|
2,375 |
|
Net income
|
|
|
2,927 |
|
|
|
888 |
|
|
|
7,175 |
|
|
|
3,336 |
|
|
|
14,018 |
|
|
|
7,139 |
|
|
|
18,109 |
|
Preferred stock dividend
|
|
|
(656 |
) |
|
|
(124 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributed to common stockholders
|
|
$ |
2,271 |
|
|
$ |
764 |
|
|
$ |
7,175 |
|
|
$ |
3,336 |
|
|
$ |
14,018 |
|
|
$ |
7,139 |
|
|
$ |
18,109 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
11
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Historical | |
|
Pro Forma As Adjusted | |
|
|
| |
|
| |
|
|
|
|
Six Months | |
|
|
|
Six Months | |
|
|
Year Ended December 31, | |
|
Ended June 30, | |
|
Year Ended | |
|
Ended | |
|
|
| |
|
| |
|
December 31, | |
|
June 30, | |
|
|
2003 | |
|
2004 | |
|
2005 | |
|
2005 | |
|
2006 | |
|
2005 | |
|
2006 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands, except ratios) | |
Other Financial Information (unaudited):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA(1)(2)
|
|
$ |
8,697 |
|
|
$ |
7,756 |
|
|
$ |
19,577 |
|
|
$ |
7,657 |
|
|
$ |
32,955 |
|
|
$ |
68,594 |
|
|
$ |
51,598 |
|
Capital expenditures
|
|
|
5,354 |
|
|
|
4,603 |
|
|
|
17,767 |
|
|
|
5,463 |
|
|
|
14,246 |
|
|
|
|
|
|
|
|
|
Ratio of earnings to fixed charges(3)
|
|
|
2.2 |
x |
|
|
1.5 |
x |
|
|
2.6 |
x |
|
|
3.9 |
x |
|
|
3.1 |
x |
|
|
1.6 |
x |
|
|
2.7 |
x |
|
|
|
|
|
|
|
|
|
|
|
As of June 30, 2006 | |
|
|
| |
|
|
|
|
Pro Forma | |
|
|
Actual | |
|
As Adjusted | |
|
|
| |
|
| |
|
|
(Unaudited) | |
|
|
(In thousands) | |
Balance Sheet Information:
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
6,208 |
|
|
$ |
44,164 |
|
Total assets
|
|
|
280,686 |
|
|
|
524,192 |
|
Long-term debt (including current portion)
|
|
|
170,016 |
|
|
|
269,630 |
|
Stockholders equity
|
|
|
83,281 |
|
|
|
168,205 |
|
|
|
(1) |
EBITDA is a non-GAAP financial measure that we
define as net income before interest, taxes, depreciation and
amortization. |
|
(2) |
EBITDA, as used and defined by us, may not be
comparable to similarly titled measures employed by other
companies and is not a measure of performance calculated in
accordance with GAAP. EBITDA should not be considered in
isolation or as a substitute for operating income, net income or
loss, cash flows provided by operating, investing and financing
activities, or other income or cash flow statement data prepared
in accordance with GAAP. However, our management believes EBITDA
is useful to an investor in evaluating our operating performance
because this measure: |
|
|
|
|
|
is widely used by investors in the energy industry to measure a
companys operating performance without regard to items
excluded from the calculation of such term, which can vary
substantially from company to company depending upon accounting
methods and book value of assets, capital structure and the
method by which assets were acquired, among other factors; |
|
|
|
helps investors to more meaningfully evaluate and compare the
results of our operations from period to period by removing the
effect of our capital structure and asset base from our
operating structure; and |
|
|
|
is used by our management for various purposes, including as a
measure of operating performance, in presentations to our board
of directors, as a basis for strategic planning and forecasting,
and as a component for setting incentive compensation. |
|
|
|
There are significant limitations to using EBITDA as a measure
of performance, including the inability to analyze the effect of
certain recurring and non-recurring items that materially affect
our net income or loss, and the lack of comparability of results
of operations of different companies. |
12
|
|
|
The following table reconciles our net income, the most directly
comparable GAAP financial measure, to EBITDA: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Historical | |
|
Pro Forma As Adjusted | |
|
|
| |
|
| |
|
|
|
|
Six Months | |
|
|
|
|
Year Ended | |
|
Ended | |
|
|
|
Six Months | |
|
|
December 31, | |
|
June 30, | |
|
Year Ended | |
|
Ended | |
|
|
| |
|
| |
|
December 31, | |
|
June 30, | |
|
|
2003 | |
|
2004 | |
|
2005 | |
|
2005 | |
|
2006 | |
|
2005 | |
|
2006 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
(Unaudited) | |
|
(Unaudited) | |
|
(Unaudited) | |
|
|
(In thousands) | |
Net income
|
|
$ |
2,927 |
|
|
$ |
888 |
|
|
$ |
7,175 |
|
|
$ |
3,336 |
|
|
$ |
14,018 |
|
|
$ |
7,139 |
|
|
$ |
18,109 |
|
Interest expense, net
|
|
|
2,464 |
|
|
|
2,776 |
|
|
|
4,397 |
|
|
|
1,166 |
|
|
|
7,425 |
|
|
|
26,030 |
|
|
|
13,343 |
|
Income taxes
|
|
|
370 |
|
|
|
514 |
|
|
|
1,344 |
|
|
|
329 |
|
|
|
3,081 |
|
|
|
6,888 |
|
|
|
6,290 |
|
Depreciation and amortization
|
|
|
2,936 |
|
|
|
3,578 |
|
|
|
6,661 |
|
|
|
2,826 |
|
|
|
8,431 |
|
|
|
28,537 |
|
|
|
13,856 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EBITDA
|
|
$ |
8,697 |
|
|
$ |
7,756 |
|
|
$ |
19,577 |
|
|
$ |
7,657 |
|
|
$ |
32,955 |
|
|
$ |
68,594 |
|
|
$ |
51,598 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(3) |
For purposes of determining the ratio of earnings to fixed
charges, earnings are defined as net income before income taxes,
extraordinary items, amortization of capitalized interest and
fixed charges, less capitalized interest. Fixed charges consist
of interest (whether expensed or capitalized), amortization of
debt expenses and discount or premium relating to any
indebtedness and dividends on preferred stock and the interest
component of leases represents the portion of rental expense
which we estimate as an interest component. |
13
RISK FACTORS
An investment in the notes is subject to numerous risks,
including those listed below. You should carefully consider the
following risks, along with the information provided elsewhere
in this prospectus. These risks could materially affect our
ability to meet our obligations under the notes. You could lose
all or part of your investment in and fail to achieve the
expected return on the notes.
Risks Associated With Our Company
|
|
|
We may fail to acquire
additional businesses, which will restrict our growth and may
have a material adverse effect on our ability to meet our
obligations under the notes. |
Our business strategy is to acquire companies operating in the
oilfield services industry. However, there can be no assurance
that we will be successful in acquiring any additional
companies. Successful acquisition of new companies will depend
on various factors, including but not limited to:
|
|
|
|
|
our ability to obtain financing; |
|
|
|
the competitive environment for acquisitions; and |
|
|
|
the integration and synergy issues described in the next risk
factor. |
There can be no assurance that we will be able to acquire and
successfully operate any particular business or that we will be
able to expand into areas that we have targeted. Our financial
condition, results of operations and ability to meet our
obligations under the notes may be materially adversely affected
if we fail to acquire additional businesses.
|
|
|
Difficulties in integrating
acquired businesses may result in reduced revenues and
income. |
We may not be able to successfully integrate the businesses of
our operating subsidiaries or any business we may acquire in the
future. The integration of the businesses will be complex and
time consuming, will place a significant strain on management
and our information systems, and this strain could disrupt our
businesses. Furthermore, if our combined businesses continue to
grow rapidly, we may be required to replace our current
information and accounting systems with systems designed for
companies that are larger than ours. We may be adversely
impacted by unknown liabilities of acquired businesses. We may
encounter substantial difficulties, costs and delays involved in
integrating common accounting, information and communication
systems, operating procedures, internal controls and human
resources practices, including incompatibility of business
cultures and the loss of key employees and customers. These
difficulties may reduce our ability to gain customers or retain
existing customers, and may increase operating expenses,
resulting in reduced revenues and income and a failure to
realize the anticipated benefits of acquisitions.
In particular, our recent acquisition of DLS and our recent
acquisition of Specialty have been our two largest acquisitions
to date and may pose greater integration risks than our previous
acquisitions. We will be conducting parts of the integration of
these two companies simultaneously, and as a result we could
strain our current resources. Furthermore, by financing part or
all of these acquisitions with proceeds from the offering of the
notes, we will depend on these entities continued
performance as a source of cash flow to service our debt
obligations.
We have made numerous acquisitions during the past five years.
As a result of these transactions, our past performance is not
indicative of future performance, and investors should not base
their expectations as to our future performance on our
historical results.
14
|
|
|
We anticipate that our recent
acquisition of DLS will substantially change the nature of our
operations and business. |
We anticipate that our recent acquisition of DLS will
substantially change the nature and geographic location of our
operations and business as a result of the character and
location of DLS businesses, which have substantially
different operating characteristics and are in different
geographic locations from our existing businesses. Prior to our
acquisition of DLS, we have operated as an oilfield services
company domestically in Texas, Louisiana, New Mexico, Colorado,
Oklahoma, Mississippi, Utah, Wyoming, offshore in the Gulf of
Mexico, and internationally in Mexico. DLS business is
located primarily in Argentina, and we have no significant
operations in South America other than through DLS. Accordingly,
this acquisition will subject us to risks inherent in operating
in a foreign country where we do not have significant prior
experience. DLS business consists of employing drilling
and workover rigs for drilling, completion and repair services
for oil and gas wells, and we do not own any drilling rigs or
workover rigs other than through DLS, and have not historically
provided such services. Consequently, we may not be able to
realize the economic benefits of this acquisition as efficiently
as in our prior acquisitions, if at all.
|
|
|
Failure to maintain effective
disclosure controls and procedures and/or internal controls over
financial reporting could have a material adverse effect on our
operations. |
As disclosed in the notes to our consolidated financial
statements included elsewhere in this prospectus and under the
caption Managements Discussion and Analysis of
Financial Condition and Results of Operations
Restatement, we understated diluted earnings per share due
to an incorrect calculation of our weighted shares outstanding
for the third quarter of 2003, for each of the first three
quarters of 2004, for the years ended December 31, 2003 and
2004 and for the quarter ended March 31, 2005. In addition,
we understated basic earnings per share due to an incorrect
calculation of our weighted average basic shares outstanding for
the quarter ended September 30, 2004. Consequently, we have
restated our financial statements for each of those periods. The
incorrect calculation resulted from a mathematical error and an
improper application of Statement of Financial Accounting
Standards, or SFAS, No. 128, Earnings Per
Share. Management has concluded that the need to
restate our financial statements resulted, in part, from the
lack of sufficient experienced accounting personnel, which in
turn resulted in a lack of effective control over the financial
reporting process.
In addition, as part of our growth strategy, we have recently
completed several acquisitions of privately-held businesses,
including closely-held entities, and in the future, we may make
additional strategic acquisitions of privately-held businesses.
Prior to becoming part of our consolidated company, these
acquired businesses have not been required to implement or
maintain the disclosure controls and procedures or internal
controls over financial reporting that federal law requires of
publicly-held companies such as ours. Similarly, it is likely
that our future acquired businesses will not have been required
to maintain such disclosure controls and procedures or internal
controls prior to their acquisition. We are in the process of
creating and implementing appropriate disclosure controls and
procedures and internal controls over financial reporting at
each of our recently acquired businesses. However, we have not
yet completed this process and cannot assure you as to when the
process will be complete. Likewise, upon the completion of any
future acquisition, we will be required to integrate the
acquired business into our consolidated companys system of
disclosure controls and procedures and internal controls over
financial reporting, but we cannot assure you as to how long the
integration process may take for any business that we may
acquire. Furthermore, during the integration process, we may not
be able to fully implement our consolidated disclosure controls
and internal controls over financial reporting. With respect to
our recent acquisition of DLS, this risk is exacerbated by
DLS relative size, when compared to the rest of our
consolidated company.
15
Also, during the fourth quarter of 2005, we failed to timely
file a Current Report on
Form 8-K relating
to the issuance of shares of our common stock in connection with
recent stock option and warrant exercises. The current report,
which was due to be filed in November 2005, was filed in
February 2006.
As a result of the issues described above, our management has
concluded that, as of the end of the periods covered by the
restatements and as of December 31, 2005, our disclosure
controls and procedures were not effective to enable us to
record, process, summarize and report information required to be
included in our SEC filings within the required time periods,
and to ensure that such information is accumulated and reported
to our management, including our chief executive officer and
chief financial accounting officer, to allow timely decisions
regarding required disclosure.
As more fully described below under the caption
Managements Discussion and Analysis of Financial
Condition and Results of Operations
Restatement, we have implemented a number of actions that
we believe address the existing deficiencies in our financial
reporting process and will improve our disclosure controls and
procedures and our internal controls over financial reporting.
However, we cannot yet assert that the remediation is or will be
effective as we have not yet had sufficient time to test the
newly implemented actions. We are in the process of documenting
and testing our internal control procedures in order to satisfy
the requirements of Section 404 of the Sarbanes-Oxley Act,
which requires annual management assessments of the
effectiveness of our internal controls over financial reporting
and a report by our independent auditors addressing these
assessments. We have also retained the services of an
independent consultant to assist us with the documenting and
testing process. During the course of our testing we may
identify deficiencies and/or one or more material weaknesses in
our internal controls over financial reporting, which we may not
be able to remediate in time to meet the deadline imposed by SEC
rules under the Sarbanes-Oxley Act for compliance with the
requirements of Section 404.
Likewise, during the course of our integration of any acquired
business (including DLS), we may identify needed improvements to
our or such acquired business internal controls and may be
required to design enhanced processes and controls in order to
make such improvements. This could result in significant delays
and costs to us and could require us to divert substantial
resources, including management time, from other activities.
If we fail to achieve and maintain the adequacy of our
disclosure controls and procedures and/or our internal controls,
as such standards are modified, supplemented or amended from
time to time, we may not be able to conclude that we have
effective disclosure controls and procedures and/or effective
internal controls over financial reporting in accordance with
Section 404 of the Sarbanes-Oxley Act. If:
|
|
|
|
|
we are not successful in improving our financial reporting
process, our disclosure controls and procedures and/or our
internal controls over financial reporting; |
|
|
|
we identify deficiencies and/or one or more material weaknesses
in our internal controls over financial reporting; or |
|
|
|
we are not successful in integrating acquired businesses (such
as DLS) into our consolidated companys system of
disclosure controls and procedures and internal controls over
financial reporting, |
then our independent registered public accounting firm may be
unable to attest that our managements assessment of our
internal controls over financial reporting is fairly stated, or
they may be unable to express an opinion on our
managements evaluation of, or on the effectiveness of, our
internal controls.
If it is determined that our disclosure controls and procedures
and/or our internal controls over financial reporting are not
effective and/or we fail to satisfy the requirements of
Section 404 of the Sarbanes-Oxley Act on a timely basis, we
may not be able to provide reliable financial and other reports
16
or prevent fraud, which, in turn, could harm our business and
operating results, cause investors to lose confidence in the
accuracy and completeness of our financial reports, have a
material adverse effect on the trading price of our common stock
and/or adversely affect our ability to timely file our periodic
reports with the SEC. Any failure to timely file our periodic
reports with the SEC may give rise to a default under the
indenture governing the notes and, ultimately, an acceleration
of amounts due under the notes. In addition, a default under the
indenture generally will also give rise to a default under our
credit agreement and could cause the acceleration of amounts due
under the credit agreement. If an acceleration of the notes or
our other debt were to occur, we cannot assure you that we would
have sufficient funds to repay such obligations.
|
|
|
The loss of key executives
would adversely affect our ability to effectively finance and
manage our business, acquire new businesses, and obtain and
retain customers. |
We are dependent upon the efforts and skills of our executives
to finance and manage our business, identify and consummate
additional acquisitions and obtain and retain customers. These
executives include:
|
|
|
|
|
Chairman of the Board and Chief Executive Officer Munawar H.
Hidayatallah; and |
|
|
|
President and Chief Operating Officer David Wilde. |
In addition, our development and expansion will require
additional experienced management and operations personnel. No
assurance can be given that we will be able to identify and
retain these employees. The loss of the services of one or more
of our key executives could increase our exposure to the other
risks described in this Risk Factors section. We do
not maintain key man insurance on any of our personnel.
|
|
|
Historically, we have been
dependent on a few customers operating in a single industry; the
loss of one or more customers could adversely affect our
financial condition and results of operations. |
Our customers are engaged in the oil and natural gas drilling
business in the United States, Mexico and elsewhere.
Historically, we have been dependent upon a few customers for a
significant portion of our revenue. In 2005, no single customer
generated over 10% of our revenues. In 2004, Matyep represented
10.8% of our revenues, and Burlington Resources represented
10.1% of our revenues. In 2003, Matyep represented 10.2% of our
revenues, Burlington represented 11.1% of our revenue and
El Paso Corporation represented 14.1% of our revenues.
Additionally, DLS currently relies on two customers for a
majority of its revenue. In 2005, Pan American Energy LLC
Sucursal Argentina, or Pan American Energy, represented 55% of
DLS revenues and Repsol-YPF represented 15% of DLS
revenues. This concentration of customers may increase our
overall exposure to credit risk, and customers will likely be
similarly affected by changes in economic and industry
conditions. Our financial condition and results of operations
will be materially adversely affected if one or more of our
significant customers fails to pay us or ceases to contract with
us for our services on terms that are favorable to us or at all.
|
|
|
Our international operations
may expose us to political and other uncertainties, including
risks of: |
|
|
|
|
|
terrorist acts, war and civil disturbances; |
|
|
|
changes in laws or policies regarding the award of
contracts; and |
|
|
|
the inability to collect or repatriate currency, income, capital
or assets. |
17
Part of our strategy is to prudently and opportunistically
acquire businesses and assets that complement our existing
products and services, and to expand our geographic footprint.
If we make acquisitions in other countries, we may increase our
exposure to the risks discussed above.
|
|
|
Environmental liabilities
could result in substantial losses. |
Since our reorganization under the U.S. federal bankruptcy
laws in 1988, a number of parties, including the Environmental
Protection Agency, have asserted that we are responsible for the
cleanup of hazardous waste sites with respect to our
pre-bankruptcy activities. We believe that such claims are
barred by applicable bankruptcy law, and we have not experienced
any material expense in relation to any such claims. However, if
we do not prevail with respect to these claims in the future, or
if additional environmental claims are asserted against us
relating to our current or future activities in the oil and
natural gas industry, we could become subject to material
environmental liabilities that could have a material adverse
effect on our financial condition and results of operation.
|
|
|
Products liability claims
relating to discontinued operations could result in substantial
losses. |
Since our reorganization under the U.S. federal bankruptcy
laws in 1988, we have been regularly named in products liability
lawsuits primarily resulting from the manufacture of products
containing asbestos. In connection with our bankruptcy, a
special products liability trust was established to address
products liability claims. We believe that claims against us are
barred by applicable bankruptcy law, and that the products
liability trust will continue to be responsible for products
liability claims. Since 1988, no court has ruled that we are
responsible for products liability claims. However, if we are
held responsible for product liability claims, we could suffer
substantial losses that could have a material adverse effect on
our financial condition and results of operation. We have not
manufactured products containing asbestos since our
reorganization in 1988.
|
|
|
We may be subject to claims
for personal injury and property damage, which could materially
adversely affect our financial condition and results of
operations. |
Our products and services are used for the exploration and
production of oil and natural gas. These operations are subject
to inherent hazards that can cause personal injury or loss of
life, damage to or destruction of property, equipment, the
environment and marine life, and suspension of operations.
Litigation arising from an accident at a location where our
products or services are used or provided may cause us to be
named as a defendant in lawsuits asserting potentially large
claims. We maintain customary insurance to protect our business
against these potential losses. Our insurance has deductibles or
self-insured retentions and contains certain coverage
exclusions. However, we could become subject to material
uninsured liabilities that could have a material adverse effect
on our financial condition and results of operation.
Risks Associated With Our Industry
|
|
|
Cyclical declines in oil and
natural gas prices may result in reduced use of our services,
affecting our business, financial condition and results of
operation and our ability to meet our capital expenditure
obligations and financial commitments. |
The oil and natural gas exploration and drilling business is
highly cyclical. Generally, as oil and natural gas prices
decrease, exploration and drilling activity declines as
marginally profitable projects become uneconomic and are either
delayed or eliminated. Declines in the number of operating
drilling rigs result in reduced use of and prices for our
services. Accordingly, when oil and natural gas prices
18
are relatively low, our revenues and income will suffer. Oil and
natural gas prices depend on many factors beyond our control,
including the following:
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economic conditions in the United States and elsewhere; |
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changes in global supply and demand for oil and natural gas; |
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the level of production of the Organization of Petroleum
Exporting Countries, commonly called OPEC; |
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the level of production of non-OPEC countries; |
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the price and quantity of imports of foreign oil and natural gas; |
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political conditions, including embargoes, in or affecting other
oil and natural gas producing activities; |
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the level of global oil and natural gas inventories; and |
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advances in exploration, development and production technologies. |
Depending on the market prices of oil and natural gas, companies
exploring for oil and natural gas may cancel or curtail their
drilling programs, thereby reducing demand for drilling
services. Our contracts are generally short-term, and oil and
natural gas companies tend to respond quickly to upward or
downward changes in prices. Any reduction in the demand for
drilling services may materially erode both pricing and
utilization rates for our services and adversely affect our
financial results. As a result, we may suffer losses, be unable
to make necessary capital expenditures and be unable to meet our
financial obligations.
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Our industry is highly
competitive, with intense price competition. |
The markets in which we operate are highly competitive.
Contracts are traditionally awarded on a competitive bid basis.
Pricing is often the primary factor in determining which
qualified contractor is awarded a job. The competitive
environment has intensified as recent mergers among oil and
natural gas companies have reduced the number of available
customers. Many other oilfield services companies are larger
than we are and have resources that are significantly greater
than our resources. These competitors are better able to
withstand industry downturns, compete on the basis of price and
acquire new equipment and technologies, all of which could
affect our revenues and profitability. These competitors compete
with us both for customers and for acquisitions of other
businesses. This competition may cause our business to suffer.
We believe that competition for contracts will continue to be
intense in the foreseeable future.
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We may experience increased
labor costs or the unavailability of skilled workers and the
failure to retain key personnel could hurt our
operations. |
Companies in our industry, including us, are dependent upon the
available labor pool of skilled employees. We compete with other
oilfield services businesses and other employers to attract and
retain qualified personnel with the technical skills and
experience required to provide our customers with the highest
quality service. We are also subject to the Fair Labor Standards
Act, which governs such matters as minimum wage, overtime and
other working conditions. A shortage in the labor pool of
skilled workers or other general inflationary pressures or
changes in applicable laws and regulations could make it more
difficult for us to attract and retain personnel and could
require us to enhance our wage and benefits packages. There can
be no assurance that labor costs will not increase. Any increase
in our operating costs could cause our business to suffer.
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Severe weather could have a
material adverse impact on our business. |
Our business could be materially and adversely affected by
severe weather. Repercussions of severe weather conditions may
include:
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curtailment of services; |
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weather-related damage to facilities and equipment resulting in
suspension of operations; |
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inability to deliver materials to job sites in accordance with
contract schedules; and |
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loss of productivity. |
In addition, oil and natural gas operations of our customers
located offshore and onshore in the Gulf of Mexico and in Mexico
may be adversely affected by hurricanes and tropical storms,
resulting in reduced demand for our services. Further, our
customers operations in the Mid-Continent and Rocky
Mountain regions of the United States are also adversely
affected by seasonal weather conditions. This limits our access
to these job sites and our ability to service wells in these
areas. These constraints decrease drilling activity and the
resulting shortages or high costs could delay our operations and
materially increase our operating and capital costs.
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Our business may be affected
by terrorist activity and by security measures taken in response
to terrorism. |
We may experience loss of business or delays or defaults in
payments from payers that have been affected by actual or
potential terrorist activities. Some oil and natural gas
drilling companies have implemented security measures in
response to potential terrorist activities, including access
restrictions, that could adversely affect our ability to market
our services to new and existing customers and could increase
our costs. Terrorist activities and potential terrorist
activities and any resulting economic downturn could adversely
impact our results of operations, impair our ability to raise
capital or otherwise adversely affect our ability to grow our
business.
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We are subject to government
regulations. |
We are subject to various federal, state and local laws and
regulations relating to the energy industry in general and the
environment in particular. Environmental laws have in recent
years become more stringent and have generally sought to impose
greater liability on a larger number of potentially responsible
parties. Although we are not aware of any proposed material
changes in any federal, state and local statutes, rules or
regulations, any changes could materially affect our financial
condition and results of operations.
Risks Associated with the Notes and Our Indebtedness
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We are a holding company, and
as a result we are dependent on dividends from our subsidiaries
to meet our obligations, including with respect to the
notes. |
We are a holding company and do not conduct any business
operations of our own. Our principal assets are the equity
interests we own in our operating subsidiaries, either directly
or indirectly. As a result, we are dependent upon cash
dividends, distributions or other transfers we receive from our
subsidiaries in order to make dividend payments to our
stockholders, to repay any debt we may incur, and to meet our
other obligations. The ability of our subsidiaries to pay
dividends and make payments to us will depend on their operating
results and may be restricted by, among other things, applicable
corporate, tax and other laws and regulations and agreements of
those subsidiaries, as well as by the terms of our credit
agreement and the indenture governing the notes. For example,
the corporate laws of
20
some jurisdictions prohibit the payment of dividends by any
subsidiary unless the subsidiary has a capital surplus or net
profits in the current or immediately preceding fiscal year.
Payments or distributions from our subsidiaries also could be
subject to restrictions on dividends or repatriation of earnings
under applicable local law, and monetary transfer restrictions
in the jurisdictions in which our subsidiaries operate. Our
subsidiaries are separate and distinct legal entities. Any right
that we have to receive any assets of or distributions from any
subsidiary upon its bankruptcy, dissolution, liquidation or
reorganization, or to realize proceeds from the sale of the
assets of any subsidiary, will be junior to the claims of that
subsidiarys creditors, including trade creditors.
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We have a substantial amount
of debt, which could adversely affect our financial health and
prevent us from making principal and interest payments on the
notes. |
After giving pro forma as adjusted effect to the DLS
transactions, as if each such transaction had occurred on
June 30, 2006, we would have had approximately
$269.6 million of consolidated total indebtedness
outstanding and approximately $11.7 million of additional
secured borrowing capacity available under our credit agreement
as of June 30, 2006.
Our substantial debt could have important consequences to you.
For example, it could:
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make it more difficult for us to satisfy our obligations with
respect to the notes and our other debt; |
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increase our vulnerability to general adverse economic and
industry conditions, including declines in oil and natural gas
prices and declines in drilling activities; |
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limit our ability to obtain additional financing for future
working capital, capital expenditures, mergers and other general
corporate purposes; |
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require us to dedicate a substantial portion of our cash flow
from operations to payments on our debt, thereby reducing the
availability of our cash flow for operations and other purposes; |
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limit our flexibility in planning for, or reacting to, changes
in our business and the industry in which we operate; |
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make us more vulnerable to increases in interest rates; |
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place us at a competitive disadvantage compared to our
competitors that have less debt; and |
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have a material adverse effect on us if we fail to comply with
the covenants in the indenture relating to the notes or in the
instruments governing our other debt. |
In addition, we may incur substantial additional debt in the
future. The indenture governing the notes permits us to incur
additional debt, and our credit agreement permits additional
borrowings. If new debt is added to our current debt levels,
these related risks could increase.
We may not maintain sufficient revenues to sustain profitability
or to meet our capital expenditure requirements and our
financial obligations. Also, we may not be able to generate a
sufficient amount of cash flow to meet our debt service
obligations.
Our ability to make scheduled payments or to refinance our
obligations with respect to our debt will depend on our
financial and operating performance, which, in turn, is subject
to prevailing economic conditions and to certain financial,
business, and other factors beyond our control. If our cash flow
and capital resources are insufficient to fund our debt service
obligations, we may be forced to reduce or delay scheduled
expansion and capital expenditures, sell material assets or
operations, obtain additional capital or restructure our debt.
We cannot assure you that our operating performance, cash
21
flow and capital resources will be sufficient for payment of our
debt in the future. In the event that we are required to dispose
of material assets or operations or restructure our debt to meet
our debt service and other obligations, we cannot assure you
that the terms of any such transaction would be satisfactory to
us or if or how soon any such transaction could be completed.
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If we fail to obtain
additional financing, we may be unable to refinance our existing
debt, expand our current operations or acquire new businesses,
which could result in a failure to grow or result in defaults in
our obligations under our credit agreement or the
notes. |
In order to refinance indebtedness, expand existing operations
and acquire additional businesses, we will require substantial
amounts of capital. There can be no assurance that financing,
whether from equity or debt financings or other sources, will be
available or, if available, will be on terms satisfactory to us.
If we are unable to obtain such financing, we will be unable to
acquire additional businesses and may be unable to meet our
obligations under our credit agreement or the notes.
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The indenture governing the
notes and our credit agreement impose restrictions on us that
may limit the discretion of management in operating our business
and that, in turn, could impair our ability to meet our
obligations under the notes. |
The indenture governing the notes and our credit agreement
contain various restrictive covenants that limit
managements discretion in operating our business. In
particular, these covenants limit our ability to, among other
things:
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incur additional debt; |
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make certain investments or pay dividends or distributions on
our capital stock or purchase or redeem or retire capital stock; |
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sell assets, including capital stock of our restricted
subsidiaries; |
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restrict dividends or other payments by restricted subsidiaries; |
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create liens; |
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enter into transactions with affiliates; and |
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merge or consolidate with another company. |
The credit agreement also requires us to maintain specified
financial ratios and satisfy certain financial tests. Our
ability to maintain or meet such financial ratios and tests may
be affected by events beyond our control, including changes in
general economic and business conditions, and we cannot assure
you that we will maintain or meet such ratios and tests or that
the lenders under the credit agreement will waive any failure to
meet such ratios or tests.
These covenants could materially and adversely affect our
ability to finance our future operations or capital needs.
Furthermore, they may restrict our ability to expand, to pursue
our business strategies and otherwise to conduct our business.
Our ability to comply with these covenants may be affected by
circumstances and events beyond our control, such as prevailing
economic conditions and changes in regulations, and we cannot
assure you that we will be able to comply with them. A breach of
these covenants could result in a default under the indenture
governing the notes and/or the credit agreement. If there were
an event of default under the indenture governing the notes
and/or the credit agreement, the affected creditors could cause
all amounts borrowed under these instruments to be due and
payable immediately. Additionally, if we fail to repay
indebtedness under our credit agreement when it becomes due, the
lenders under the credit agreement could proceed against the
assets which we have pledged to
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them as security. Our assets and cash flow might not be
sufficient to repay our outstanding debt in the event of a
default.
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The notes and the related
guarantees are unsecured and effectively subordinated to our and
the subsidiary guarantors secured indebtedness. |
The notes and the related guarantees are not secured. Our
obligations under the credit agreement are secured by
substantially all of our assets. If we become insolvent or are
liquidated, or if payment under the credit agreement or any of
our other future secured debt obligations is accelerated, the
lenders under our credit agreement would be entitled to exercise
the remedies available to a secured lender under applicable law
and the terms of our credit agreement and will have a claim on
the assets secured thereby before the holders of the notes. The
notes are therefore effectively subordinated to our existing and
future secured indebtedness and the guarantees are effectively
subordinated to the existing and future secured indebtedness of
the subsidiary guarantors, in each case to the extent of the
value of the assets securing that indebtedness. As a result, the
holders of the notes may recover ratably less than the lenders
of our or the subsidiary guarantors secured debt in the
event of a bankruptcy or liquidation.
As of June 30, 2006, after giving effect to the DLS
transactions, as if each such transaction had occurred on that
date, we (not including our subsidiaries) would have had
$130,000 of secured indebtedness outstanding and approximately
$11.7 million of additional secured borrowing capacity
available under our credit agreement, and the subsidiary
guarantors would have had an aggregate of approximately
$267.3 million of total indebtedness outstanding,
approximately $3.1 million of which would have been secured
indebtedness.
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Federal and state statutes
allow courts, under specific circumstances, to void guarantees
and require note holders to return payments received from
guarantors. |
Under U.S. federal bankruptcy law and comparable provisions
of state fraudulent transfer laws, a guarantee could be voided,
or claims in respect of a guarantee could be subordinated to all
other debts of that guarantor if, among other things, the
guarantor, at the time it incurred the indebtedness evidenced by
its guarantee:
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received less than reasonably equivalent value or fair
consideration for the incurrence of such guarantee; and |
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was insolvent or rendered insolvent by reason of such
incurrence; or |
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was engaged in a business or transaction for which the
guarantors remaining assets constituted unreasonably small
capital; or |
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intended to incur, or believed that it would incur, debts beyond
its ability to pay such debts as they mature. |
In addition, any payment by that guarantor pursuant to its
guarantee could be voided and required to be returned to the
guarantor, or to a fund for the benefit of the creditors of the
guarantor. In any such case, your right to receive payments in
respect of the notes from any such guarantor would be
effectively subordinated to all indebtedness and other
liabilities of that guarantor.
The measures of insolvency for purposes of these fraudulent
transfer laws will vary depending upon the law applied in any
proceeding to determine whether a fraudulent transfer has
occurred. Generally, however, a guarantor would be considered
insolvent if:
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the sum of its debts, including contingent liabilities, was
greater than the fair saleable value of all of its assets; or |
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if the present fair saleable value of its assets was less than
the amount that would be required to pay its probable liability
on its existing debts, including contingent liabilities, as they
become absolute and mature; or |
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it could not pay its debts as they become due. |
On the basis of historical financial information, recent
operating history and other factors, we believe that each
guarantor, after giving effect to its guarantee of these notes,
will not be insolvent, will not have unreasonably small capital
for the business in which it is engaged and will not have
incurred debts beyond its ability to pay such debts as they
mature. We cannot assure you, however, as to what standard a
court would apply in making these determinations or that a court
would agree with our conclusions in this regard.
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Your right to receive
payments on the notes will be effectively subordinated to the
rights of creditors of our subsidiaries that do not guarantee
the notes (such as DLS and its subsidiaries) or whose guarantees
are invalidated. |
All of our current domestic subsidiaries will guarantee the
notes. However, creditors of foreign subsidiaries (such as DLS
and its subsidiaries) or other subsidiaries that do not
guarantee the notes will have claims, with respect to the assets
of those subsidiaries, that rank effectively senior to the
notes. In the event of any distribution or payment of assets of
such subsidiaries in any dissolution, winding up, liquidation,
reorganization or other bankruptcy proceeding, the claims of
those creditors must be satisfied prior to making any such
distribution or payment to Allis-Chalmers in respect of its
direct or indirect equity interests in such subsidiaries.
Accordingly, after satisfaction of the claims of such creditors,
there may be little or no amounts left available to make
payments in respect of the notes. Also, as described above,
there are federal and state laws that could invalidate the
guarantees of our subsidiaries that guarantee the notes. If that
were to occur, the claims of creditors of those subsidiaries
would also rank effectively senior to the notes, to the extent
of the assets of those subsidiaries.
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We may not be able to finance
a change of control offer required by the indenture governing
the notes. |
If we were to experience a change of control, the indenture
governing the notes will require us to offer to purchase all the
notes then outstanding at 101% of their principal amount, plus
unpaid accrued interest to the date of repurchase. If a change
of control were to occur, we cannot assure you that we would
have sufficient funds to purchase the notes. In addition, our
credit agreement restricts our ability to repurchase the notes,
even when we are required to do so by the indenture in
connection with a change of control. A change in control could
therefore result in a default under the credit agreement and
could cause the acceleration of our debt. The inability to repay
such debt, if accelerated, and to purchase all of the tendered
notes following a change of control, would constitute an event
of default under the indenture.
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A financial failure by any
subsidiary may hinder payment on the notes, as well as the
enforcement of remedies under any subsidiary
guarantees. |
An investment in the notes, as in any type of security, involves
insolvency and bankruptcy considerations that investors should
carefully consider. If any of the subsidiary guarantors
subsequently becomes a debtor subject to insolvency proceedings
under the bankruptcy code, it is likely to result in delays in
the payment of the notes and in the exercise of enforcement
remedies under the notes or any subsidiary guarantees.
Provisions under the bankruptcy code or general principles of
equity that could result in the impairment of your rights
include the automatic stay, avoidance of preferential transfers
by
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a trustee or a debtor-in-possession, limitations of
collectability of unmatured interest or attorneys fees and
forced restructuring of the notes.
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If an active trading market
does not develop for these notes you may not be able to resell
them. |
Although the issuance of the new notes will be registered under
the Securities Act, the new notes will constitute a new issue of
securities with no established trading market. We cannot assure
you that an active trading market will develop. If no active
trading market develops, you may not be able to resell your new
notes at their fair market value or at all. Future trading
prices of the new notes will depend on many factors, including,
among other things, prevailing interest rates, our operating
results and the market for similar securities. We do not intend
to apply to list the new notes on any securities exchange or
arrange for quotation on any automated dealer quotation system.
Risks Associated With DLS Business and Industry
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A material or extended
decline in expenditures by oil and gas companies due to a
decline or volatility in oil and gas prices, a decrease in
demand for oil and gas or other factors may reduce demand for
DLS services and substantially reduce DLS revenues,
profitability, cash flows and/or liquidity. |
The profitability of DLS operations depends upon
conditions in the oil and gas industry and, specifically, the
level of exploration and production expenditures of oil and gas
company customers. The oil and gas industry is cyclical and
subject to governmental price controls. The demand for contract
drilling and related services is directly influenced by many
factors beyond DLS control, including:
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oil and gas prices and expectations about future prices; |
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the demand for oil and gas, both in Latin America and globally; |
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the cost of producing and delivering oil and gas; |
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advances in exploration, development and production technology; |
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government regulations, including governmental imposed commodity
price controls, export controls and renationalization of a
countrys oil and gas industry; |
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local and international political and economic conditions; |
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the ability of OPEC to set and maintain production levels and
prices; |
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the level of production by non-OPEC countries; and |
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the policies of various governments regarding exploration and
development of their oil and gas reserves. |
Depending on the factors outlined above, companies exploring for
oil and gas may cancel or curtail their drilling programs,
thereby reducing demand for drilling services. Such a reduction
in demand may erode daily rates and utilization of DLS
rigs. Any significant decrease in daily rates or utilization of
DLS rigs could materially reduce DLS revenues,
profitability, cash flows and/or liquidity.
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A majority of DLS
revenues are derived from two customers. The termination of the
contracts with these two customers could have a significant
negative effect on the revenues, results of operations and
financial condition of DLS. |
A majority of DLS revenues are currently received pursuant
to a strategic agreement with Pan American Energy. Pan American
Energy is a joint venture that is owned 60% by British Petroleum
and 40% by Bridas Corporation, an affiliate of the current
stockholders of DLS. This agreement terminates on June 30,
2008. However, Pan American Energy may terminate the agreement
(i) without cause at any time with 60 days
notice, or (ii) in the event of a breach of the agreement
by DLS if such breach is not
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cured within 20 days of notice of the breach. DLS is
currently in negotiations to extend this agreement to December
2010.
In addition, DLS derives over 10% of its revenues from
Repsol-YPF pursuant to a drilling equipment contract and a
drilling fluids contract, both of which are scheduled to expire
in September 2006. We cannot assure you that these contracts
will be renewed or replaced, and consequently there is a risk
that DLS could fail to continue receiving the significant
revenues generated under these contracts.
Because a majority of DLS revenues are currently generated
under these agreements, DLS revenues and earnings will be
materially adversely affected if these agreements are terminated
unless DLS is able to enter into satisfactory substitute
arrangements. We cannot assure you that in the event of such a
termination DLS would be able to enter into substitute
arrangements on terms similar to those contained in the current
agreements with Pan American Energy and Repsol-YPF.
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DLS operations and
financial condition could be affected by union activity and
general labor unrest. Additionally, DLS labor expenses
could increase as a result of governmental regulation of
payments to employees. |
In Argentina, labor organizations have substantial support and
have considerable political influence. The demands of labor
organizations have increased in recent years as a result of the
general labor unrest and dissatisfaction resulting from the
disparity between the cost of living and salaries in Argentina
as a result of the devaluation of the Argentine peso. There can
be no assurance that DLS will not face labor disruptions in the
future or that any such disruptions will not have a material
adverse effect on DLS financial condition or results of
operations.
The Argentine government has in the past and may in the future
promulgate laws, regulations and decrees requiring companies in
the private sector to maintain minimum wage levels and provide
specified benefits to employees, including significant mandatory
severance payments. In the aftermath of the Argentine economic
crisis of 2001 and 2002, both the government and private sector
companies have experienced significant pressure from employees
and labor organizations relating to wage levels and employee
benefits. In early 2005 the Argentine government promised not to
order salary increases by decree. However, there has been no
abatement of pressure to mandate salary increases, and it is
possible the government will adopt measures that will increase
salaries or require DLS to provide additional benefits, which
would increase DLS costs and potentially reduce DLS
profitability, cash flow and/or liquidity.
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Rig upgrade, refurbishment
and construction projects are subject to risks, including delays
and cost overruns, which could have an adverse effect on
DLS results of operations and cash flows. |
DLS often has to make upgrade and refurbishment expenditures for
its rig fleet to comply with DLS quality management and
preventive maintenance system or contractual requirements or
when repairs are required in response to an inspection by a
governmental authority. DLS may also make significant
expenditures when it moves rigs from one location to another.
Additionally, DLS may make substantial expenditures for the
construction of new rigs. Rig upgrade, refurbishment and
construction projects are subject to the risks of delay or cost
overruns inherent in any large construction project, including
the following:
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shortages of material or skilled labor; |
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unforeseen engineering problems; |
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unanticipated change orders; |
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work stoppages; |
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adverse weather conditions; |
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long lead times for manufactured rig components; |
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unanticipated cost increases; and |
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inability to obtain the required permits or approvals. |
Significant cost overruns or delays could adversely affect
DLS financial condition and results of operations.
Additionally, capital expenditures for rig upgrade,
refurbishment or construction projects could exceed DLS
planned capital expenditures, impairing DLS ability to
service its debt obligations.
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An oversupply of comparable
rigs in the geographic markets in which DLS competes could
depress the utilization rates and dayrates for DLS rigs
and materially reduce DLS revenues and
profitability. |
Utilization rates, which are the number of days a rig actually
works divided by the number of days the rig is available for
work, and dayrates, which are the contract prices customers pay
for rigs per day, are also affected by the total supply of
comparable rigs available for service in the geographic markets
in which DLS competes. Improvements in demand in a geographic
market may cause DLS competitors to respond by moving
competing rigs into the market, thus intensifying price
competition. Significant new rig construction could also
intensify price competition. In the past, there have been
prolonged periods of rig oversupply with correspondingly
depressed utilization rates and dayrates largely due to earlier,
speculative construction of new rigs. Improvements in dayrates
and expectations of longer-term, sustained improvements in
utilization rates and dayrates for drilling rigs may lead to
construction of new rigs. These increases in the supply of rigs
could depress the utilization rates and dayrates for DLS
rigs and materially reduce DLS revenues and profitability.
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Worldwide political and
economic developments may hurt DLS operations
materially. |
Currently, DLS derives substantially all of its revenues from
operations in Argentina and a small portion from operations in
Bolivia. DLS operations are subject to the following
risks, among others:
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expropriation of assets; |
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nationalization of components of the energy industry in the
geographic areas where DLS operates; |
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foreign currency fluctuations and devaluation; |
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new economic and tax policies; |
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restrictions on currency, income, capital or asset repatriation; |
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political instability, war and civil disturbances; |
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uncertainty or instability resulting from armed hostilities or
other crises in the Middle East or the geographic areas in which
DLS operates; and |
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acts of terrorism. |
Continued hostilities in the Middle East and the occurrence or
threat of future terrorist attacks against the United States or
other developed countries could cause a downturn in the
economies of the United States and those other countries. A
lower level of economic activity could result in a decline in
energy consumption, which could cause DLS revenues and
margins to decline and limit its future growth prospects. More
specifically, these risks could lead to increased volatility in
prices for crude oil and natural gas and could affect the
markets for DLS drilling services. In addition, these
risks could increase instability in the financial and insurance
markets and make it more difficult for DLS to access
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capital and to obtain insurance coverages that DLS considers
adequate or are otherwise required by DLS contracts.
DLS attempts to limit the risks of currency fluctuation and
restrictions on currency repatriation where possible by
obtaining contracts providing for payment of a percentage of the
contract in U.S. dollars or freely convertible foreign
currency. To the extent possible, DLS seeks to limit its
exposure to local currencies by matching the acceptance of local
currencies to DLS expense requirements in those
currencies. Although DLS has done this in the past, DLS may not
be able to take these actions in the future, thereby exposing
DLS to foreign currency fluctuations that could cause its
results of operations, financial condition and cash flows to
deteriorate materially.
Over the past several years, Argentina and Bolivia have
experienced political and economic instability that resulted in
significant changes in their general economic policies and
regulations.
DLS derives a small portion of its revenues from operating one
drilling rig in Bolivia. Recently, Bolivian President Evo
Morales announced the nationalization of Bolivias natural
gas industry and ordered the Bolivian military to occupy
Bolivias natural gas fields. This measure will likely
adversely affect the Bolivian operations of foreign oil and gas
companies operating in Bolivia, including DLS customers
and potential future customers, and accordingly, DLS
prospects for future business in Bolivia may be harmed. In
addition, in light of these recent political developments in
Bolivia, DLS assets in Bolivia may be subject to an
increased risk of expropriation or government imposed
restrictions on movement to a new location.
In light of the early stage and uncertainty of political
developments affecting the energy industry in Bolivia, we are
unable to predict the effect that recent events may have on
DLS operations, financial results or business plans. There
is a risk that the changes resulting from the recent events in
Bolivia will adversely affect DLS financial position or
results of operations, and DLS operations may be further
adversely affected by continuing economic and political
instability in Bolivia. Furthermore, if nationalistic measures
similar to those developing in Bolivia were to be adopted in
other countries where DLS may in the future seek drilling
contracts, DLS prospects in such countries may be
adversely affected.
DLS operations are also subject to other risks, including
foreign monetary and tax policies, expropriation,
nationalization and nullification or modification of contracts.
Additionally, DLS ability to compete may be limited by
foreign governmental regulations that favor or require the
awarding of contracts to local contractors or by regulations
requiring foreign contractors to employ citizens of, or purchase
supplies from, a particular jurisdiction. Furthermore, DLS may
face governmentally imposed restrictions from time to time on
its ability to transfer funds.
|
|
|
Devaluation of the Argentine
peso will adversely affect DLS results of
operations. |
The Argentine peso has been subject to significant devaluation
in the past and may be subject to significant fluctuations in
the future. Given the economic and political uncertainties in
Argentina, it is impossible to predict whether, and to what
extent, the value of the Argentine peso may depreciate or
appreciate against the U.S. dollar. We cannot predict how
these uncertainties will affect DLS financial results, but
there is a risk that DLS financial performance could be
adversely affected. Moreover, we cannot predict whether the
Argentine government will further modify its monetary policy
and, if so, what effect any of these changes could have on the
value of the Argentine peso. Such changes could have an adverse
effect on DLS financial condition and results of
operations.
28
|
|
|
Argentina continues to face
considerable political and economic uncertainty. |
Although general economic conditions have shown improvement and
political protests and social disturbances have diminished
considerably since the economic crisis of 2001 and 2002, the
rapid and radical nature of the changes in the Argentine social,
political, economic and legal environment over the past several
years and the absence of a clear political consensus in favor of
any particular set of economic policies have given rise to
significant uncertainties about the countrys economic and
political future. It is currently unclear whether the economic
and political instability experienced over the past several
years will continue and it is possible that, despite recent
economic growth, Argentina may return to a deeper recession,
higher inflation and unemployment and greater social unrest. If
instability persists, there could be a material adverse effect
on DLS results of operations and financial condition.
In the event of further social or political crisis, companies in
Argentina may also face the risk of further civil and social
unrest, strikes, expropriation, nationalization, forced
renegotiation or modification of existing contracts and changes
in taxation policies, including royalty and tax increases and
retroactive tax claims.
In addition, investments in Argentine companies may be further
affected by changes in laws and policies of the United States
affecting foreign trade, taxation and investment.
|
|
|
An increase in inflation
could have a material adverse effect on DLS results of
operations. |
The devaluation of the Argentine peso created pressures on the
domestic price system that generated high rates of inflation in
2002 before substantially stabilizing in 2003 and remaining
stable in 2004. In 2005, however, inflation rates began to
increase. In addition, in response to the economic crisis in
2002, the federal government granted the Central Bank greater
control over monetary policy than was available to it under the
previous monetary regime, known as the
Convertibility regime, including the ability to
print currency, to make advances to the federal government to
cover its anticipated budget deficit and to provide financial
assistance to financial institutions with liquidity problems. We
cannot assure you that inflation rates will remain stable in the
future. Significant inflation could have a material adverse
effect on DLS results of operations and financial
condition.
|
|
|
DLS customers may seek
to cancel or renegotiate some of DLS drilling contracts
during periods of depressed market conditions or if DLS
experiences operational difficulties. |
Substantially all of DLS contracts with major customers
are dayrate contracts, where DLS charges a fixed charge per day
regardless of the number of days needed to drill the well.
During depressed market conditions, a customer may no longer
need a rig that is currently under contract or may be able to
obtain a comparable rig at a lower daily rate. As a result,
customers may seek to renegotiate the terms of their existing
drilling contracts or avoid their obligations under those
contracts. In addition, DLS customers may have the right
to terminate existing contracts if DLS experiences operational
problems. The likelihood that a customer may seek to terminate a
contract for operational difficulties is increased during
periods of market weakness. The cancellation of a number of
DLS drilling contracts could materially reduce DLS
revenues and profitability.
|
|
|
DLS is subject to numerous
governmental laws and regulations, including those that may
impose significant liability on DLS for environmental and
natural resource damages. |
Many aspects of DLS operations are subject to laws and
regulations that may relate directly or indirectly to the
contract drilling and well servicing industries, including those
requiring DLS to control the discharge of oil and other
contaminants into the environment or otherwise relating to
environmental protection. The countries where DLS operates have
environmental laws and regulations covering the
29
discharge of oil and other contaminants and protection of the
environment in connection with operations. Failure to comply
with these laws and regulations may result in the assessment of
administrative, civil and even criminal penalties, the
imposition of remedial obligations, and the issuance of
injunctions that may limit or prohibit DLS operations.
Laws and regulations protecting the environment have become more
stringent in recent years and may in certain circumstances
impose strict liability, rendering DLS liable for environmental
and natural resource damages without regard to negligence or
fault on DLS part. These laws and regulations may expose
DLS to liability for the conduct of, or conditions caused by,
others or for acts that were in compliance with all applicable
laws at the time the acts were performed. The application of
these requirements, the modification of existing laws or
regulations or the adoption of new laws or regulations
curtailing exploratory or development drilling for oil and gas
could materially limit future contract drilling opportunities or
materially increase DLS costs or both.
|
|
|
DLS is subject to hazards
customary for drilling operations, which could adversely affect
its financial performance if DLS is not adequately indemnified
or insured. |
Substantially all of DLS operations are subject to hazards
that are customary for oil and gas drilling operations,
including blowouts, reservoir damage, loss of well control,
cratering, oil and gas well fires and explosions, natural
disasters, pollution and mechanical failure. Any of these risks
could result in damage to or destruction of drilling equipment,
personal injury and property damage, suspension of operations or
environmental damage. Generally, drilling contracts provide for
the division of responsibilities between a drilling company and
its customer, and DLS generally obtains indemnification from its
customers by contract for some of these risks. However, there
may be limitations on the enforceability of indemnification
provisions that allow a contractor to be indemnified for damages
resulting from the contractors fault. To the extent that
DLS is unable to transfer such risks to customers by contract or
indemnification agreements, DLS generally seeks protection
through insurance. However, DLS has a significant amount of
self-insured retention or deductible for certain losses relating
to workers compensation, employers liability,
general liability and property damage. There is no assurance
that such insurance or indemnification agreements will
adequately protect DLS against liability from all of the
consequences of the hazards and risks described above. The
occurrence of an event not fully insured or for which DLS is not
indemnified against, or the failure of a customer or insurer to
meet its indemnification or insurance obligations, could result
in substantial losses. In addition, there can be no assurance
that insurance will continue to be available to cover any or all
of these risks, or, even if available, that insurance premiums
or other costs will not rise significantly in the future, so as
to make the cost of such insurance prohibitive.
Risks Associated with Our Acquisition of DLS
|
|
|
In connection with our
acquisition of DLS, the DLS sellers have the right to designate
two nominees for election to our board of directors, and their
interests may be different from yours. |
The DLS sellers collectively hold 2.5 million shares of our
common stock, representing approximately 10.4% of our issued and
outstanding shares. Under the investors rights agreement that we
entered into in connection with the acquisition, the DLS sellers
have the right to designate two nominees for election to our
board of directors. As a result, the DLS sellers have a greater
ability to determine the composition of our board of directors
and to control our future operations and strategy as compared to
the voting power and control that could be exercised by a
stockholder owning the same number of shares and not benefiting
from board designation rights.
Conflicts of interest between the DLS sellers and the holders of
the notes may arise with respect to sales of shares of capital
stock owned by the DLS sellers or other matters. In addition,
the interests of
30
the DLS sellers regarding any proposed merger or sale may differ
from the interests of the holders of the notes.
The board designation rights described above could also have the
effect of delaying or preventing a change in our control or
otherwise discouraging a potential acquirer from attempting to
obtain control of us, which in turn could have a material and
adverse effect on the market price of the notes and/or our
ability to meet our obligations under the notes.
Risks Associated With Our Recent Common Stock Offering
|
|
|
We may have a contingent
liability arising out of a possible violation of Section 5
of the Securities Act in connection with electronic
communications sent to potential investors in our common
stock. |
On or about July 20, 2006, one of the proposed underwriters
of our recent common stock offering (which closed on
August 14, 2006) sent e-mails and/or instant messages to
approximately 20 potential investors in our common stock.
Although we did not authorize these communications, and we
believe they were not made or intended to be made on our behalf,
these communications may have constituted violations of
Section 5 of the Securities Act. Accordingly, if the
recipients of these emails were to purchase shares in our recent
common stock offering, they might have the right, under certain
circumstances, to require us to repurchase those shares.
Consequently, we could have a contingent liability arising out
of these possible violations of the Securities Act. The
magnitude of this liability is presently impossible to quantify,
and would depend upon the number of shares purchased by the
recipients of such communications and the trading price of our
common stock. However, the proposed underwriter who sent these
electronic communications did not act as an underwriter in the
common stock offering, and we and the underwriters that did
participate in the common stock offering took measures designed
to ensure that the recipients of the communications did not have
the opportunity to purchase shares in that offering.
Furthermore, if any investors in our common stock do assert any
such liability, we intend to contest the matter vigorously, and
in light of the remedial measures and our belief that the
communications were not made or intended to be made on our
behalf, we do not believe that any such liability would be
material to our financial condition.
31
USE OF PROCEEDS
The exchange offer is intended to satisfy our obligations under
the registration rights agreements. We will not receive any
proceeds from the issuance of the new notes and have agreed to
pay all expenses of the exchange offer. In exchange for issuing
the new notes, we will receive a like principal amount of old
notes. The old notes surrendered in exchange for the new notes
will be retired and cancelled and will not be reissued.
Accordingly, issuing the new notes will not result in any
increase or decrease in our outstanding debt.
32
UNAUDITED PRO FORMA AS ADJUSTED CONSOLIDATED
FINANCIAL INFORMATION
Introduction
Our unaudited pro forma as adjusted balance sheet as of
June 30, 2006 reflects the following transactions as if
they occurred on June 30, 2006:
|
|
|
|
|
Our recent acquisition of DLS, which closed on August 14,
2006, for the consideration described below under
DLS Business, including the assumption of
$8.6 million of DLS currently existing indebtedness
and the issuance of 2.5 million shares of our common stock
to the sellers, as adjusted for our recent offering of
$95.0 million of 9.0% Senior Notes due 2014 and the sale of
an additional 3.5 million shares of our common stock to
fund a portion of the cash component of the purchase price for
this acquisition. The following table summarizes the preliminary
allocation of the purchase price to the estimated fair value of
the assets acquired and liabilities assumed as if the
acquisition occurred on June 30, 2006 (in thousands): |
|
|
|
|
|
|
Current assets
|
|
$ |
52,651 |
|
Property and equipment
|
|
|
150,851 |
|
Other long-term assets
|
|
|
2 |
|
|
|
|
|
|
Total assets acquired
|
|
|
203,504 |
|
|
|
|
|
Current liabilities
|
|
|
31,968 |
|
Long-term debt
|
|
|
8,614 |
|
Other long term liabilities
|
|
|
27,000 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
67,582 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
135,922 |
|
|
|
|
|
|
|
|
We incurred approximately $4.6 million of acquisition costs
in connection with this acquisition. DLS historical property and
equipment values are expected to be increased by approximately
$42.3 million based on third-party valuations. We do not
expect any material differences from the preliminary allocation
of the purchase price and actual purchase price allocation. |
Our unaudited pro forma as adjusted condensed consolidated
statement of operations for the six months ended June 30,
2006 reflects the following transactions as if such transactions
occurred on January 1, 2005:
|
|
|
|
|
Our acquisition of Rogers, which closed on April 3, 2006.
The following table summarizes the allocation of the purchase
price to the estimated fair value of the assets acquired and
liabilities assumed at the date of acquisition (in thousands): |
|
|
|
|
|
|
Current assets
|
|
$ |
4,520 |
|
Property and equipment
|
|
|
9,886 |
|
Intangible assets
|
|
|
1,131 |
|
|
|
|
|
|
Total assets acquired
|
|
|
15,517 |
|
|
|
|
|
Current liabilities
|
|
|
1,717 |
|
Other long term liabilities
|
|
|
100 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
1,817 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
13,700 |
|
|
|
|
|
|
|
|
We paid the purchase price with $11.3 million in cash (of
which we borrowed $5.0 million under our line of credit), a
$750,000 seller financed note and 125,285 newly issued shares of
our common stock, which had a value of $1.7 million. We
incurred approximately $341,000 of acquisition costs in
connection with the Rogers acquisition. Rogers historical
property and |
33
|
|
|
equipment book values were increased by approximately
$8.4 million based on third-party valuations. Intangible
assets include $981,000 assigned to patents and $150,000
assigned to a non-compete agreement, based on third-party
valuations and an employment contract. The intangibles have a
weighted-average useful life of 11 years. |
|
|
|
|
|
Our recent acquisition of DLS, which closed on August 14,
2006, for the consideration described below under
DLS Business, including the assumption of
$8.6 million of DLS indebtedness and the issuance of
2.5 million shares of our common stock to the sellers; |
|
|
|
The sale of $95.0 million aggregate principal amount of
9.0% senior notes; and |
|
|
|
Our issuance of an additional 3.5 million shares of our
common stock in order to fund a portion of the cash component of
the purchase price for the pending DLS acquisition. The pro
forma treats the shares as having been issued at a price of
$14.50 per share. |
Our unaudited pro forma as adjusted condensed consolidated
statement of operations for the year ended December 31,
2005 reflects the following transactions as if such transactions
occurred on January 1, 2005:
|
|
|
|
|
Our acquisition of Delta Rental Service, Inc., or Delta, which
closed on April 1, 2005. The following table summarizes the
allocation of the purchase price to the estimated fair value of
the assets acquired and liabilities assumed at the date of
acquisition (in thousands): |
|
|
|
|
|
|
Current assets
|
|
$ |
1,327 |
|
Property and equipment
|
|
|
5,529 |
|
Intangible assets
|
|
|
150 |
|
|
|
|
|
|
Total assets acquired
|
|
|
7,006 |
|
|
|
|
|
Current liabilities
|
|
|
633 |
|
Long-term debt
|
|
|
523 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
1,156 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
5,850 |
|
|
|
|
|
|
|
|
We paid the purchase price with approximately $4.5 million
in cash, newly issued shares of our common stock valued at
approximately $1.0 million and two promissory notes
totaling $350,000 in principal amount. We incurred approximately
$28,000 of acquisition costs in connection with the Delta
acquisition. Deltas historical property and equipment book
values were increased by approximately $4.2 million based
on third-party valuations. The fair value of the $150,000
non-compete intangible asset was based on a non-compete
agreement and the related employment contract and has a useful
life of 3 years. |
34
|
|
|
|
|
Our acquisition of Capcoil Tubing Services, Inc., or Capcoil,
which closed on May 2, 2005. The following table summarizes
the allocation of the purchase price to the estimated fair value
of the assets acquired and liabilities assumed at the date of
acquisition (in thousands): |
|
|
|
|
|
|
Current assets
|
|
$ |
1,706 |
|
Property and equipment
|
|
|
2,908 |
|
Other long-term assets
|
|
|
11 |
|
Intangible assets
|
|
|
1,389 |
|
Goodwill
|
|
|
184 |
|
|
|
|
|
|
Total assets acquired
|
|
|
6,198 |
|
|
|
|
|
Current liabilities
|
|
|
847 |
|
Long-term debt
|
|
|
1,851 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
2,698 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
3,500 |
|
|
|
|
|
|
|
|
We paid the purchase price with approximately $2.7 million
in cash and newly issued shares of our common stock valued at
approximately $750,000. We incurred approximately $26,000 of
acquisition costs in connection with the Capcoil acquisition.
Capcoils historical property and equipment book values
were increased by approximately $1.0 million based on
third-party valuations. Intangible assets include
$1.0 million assigned to non-compete agreements included in
employment contracts and $364,000 assigned to customer lists
based on third-party valuations. The intangibles have a
weighted-average useful life of 5 years. |
|
|
|
|
|
Our acquisition of the assets of W.T. Enterprises, Inc., or
W.T., which closed on July 11, 2005. The following table
summarizes the allocation of the purchase price to the estimated
fair value of the assets acquired at the date of acquisition (in
thousands): |
|
|
|
|
|
|
Property and equipment
|
|
$ |
4,500 |
|
Intangible assets
|
|
|
1,481 |
|
Goodwill
|
|
|
82 |
|
|
|
|
|
|
Total assets acquired
|
|
$ |
6,063 |
|
|
|
|
|
|
|
|
We paid the purchase price with borrowings under our line of
credit. We incurred approximately $63,000 of acquisition costs
in connection with the W.T. acquisition. W.T.s historical
property and equipment book values were increased by
approximately $3.0 million based on third-party valuations.
Intangible assets include $600,000 assigned to non-compete
agreements and $881,000 assigned to customer lists based on
third-party valuations. The intangibles have a weighted-average
useful life of 8 years. |
|
|
|
|
|
Our acquisition of the minority interest in AirComp LLC, or
AirComp, from M-I LLC,
or M-I, and a
subordinated note in the principal amount of $4.8 million,
which closed on July 11, 2005. We paid the purchase price
with $7.1 million in cash from borrowings under our line of
credit and the issuance of a new $4.0 million 5%
subordinated note. |
35
|
|
|
|
|
Our acquisition of Specialty, which closed on January 18,
2006. The following table summarizes the allocation of the
purchase price to the estimated fair value of the assets
acquired and liabilities assumed at the date of acquisition (in
thousands): |
|
|
|
|
|
|
Accounts receivable
|
|
$ |
7,167 |
|
Other current assets
|
|
|
425 |
|
Property and equipment
|
|
|
90,540 |
|
|
|
|
|
|
Total assets acquired
|
|
|
98,132 |
|
|
|
|
|
Current liabilities
|
|
|
2,058 |
|
Long-term debt
|
|
|
74 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
2,132 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
96,000 |
|
|
|
|
|
|
|
|
We paid the purchase price with net proceeds from our issuance
of 9% senior notes in January 2006. We incurred approximately
$453,000 of acquisition costs in connection with the Specialty
acquisition. Specialtys historical property and equipment
book values were increased by approximately $71.5 million
based on third-party valuations. |
|
|
|
|
|
Our issuance of $160.0 million aggregate principal amount
of 9% senior notes in January 2006; |
|
|
|
Our acquisition of Rogers, which closed on April 3, 2006,
for $11.3 million in cash (of which we borrowed
$5.0 million under our debt facility), the issuance of a
$750,000 three year promissory note and the issuance of
125,285 shares of our common stock; |
|
|
|
Our acquisition of DLS for the consideration described below
under DLS Business, including the assumption
of $8.6 million of DLS indebtedness and the issuance
of 2.5 million shares of our common stock to the sellers; |
|
|
|
Our sale of an additional $95.0 million aggregate principal
amount of notes in this offering; and |
|
|
|
Our issuance of an additional 3.5 million shares of our
common stock in order to fund a portion of the cash component of
the purchase price for the DLS acquisition. The pro forma treats
the shares as having been issued at a price of $14.50 per share. |
However, the pro forma as adjusted statement of operations
information presented below does not give effect to our
immaterial acquisition of Target Energy, Inc., which was
acquired effective August 1, 2005, and our acquisition of
certain casing and tubing assets from Patterson Services, Inc.
on September 1, 2005.
Adjustments for the above-listed transactions on an individual
basis are presented in the notes to the unaudited pro forma as
adjusted financial statements.
Certain information normally included in the financial
statements prepared in accordance with GAAP has been condensed
or omitted in accordance with the rules and regulations of the
SEC. The unaudited pro forma as adjusted financial statements
and accompanying notes should be read in conjunction with the
historical financial statements and related notes thereto
appearing elsewhere herein. The unaudited pro forma as adjusted
consolidated condensed financial statements do not purport to be
indicative of the results of operations or financial position
that we actually would have achieved if the transactions had
been consummated on the dates indicated, nor do they project our
results of operations or financial position for any future
period or date.
36
Unaudited Pro Forma As Adjusted Consolidated Balance Sheet
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of June 30, 2006 | |
|
|
(Unaudited) | |
|
|
| |
|
|
|
|
Financing/ | |
|
|
|
|
Allis-Chalmers | |
|
DLS | |
|
Pro Forma | |
|
Offering | |
|
Pro Forma | |
|
|
Historical | |
|
Historical | |
|
Adjustments(1) | |
|
Adjustments(2) | |
|
As Adjusted | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands) | |
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
6,208 |
|
|
$ |
492 |
|
|
$ |
(97,772 |
)AA |
|
$ |
135,236 |
AB |
|
$ |
44,164 |
|
Trade receivables, net
|
|
|
49,114 |
|
|
|
29,244 |
|
|
|
|
|
|
|
|
|
|
|
78,358 |
|
Inventories
|
|
|
9,897 |
|
|
|
16,608 |
|
|
|
|
|
|
|
|
|
|
|
26,505 |
|
Prepaids and other
|
|
|
2,655 |
|
|
|
6,307 |
|
|
|
|
|
|
|
|
|
|
|
8,962 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
67,874 |
|
|
|
52,651 |
|
|
|
(97,772 |
) |
|
|
135,236 |
|
|
|
157,989 |
|
Property and equipment, net
|
|
|
185,750 |
|
|
|
108,593 |
|
|
|
42,258 |
AC |
|
|
|
|
|
|
336,601 |
|
Goodwill
|
|
|
12,417 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
12,417 |
|
Other intangibles, net
|
|
|
7,131 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,131 |
|
Debt issuance costs, net
|
|
|
6,187 |
|
|
|
|
|
|
|
|
|
|
|
2,538 |
AD |
|
|
8,725 |
|
Other assets
|
|
|
1,327 |
|
|
|
2 |
|
|
|
|
|
|
|
|
|
|
|
1,329 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
280,686 |
|
|
$ |
161,246 |
|
|
$ |
(55,514 |
) |
|
$ |
137,774 |
|
|
$ |
524,192 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current maturities of long-term debt
|
|
$ |
4,059 |
|
|
$ |
8,861 |
|
|
$ |
(6,361 |
)AE |
|
$ |
|
|
|
$ |
6,559 |
|
Trade accounts payable
|
|
|
9,616 |
|
|
|
17,270 |
|
|
|
|
|
|
|
|
|
|
|
26,886 |
|
Accrued employee benefits
|
|
|
2,270 |
|
|
|
12,593 |
|
|
|
|
|
|
|
|
|
|
|
14,863 |
|
Accrued interest
|
|
|
6,654 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,654 |
|
Accrued expenses
|
|
|
7,781 |
|
|
|
2,105 |
|
|
|
|
|
|
|
|
|
|
|
9,886 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
30,380 |
|
|
|
40,829 |
|
|
|
(6,361 |
) |
|
|
|
|
|
|
64,848 |
|
Accrued postretirement benefit obligations
|
|
|
319 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
319 |
|
Long-term debt, net of current maturities
|
|
|
165,957 |
|
|
|
17,453 |
|
|
|
(11,339 |
)AE |
|
|
91,000 |
AF |
|
|
263,071 |
|
Other long-term liabilities
|
|
|
749 |
|
|
|
749 |
|
|
|
26,251 |
AG |
|
|
|
|
|
|
27,749 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
197,405 |
|
|
|
59,031 |
|
|
|
8,551 |
|
|
|
91,000 |
|
|
|
355,987 |
|
|
STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock
|
|
|
185 |
|
|
|
42,963 |
|
|
|
(42,938 |
)AH |
|
|
35 |
AI |
|
|
245 |
|
Capital in excess of par value
|
|
|
67,261 |
|
|
|
31,606 |
|
|
|
6,519 |
AH |
|
|
46,739 |
AI |
|
|
152,125 |
|
Retained earnings
|
|
|
15,835 |
|
|
|
27,646 |
|
|
|
(27,646 |
)AH |
|
|
|
|
|
|
15,835 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
83,281 |
|
|
|
102,215 |
|
|
|
(64,065 |
) |
|
|
46,774 |
|
|
|
168,205 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity
|
|
$ |
280,686 |
|
|
$ |
161,246 |
|
|
$ |
(55,514 |
) |
|
$ |
137,774 |
|
|
$ |
524,192 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Reflects adjustments for the acquisition of Rogers and the
acquisition of DLS. |
|
(2) |
Reflects adjustments for the August 2006 offering of
$95.0 million principal amount of notes and the
August 2006 offering and sale of 3,450,000 shares of our
common stock to fund a portion of the cash component of the
purchase price for the acquisition of DLS. |
37
Unaudited Pro Forma Consolidated Statement of Operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Six Months Ended June 30, 2006 | |
|
|
(Unaudited) | |
|
|
| |
|
|
Allis-Chalmers | |
|
DLS | |
|
Rogers | |
|
Pro Forma | |
|
Pro Forma | |
|
Offering | |
|
Pro Forma | |
|
|
Historical | |
|
Historical | |
|
Historical | |
|
Adjustments(1) | |
|
Combined | |
|
Adjustments(2) | |
|
As Adjusted | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except per share amounts) | |
Revenues
|
|
$ |
107,498 |
|
|
$ |
82,019 |
|
|
$ |
2,085 |
|
|
$ |
|
|
|
$ |
191,602 |
|
|
$ |
|
|
|
$ |
191,602 |
|
Cost of revenues
|
|
|
66,239 |
|
|
|
68,490 |
|
|
|
1,105 |
|
|
|
(341 |
)A |
|
|
135,493 |
|
|
|
|
|
|
|
135,493 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
41,259 |
|
|
|
13,529 |
|
|
|
980 |
|
|
|
341 |
|
|
|
56,109 |
|
|
|
|
|
|
|
56,109 |
|
General and administrative expense
|
|
|
16,755 |
|
|
|
2,205 |
|
|
|
820 |
|
|
|
33 |
B |
|
|
19,813 |
|
|
|
158 |
C |
|
|
19,971 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
24,504 |
|
|
|
11,324 |
|
|
|
160 |
|
|
|
308 |
|
|
|
36,296 |
|
|
|
(158 |
) |
|
|
36,138 |
|
Other income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
|
|
|
|
|
|
|
|
2 |
|
|
|
|
|
|
|
2 |
|
|
|
|
|
|
|
2 |
|
|
Interest expense
|
|
|
(7,425 |
) |
|
|
(2,748 |
) |
|
|
|
|
|
|
804 |
D |
|
|
(9,369 |
) |
|
|
(3,976 |
)E |
|
|
(13,345 |
) |
|
Other
|
|
|
20 |
|
|
|
(784 |
) |
|
|
(7 |
) |
|
|
|
|
|
|
(771 |
) |
|
|
|
|
|
|
(771 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before taxes
|
|
|
17,099 |
|
|
|
7,792 |
|
|
|
155 |
|
|
|
1,112 |
|
|
|
26,158 |
|
|
|
(4,134 |
) |
|
|
22,024 |
|
Taxes
|
|
|
(3,081 |
) |
|
|
(3,512 |
) |
|
|
|
|
|
|
303 |
F |
|
|
(6,290 |
) |
|
|
|
F |
|
|
(6,290 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
|
14,018 |
|
|
|
4,280 |
|
|
|
155 |
|
|
|
1,415 |
|
|
|
19,868 |
|
|
|
(4,134 |
) |
|
|
15,734 |
|
Discontinued operations
|
|
|
|
|
|
|
2,375 |
|
|
|
|
|
|
|
|
|
|
|
2,375 |
|
|
|
|
|
|
|
2,375 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income/(loss)
|
|
$ |
14,018 |
|
|
$ |
6,655 |
|
|
$ |
155 |
|
|
$ |
1,415 |
|
|
$ |
22,243 |
|
|
$ |
(4,134 |
) |
|
$ |
18,109 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per common share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
$ |
0.80 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.98 |
|
|
|
|
|
|
$ |
0.67 |
|
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
0.12 |
|
|
|
|
|
|
|
0.10 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.80 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
1.10 |
|
|
|
|
|
|
$ |
0.77 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
$ |
0.74 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.92 |
|
|
|
|
|
|
$ |
0.63 |
|
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
0.11 |
|
|
|
|
|
|
|
0.09 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.74 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
1.03 |
|
|
|
|
|
|
$ |
0.72 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares outstanding
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
17,578 |
|
|
|
|
|
|
|
|
|
|
|
2,563 |
G |
|
|
20,141 |
|
|
|
3,450 |
H |
|
|
23,591 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
19,000 |
|
|
|
|
|
|
|
|
|
|
|
2,563 |
G |
|
|
21,563 |
|
|
|
3,450 |
H |
|
|
25,013 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Reflects adjustments for the acquisition of Rogers and the
acquisition of DLS, including the assumption of $8.6 of
DLS indebtedness and the issuance of 2.5 million
shares of our common stock to the sellers as the stock component
of the purchase price for the DLS acquisition. |
|
(2) |
Reflects adjustments for our $95.0 million notes offering
in August 2006 and the August 2006 offering and sale
of an additional 3,450,000 shares of our common stock to fund a
portion of the cash component of the purchase price for the
acquisition of DLS. |
38
Unaudited Pro Forma As Adjusted Consolidated Statement of
Operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2005 | |
|
|
| |
|
|
|
|
Other | |
|
|
|
|
Allis-Chalmers | |
|
Specialty | |
|
DLS | |
|
Acquisitions(1) | |
|
Pro Forma | |
|
Pro Forma | |
|
Offering | |
|
Pro Forma | |
|
|
Historical | |
|
Historical | |
|
Historical | |
|
Historical | |
|
Adjustments(2) | |
|
Combined | |
|
Adjustments(3) | |
|
As Adjusted | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except per share amounts) | |
Revenues
|
|
$ |
105,344 |
|
|
$ |
32,709 |
|
|
$ |
129,849 |
|
|
$ |
13,415 |
|
|
$ |
|
|
|
$ |
281,317 |
|
|
$ |
|
|
|
$ |
281,317 |
|
Cost of revenues
|
|
|
74,763 |
|
|
|
8,550 |
|
|
|
113,351 |
|
|
|
7,420 |
|
|
|
7,101 |
I |
|
|
211,185 |
|
|
|
|
|
|
|
211, 185 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
30,581 |
|
|
|
24,159 |
|
|
|
16,498 |
|
|
|
5,995 |
|
|
|
(7,101 |
) |
|
|
70,132 |
|
|
|
|
|
|
|
70,132 |
|
General and administrative expense
|
|
|
17,363 |
|
|
|
7,232 |
|
|
|
3,933 |
|
|
|
4,275 |
|
|
|
(145 |
)J |
|
|
32,658 |
|
|
|
1,017 |
K |
|
|
33,675 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
13,218 |
|
|
|
16,927 |
|
|
|
12,565 |
|
|
|
1,720 |
|
|
|
(6,956 |
) |
|
|
37,474 |
|
|
|
(1,017 |
) |
|
|
36,457 |
|
Other income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
|
|
|
|
136 |
|
|
|
|
|
|
|
56 |
|
|
|
|
|
|
|
192 |
|
|
|
|
|
|
|
192 |
|
|
Interest expense
|
|
|
(4,397 |
) |
|
|
(185 |
) |
|
|
(5,394 |
) |
|
|
(54 |
) |
|
|
(6,879 |
)L |
|
|
(16,909 |
) |
|
|
(9,313 |
)M |
|
|
(26,222 |
) |
|
Other
|
|
|
186 |
|
|
|
72 |
|
|
|
7,127 |
|
|
|
353 |
|
|
|
|
|
|
|
7,738 |
|
|
|
|
|
|
|
7,738 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before taxes
|
|
|
9,007 |
|
|
|
16,950 |
|
|
|
14,298 |
|
|
|
2,075 |
|
|
|
(13,835 |
) |
|
|
28,495 |
|
|
|
(10,330 |
) |
|
|
18,165 |
|
Minority interest
|
|
|
(488 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
488 |
N |
|
|
|
|
|
|
|
|
|
|
|
|
Taxes
|
|
|
(1,344 |
) |
|
|
|
|
|
|
(3,547 |
) |
|
|
(340 |
) |
|
|
(1,657 |
)F |
|
|
(6,888 |
) |
|
|
|
F |
|
|
(6,888 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
|
7,175 |
|
|
|
16,950 |
|
|
|
10,751 |
|
|
|
1,735 |
|
|
|
(15,004 |
) |
|
|
21,607 |
|
|
|
(10,330 |
) |
|
|
11,277 |
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
(4,138 |
) |
|
|
|
|
|
|
|
|
|
|
(4,138 |
) |
|
|
|
|
|
|
(4,138 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
7,175 |
|
|
$ |
16,950 |
|
|
$ |
6,613 |
|
|
$ |
1,735 |
|
|
$ |
(15,004 |
) |
|
$ |
17,469 |
|
|
$ |
(10,330 |
) |
|
$ |
7,139 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income (loss) per common share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
$ |
0.48 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
1.23 |
|
|
|
|
|
|
$ |
0.54 |
|
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(0.24 |
) |
|
|
|
|
|
|
(0.20 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.48 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.99 |
|
|
|
|
|
|
$ |
0.34 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
$ |
0.44 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
1.14 |
|
|
|
|
|
|
$ |
0.50 |
|
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(0.22 |
) |
|
|
|
|
|
|
(0.18 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.44 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.92 |
|
|
|
|
|
|
$ |
0.32 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares outstanding
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
14,832 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,742 |
O |
|
|
17,574 |
|
|
|
3,450 |
H |
|
|
21,024 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
16,238 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,742 |
O |
|
|
18,980 |
|
|
|
3,450 |
H |
|
|
22,430 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Acquisitions of Capcoil, Delta, the minority interest of M-I in
AirComp, W.T. and Rogers. |
|
(2) |
Reflects adjustments for the acquisitions described in footnote
(1) and the acquisition of Specialty and the acquisition of
DLS, including the assumption of $8.6 million of DLS
indebtedness and the issuance of 2.5 million shares of our
common stock to the sellers as the stock component of the
purchase price for the DLS acquisition. |
|
(3) |
Reflects adjustments for our $160.0 million notes offering
in January 2006, our $95.0 million notes offering in August
2006 and the August 2006 offering and sale of an additional
3,450,000 shares of our common stock to fund a portion of
the cash component of the purchase price for the acquisition of
DLS. |
39
Notes to Unaudited Pro Forma As Adjusted Consolidated
Condensed Financial Statements
The following pro forma adjustments have been made to the
historical financial statements:
|
|
|
AA) Reflects the cash payment of $93.2 million to
purchase DLS and fees to acquire DLS, which includes
approximately $4.6 million in transaction costs. |
|
|
AB) Reflects the net proceeds from the August 2006 debt and
equity offerings and sale of 3.5 million shares of our
common stock and the repayment of existing debt. |
|
|
AC) Reflects the
step-up in the basis of
the fixed assets as a result of the acquisition of DLS to the
lower of fair market value or actual cost. |
|
|
AD) Fees and expenses related to the sale of
$95.0 million of notes in the August 2006 offering. |
|
|
AE) Reflects the repayment of debt of DLS prior to the
acquisition. |
|
|
AF) Reflects the proceeds from the sale of
$95.0 million of notes after repaying $4.0 million of
existing debt. |
|
|
Maturities of pro forma debt obligations at June 30, 2006
are as follows (in thousands): |
|
|
|
|
|
Period Ending:
|
|
|
|
|
June 30, 2007
|
|
$ |
6,559 |
|
June 30, 2008
|
|
|
3,427 |
|
June 30, 2009
|
|
|
1,418 |
|
June 30, 2010
|
|
|
2,156 |
|
June 30, 2011
|
|
|
1,070 |
|
Thereafter
|
|
|
255,000 |
|
|
|
|
|
Total
|
|
$ |
269,630 |
|
|
|
|
|
|
|
|
AG) Reflects deferred taxes on the DLS acquisition. |
|
|
AH) Reflects the elimination of DLSs
stockholders equity and the issuance of 2.5 million
shares in the DLS acquisition. |
|
|
AI) Reflects the additional stock issued in connection with
the offering, issuance and sale of 3.5 million shares of
our common stock to fund a portion of the cash component of the
purchase price for the DLS acquisition, net of expenses. |
40
|
|
|
A) Reflects the impact on depreciation expense as a result
of the step-up in basis
of fixed assets and a longer estimated life on DLS assets. |
|
|
B) Reflects the increase in amortization due to the
increase in other intangible assets in connection with the
acquisition of Rogers. |
|
|
C) Reflects the amortization on the financing fees related
to the sale of an additional $95.0 million of notes in
August 2006. |
|
|
D) Reflects the net increase in interest expense after
taking into account debt of acquired companies that was repaid
and additional borrowings needed to complete the acquisitions.
Approximately $8.6 million of existing debt for DLS will
remain outstanding after the acquisition. The interest rate
assumed on the $8.6 million of DLS debt was 6.21%, which
was the actual average interest rate on this debt as of
June 30, 2006. Each 0.125% change in this interest rate
would affect interest expense by $10,770 per annum. The
interest expense category for DLS historical financials
also includes other bank fees and other financial expenses of
approximately $1.6 million. In conjunction with the Rogers
acquisition, we issued a $750,000 note to the seller bearing
interest at a fixed rate of 5%, and we borrowed
$5.0 million under our line of credit. We assumed an 8%
interest rate for this $5.0 million borrowing, which is our
current borrowing rate under our committed line of credit. Each
0.125% change in this interest rate would affect interest
expense by $6,250 per annum. |
|
|
E) Reflects the additional interest expense related to the
sale of $95.0 million of notes bearing interest at 9.0%. We
repaid our $4.0 million, 5% subordinated note with a
portion of the net proceeds of the offering of such notes. The
proforma also reflects our repayment in June 2006 of the
$5.0 million borrowed under our revolving line of credit to
fund a portion of the Rogers acquisition. |
|
|
F) A statutory tax rate of 35% was applied to the
adjustments, but since Allis-Chalmers has a net operating loss
carryforward no tax expense was recorded. In addition, the
Allis-Chalmers net operating loss position offsets the
historical tax liabilities for operations in the United States
of acquired companies. Income taxes for DLS were computed at the
Argentinian statutory rate of 35% as we have no net operating
losses in Argentina to offset the tax liability. The net
operating loss carryforward, after the historical results for
Allis-Chalmers for the year ended December 31, 2005, is
approximately $15.4 million. |
|
|
G) Reflects the issuance of shares of our common stock as
part of the acquisition price for Rogers and DLS. We issued
125,285 shares in the Rogers acquisition, and the
consideration for our recent DLS acquisition included
2.5 million shares of our common stock. |
|
|
H) Reflects the issuance of shares of our common stock as a
result of the offering, issuance and sale of an additional
3.5 million shares of our common stock to fund a portion of
the cash component of the purchase price for the DLS
acquisition. The pro forma statement of operations treats the
shares as having been issued at a price of $14.50 per share. |
|
|
I) Reflects the increase in depreciation expense as a
result of the step-up
in basis of fixed assets and a longer estimated life on DLS
assets. |
|
|
J) Reflects the increase in amortization due to the
increase in other intangible assets in connection with the
acquisitions of Capcoil, W.T. and Rogers. Also reflects the
decreased rent expense of $386,000 that will result from the
acquisition of Specialty. We entered into a new lease for the
Specialty yard with the seller. Entering into this lease was
required by the purchase agreement and was a condition to the
closing of the Specialty acquisition. |
41
|
|
|
K) Reflects the amortization on the financing fees related
to our $160.0 million notes offering in January 2006 and
the sale of $95.0 million of notes in August 2006. |
|
|
L) Reflects the net increase in interest expense after
taking into account debt of acquired companies that was repaid
and additional borrowings needed to complete the acquisitions.
We applied $96.0 million of the net proceeds from our
$160.0 million notes offering in January 2006 to fund
the acquisition of Specialty. The notes bear interest at a fixed
rate of 9%. Approximately $8.6 million of DLS
pre-acquisition debt remained outstanding immediately following
the acquisition. The interest rate assumed on the
$8.6 million of DLS debt was 6.21% which was the actual
average interest rate on this debt as of June 30, 2006.
Each 0.125% change in this interest rate would affect interest
expense by $10,770 per annum. The interest expense category
for DLS historical financials also includes other bank
fees and other financial expenses of approximately
$2.7 million. In conjunction with the Rogers acquisition,
we issued a $750,000 note to the seller bearing interest at
5% fixed and we borrowed $5.0 million under our line of
credit. We assumed an 8% interest rate for this
$5.0 million borrowing which is our current borrowing rate
under our committed line of credit. Each 0.125% change in this
interest rate would affect interest expense by $6,250 per
annum. To acquire M-Is 45% interest in AirComp we issued a
new note for $4.0 million to replace a note for $4.8
million, both notes bore interest at 5.0%. |
|
|
M) Reflects the increased interest expense related to
additional borrowings as a result of the January 2006 notes
offering, and the sale of $95.0 million of notes in August
2006. We repaid our $4.0 million 5% subordinated note with
a portion of the net proceeds of the offering of senior notes in
August 2006. The proforma also reflects the repayment of the
$5.0 million borrowed under our revolving line of credit to
fund a portion of the Rogers acquisition. Interest on the
proceeds of the January 2006 notes in excess of the Specialty
acquisition and net of debt repayments and the interest on the
August 2006 notes are computed at the contractual rate of 9%. |
|
|
N) Reflects the elimination of the 45% minority interest
position of M-I in AirComp. |
|
|
O) Reflects the issuance of shares of our common stock as
part of the acquisition price for Delta, Capcoil, Rogers and
DLS. The Delta acquisition included consideration of
$1.0 million in stock, the Capcoil acquisition included
consideration of $765,000 in stock and the Rogers acquisition
included consideration of $1,650,000 in stock. The stock
component of the consideration for the recent DLS acquisition is
comprised of 2.5 million shares. |
42
SELECTED HISTORICAL CONSOLIDATED FINANCIAL INFORMATION
The following selected historical consolidated financial
information for each of the years in the five-year period ended
December 31, 2005 has been derived from our audited
consolidated financial statements, and the financial information
for the six months ended June 30, 2005 and 2006 was derived
from our unaudited interim financial statements included
elsewhere in this prospectus. This information is only a summary
and you should read it in conjunction with
Managements Discussion and Analysis of Financial
Condition and Results of Operations, which discusses
factors affecting the comparability of the information
presented, and in conjunction with our consolidated financial
statements and related notes included elsewhere in this
prospectus. Our historical consolidated financial statements
have been restated for the period from July 1, 2003 through
March 31, 2005, as described in the notes to our
consolidated financial statements included elsewhere herein.
Results for interim periods may not be indicative of results for
full fiscal years.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended | |
|
|
Year Ended December 31, | |
|
June 30, | |
|
|
| |
|
| |
|
|
2001(1) | |
|
2002 | |
|
2003 | |
|
2004 | |
|
2005 | |
|
2005 | |
|
2006 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
(Unaudited) | |
|
|
(In thousands, except per share amounts and ratios) | |
Statement of Operations Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
$ |
4,796 |
|
|
$ |
17,990 |
|
|
$ |
32,724 |
|
|
$ |
47,726 |
|
|
$ |
105,344 |
|
|
$ |
42,922 |
|
|
$ |
107,498 |
|
Cost of revenues
|
|
|
3,331 |
|
|
|
14,640 |
|
|
|
24,029 |
|
|
|
35,300 |
|
|
|
74,763 |
|
|
|
30,482 |
|
|
|
66,239 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
1,465 |
|
|
|
3,350 |
|
|
|
8,695 |
|
|
|
12,426 |
|
|
|
30,581 |
|
|
|
12,440 |
|
|
|
41,259 |
|
General and administrative expense
|
|
|
2,898 |
|
|
|
3,792 |
|
|
|
6,169 |
|
|
|
8,011 |
|
|
|
17,715 |
|
|
|
6,459 |
|
|
|
15,482 |
|
Personnel restructuring costs
|
|
|
|
|
|
|
495 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Abandoned acquisition/private placement costs
|
|
|
|
|
|
|
233 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Post-retirement medical costs
|
|
|
|
|
|
|
(98 |
) |
|
|
(99 |
) |
|
|
188 |
|
|
|
(352 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total operating expenses
|
|
|
2,898 |
|
|
|
4,422 |
|
|
|
6,070 |
|
|
|
8,199 |
|
|
|
17,363 |
|
|
|
6,459 |
|
|
|
15,482 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
(1,433 |
) |
|
|
(1,072 |
) |
|
|
2,625 |
|
|
|
4,227 |
|
|
|
13,218 |
|
|
|
5,161 |
|
|
|
24,504 |
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense, net
|
|
|
(828 |
) |
|
|
(2,207 |
) |
|
|
(2,464 |
) |
|
|
(2,776 |
) |
|
|
(4,397 |
) |
|
|
(1,166 |
) |
|
|
(7,425 |
) |
|
Factoring costs on note receivable
|
|
|
|
|
|
|
(191 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Settlement on lawsuit
|
|
|
|
|
|
|
|
|
|
|
1,034 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gain on sale of interest in AirComp
|
|
|
|
|
|
|
|
|
|
|
2,433 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other
|
|
|
(12 |
) |
|
|
(40 |
) |
|
|
12 |
|
|
|
272 |
|
|
|
186 |
|
|
|
158 |
|
|
|
20 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense)
|
|
|
(840 |
) |
|
|
(2,438 |
) |
|
|
1,015 |
|
|
|
(2,504 |
) |
|
|
(4,211 |
) |
|
|
(1,008 |
) |
|
|
(7,405 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) before income taxes and minority interest
|
|
|
(2,273 |
) |
|
|
(3,510 |
) |
|
|
3,640 |
|
|
|
1,723 |
|
|
|
9,007 |
|
|
|
4,153 |
|
|
|
17,099 |
|
Minority interests in income of subsidiaries
|
|
|
|
|
|
|
(189 |
) |
|
|
(343 |
) |
|
|
(321 |
) |
|
|
(488 |
) |
|
|
(488 |
) |
|
|
|
|
Income tax
|
|
|
|
|
|
|
(270 |
) |
|
|
(370 |
) |
|
|
(514 |
) |
|
|
(1,344 |
) |
|
|
(329 |
) |
|
|
(3,081 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) from continuing operations
|
|
|
(2,273 |
) |
|
|
(3,969 |
) |
|
|
2,927 |
|
|
|
888 |
|
|
|
7,175 |
|
|
|
3,336 |
|
|
|
14,018 |
|
(Loss) from discontinued operations
|
|
|
(291 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Loss) from sales of discontinued operations
|
|
|
(2,013 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net (loss) from discontinued operations
|
|
|
(2,304 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
|
(4,577 |
) |
|
|
(3,969 |
) |
|
|
2,927 |
|
|
|
888 |
|
|
|
7,175 |
|
|
|
3,336 |
|
|
|
14,018 |
|
Preferred stock dividend
|
|
|
|
|
|
|
(321 |
) |
|
|
(656 |
) |
|
|
(124 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributed to common stockholders
|
|
$ |
(4,577 |
) |
|
$ |
(4,290 |
) |
|
$ |
2,271 |
|
|
$ |
764 |
|
|
$ |
7,175 |
|
|
$ |
3,336 |
|
|
$ |
14,018 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Financial Data (unaudited):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ratio of earnings to fixed charges(2)
|
|
|
(1.6 |
)x |
|
|
(0.4 |
)x |
|
|
2.2 |
x |
|
|
1.5 |
x |
|
|
2.6 |
x |
|
|
3.9 |
x |
|
|
3.1 |
x |
43
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of December 31, | |
|
|
|
|
| |
|
As of | |
|
|
2001 | |
|
2002 | |
|
2003 | |
|
2004 | |
|
2005 | |
|
June 30, 2006 | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
|
|
|
|
|
|
|
|
|
|
(Unaudited) | |
|
|
(In thousands) | |
Balance Sheet Data:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
152 |
|
|
$ |
146 |
|
|
$ |
1,299 |
|
|
$ |
7,344 |
|
|
$ |
1,920 |
|
|
$ |
6,208 |
|
Total assets
|
|
|
12,465 |
|
|
|
34,778 |
|
|
|
53,662 |
|
|
|
80,192 |
|
|
|
137,355 |
|
|
|
280,686 |
|
Long-term debt (including current portion)
|
|
|
7,856 |
|
|
|
21,221 |
|
|
|
32,233 |
|
|
|
30,473 |
|
|
|
60,569 |
|
|
|
170,016 |
|
Stockholders equity
|
|
|
1,250 |
|
|
|
1,009 |
|
|
|
4,541 |
|
|
|
35,109 |
|
|
|
60,875 |
|
|
|
83,281 |
|
|
|
(1) |
We entered the oilfield services business in 2001. We sold our
last non-oilfield services business in December 2001, which is
reflected in our financial statements for 2001 as a discontinued
operation. |
|
|
(2) |
For purposes of determining the ratio of earnings to fixed
charges, earnings are defined as net income before income taxes,
extraordinary items, amortization of capitalized interest and
fixed charges, less capitalized interest. Fixed charges consist
of interest (whether expensed or capitalized), amortization of
debt expenses and discount or premium relating to any
indebtedness and dividends on preferred stock and the interest
component of leases represents the portion of rental expense
which we estimate as an interest component. For the years ended
December 31, 2001 and December 31, 2002, earnings were
inadequate to cover fixed charges due to a deficiency of
approximately $2.3 million and $3.7 million,
respectively. |
44
MANAGEMENTS DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion and analysis should be read in
conjunction with our selected historical financial information
and our accompanying financial statements and the notes to those
financial statements included elsewhere in this document. The
following discussion contains forward-looking statements within
the meaning of the Private Securities Litigation Reform Act of
1995 that reflect our plans, estimates and beliefs. Our actual
results could differ materially from those anticipated in these
forward-looking statements as a result of risks and
uncertainties, including, but not limited to, those discussed
above under Risk Factors.
Overview of Our Business
We are a multi-faceted oilfield services company that provides
services and equipment to oil and natural gas exploration and
production companies, domestically in Texas, Louisiana, New
Mexico, Colorado, Oklahoma, Mississippi, Utah, Wyoming, offshore
in the Gulf of Mexico, and internationally in Mexico. We
currently operate in five sectors of the oil and natural gas
service industry: directional drilling services; rental tools;
casing and tubing services; compressed air drilling services;
and production services.
We derive operating revenues from rates per day and rates per
job that we charge for the labor and equipment required to
provide a service. The price we charge for our services depends
upon several factors, including the level of oil and natural gas
drilling activity and the competitive environment in the
particular geographic regions in which we operate. Contracts are
awarded based on price, quality of service and equipment, and
general reputation and experience of our personnel. The demand
for drilling services has historically been volatile and is
affected by the capital expenditures of oil and natural gas
exploration and development companies, which can fluctuate based
upon the prices of oil and natural gas, or the expectation for
the prices of oil and natural gas.
The number of working drilling rigs, typically referred to as
the rig count, is an important indicator of activity
levels in the oil and natural gas industry. The rig count in the
United States increased from 862 as of December 31, 2002 to
1,762 on August 18, 2006, according to the Baker Hughes rig
count. Furthermore, directional and horizontal rig counts
increased from 283 as of December 31, 2002 to 698 on
August 18, 2006, which accounted for 32.8% and 40.0% of the
total U.S. rig count, respectively. Currently, we believe
that the number of available drilling rigs is insufficient to
meet the demand for drilling rigs. Consequently, unless a
significant number of additional drilling rigs are brought
online, the rig count may not increase substantially despite the
strong demand.
Our cost of revenues represents all direct and indirect costs
associated with the operation and maintenance of our equipment.
The principal elements of these costs are direct and indirect
labor and benefits, repairs and maintenance of our equipment,
insurance, equipment rentals, fuel and depreciation. Operating
expenses do not fluctuate in direct proportion to changes in
revenues because, among other factors, we have a fixed base of
inventory of equipment and facilities to support our operations,
and in periods of low drilling activity we may also seek to
preserve labor continuity to market our services and maintain
our equipment.
Cyclical Nature of Oilfield Services Industry
The oilfield services industry is highly cyclical. The most
critical factor in assessing the outlook for the industry is the
worldwide supply and demand for oil and the domestic supply and
demand for natural gas. The peaks and valleys of demand are
further apart than those of many other cyclical industries. This
is primarily a result of the industry being driven by commodity
demand and
45
corresponding price increases. As demand increases, producers
raise their prices. The price escalation enables producers to
increase their capital expenditures. The increased capital
expenditures ultimately result in greater revenues and profits
for services and equipment companies. The increased capital
expenditures also ultimately result in greater production which
historically has resulted in increased supplies and reduced
prices.
Demand for our services has been strong throughout 2003, 2004
and 2005 due to high oil and natural gas prices and increased
demand and declining production costs for natural gas as
compared to other energy sources. Management believes the
current market fundamentals are indicative of a favorable
long-term trend of activity in our markets. However, these
factors could be more than offset by other developments
affecting the worldwide supply and demand for oil and natural
gas products.
Restatement
We understated diluted earnings per share due to an incorrect
calculation of our weighted shares outstanding for the third
quarter of 2003, for each of the first three quarters of 2004,
for the years ended December 31, 2003 and 2004 and for the
quarter ended March 31, 2005. In addition, we understated
basic earnings per share due to an incorrect calculation of our
weighted average basic shares outstanding for the quarter ended
September 30, 2004. Consequently, we have restated our
financial statements for each of those periods. The incorrect
calculation resulted from a mathematical error and an improper
application of Statement of Financial Accounting Standards
No. 128, Earnings Per Share, or SFAS,
No. 128. The effect of the restatement is to reduce
weighted average diluted shares outstanding for each period and
to reduce weighted average basic shares outstanding for the
quarter ended September 30, 2004. Therefore, diluted
earnings per share were increased for the relevant periods and
basic earnings per share were increased for the quarter ended
September 30, 2004. (See Note 2 to our consolidated
financial statements for the three years ended December 31,
2005).
In connection with the formation of AirComp in 2003, we, along
with M-I, contributed assets to AirComp in exchange for a 55%
interest and 45% interest, respectively, in AirComp. We
originally accounted for the formation of AirComp as a joint
venture, but in February 2005 determined that the transaction
should have been accounted for using purchase accounting
pursuant to SFAS No. 141, Business
Combinations and SEC Staff Accounting
Bulletin No. 51 Accounting for Sales of Stock
by a Subsidiary. Consequently, we have restated our
financial statements for the year ended December 31, 2003
and for the first three quarters of 2004 (See Note 2 to our
consolidated financial statements for the three years ended
December 31, 2005).
Management has concluded that the need to restate our financial
statements resulted, in part, from the lack of sufficient
experienced accounting personnel, which in turn resulted in a
lack of effective control over the financial reporting process.
We have implemented a number of actions that we believe address
the deficiencies in our financial reporting process, including
the following:
|
|
|
|
|
The addition of experienced accounting personnel with
appropriate experience and qualifications to perform quality
review procedures and to satisfy our financial reporting
obligations. During August 2004, we hired a new chief financial
officer and in October 2004 we hired a full-time in-house
general counsel. In March 2005, we hired a certified public
accountant as our financial reporting manager and in July 2005
we hired as chief accounting officer, a certified public
accountant who has significant prior experience as a chief
accounting officer of a publicly traded company. In 2006, we
have added three additional certified public accountants in
connection with the growth of our business and to implement and
monitor compliance with internal control processes. |
46
|
|
|
|
|
In the fourth quarter of 2004, we engaged an independent
internal controls consulting firm which is in the process of
documenting, analyzing, identifying and correcting deficiencies
and testing our internal controls and procedures, including our
controls over internal financial reporting. |
|
|
|
We are in the final stages of completing the implementation of a
new accounting software to facilitate timely and accurate
reporting. |
Although we have implemented a number of actions as described
above, we have not yet had sufficient time to test the newly
implemented actions.
Results of Operations
In February 2002, we acquired 81% of the capital stock of
Allis-Chalmers Tubular Services Inc., or Tubular. In February
2002, we also purchased substantially all the outstanding common
stock and preferred stock of Strata Directional Technology,
Inc., or Strata. The results from our casing and tubing services
and directional drilling services are included in our operating
results from February 1, 2002.
In July 2003, through our subsidiary Mountain Compressed Air,
Inc., or Mountain Air, we entered into a limited liability
company agreement with M-I, a company owned by Smith
International and Schlumberger N.V., to form AirComp. We
owned 55% and M-I owned 45% of AirComp until we purchased
M-Is interest in July 2005. We have consolidated AirComp
into our financial statements beginning with the quarter ending
September 30, 2003.
In September 2004, we acquired the remaining 19% of Tubular and
we acquired Safco-Oil Field Products, Inc., or Safco. In
November 2004, AirComp acquired substantially all of the assets
of Diamond Air and, in December 2004, we acquired Downhole
Injection Services, LLC, or Downhole. We consolidated the
results of these acquisitions from the day they were acquired.
In April 2005, we acquired Delta Rental Service, Inc., or Delta,
and, in May 2005, we acquired Capcoil. We report the operations
of Downhole and Capcoil as our production services segment and
the operations of Safco and Delta as our rental tools segment.
In July 2005, we acquired the 45% interest of M-I in our
compressed air drilling subsidiary, AirComp, making us the 100%
owner of AirComp. In addition, in July 2005, we acquired the
compressed air drilling assets of W.T. Enterprises, Inc., or
W.T. On August 1, 2005, we acquired 100% of the outstanding
capital stock of Target Energy Inc., or Target. The results of
Target are included in our directional and horizontal drilling
segment as their measurement-while-drilling equipment is
utilized in that segment. On September 1, 2005, we acquired
the casing and tubing service assets of Patterson Services,
Inc., or Patterson. We consolidated the results of these
acquisitions from the day they were acquired.
In January 2006, we acquired 100% of the outstanding stock of
Specialty. In April 2006, we acquired 100% of the
outstanding stock of Rogers. We consolidated the results of each
of these acquisitions from the effective date thereof.
The foregoing acquisitions affect the comparability from period
to period of our historical results, and our historical results
may not be indicative of our future results.
|
|
|
Comparison of Three Months
Ended June 30, 2006 and 2005 |
Our revenues for the three months ended June 30, 2006 were
$60.5 million, an increase of 156.4% compared to
$23.6 million for the three months ended June 30,
2005. Revenues increased in all of our business segments due to
acquisitions completed in the second and third quarters of 2005
and the first and second quarters of 2006, the investment in
additional equipment, improved pricing for our services, the
addition of operations and sales personnel and the opening of
new operations offices. Revenues
47
increased most significantly at our rental tools segment due to
the acquisition of Specialty, effective January 1, 2006.
Our casing and tubing services segment also so a substantial
increase in revenue, primarily due to the acquisitions of the
casing and tubing assets of Patterson Services, Inc on
September 1, 2005, and the acquisition of Rogers as of
April 1, 2006, along with improved market conditions and
increased market penetration for our services in South Texas,
East Texas, Louisiana and the U.S. Gulf of Mexico. Revenue
increased at our compressed air drilling segment due to the
acquisition of the air drilling assets of W.T. on July 11,
2005, the purchase of additional equipment and improved pricing
for our services in West Texas. Our directional drilling
services segment revenues increased in the 2006 period compared
to the 2005 period due to improved pricing for directional
drilling services, the acquisition of Target, which provides
measurement-while-drilling tools, or MWD, the addition of
operations and sales personnel, the opening of new operations
offices and the purchase of additional down-hole motors and MWDs
which increased our capacity and market presence. Also
contributing to increased revenues was the acquisition of
Capcoil as of May 1, 2005 in our production services
segment.
Our gross profit for the quarter ended June 30, 2006
increased 262.6% to $24.7 million, or 40.8% of revenues,
compared to $6.8 million, or 28.8%, of revenues for the
three months ended June 30, 2005. The increase in gross
profit as a percentage of revenues is due to the acquisition of
Specialty as of January 1, 2006, in the high margin rental
tool business. The increase in gross profit is also due to
increased revenues at our compressed air drilling services
segment, including the acquisition of the air drilling assets of
WT, increased revenues and improved pricing in the directional
drilling services segment. Improved market conditions for our
domestic casing and tubing segment, the acquisition of
additional casing and tubing assets in September 2005 and
the acquisition of Rogers in April 2006 also contributed to
the increase in gross profit. The increase in gross profit was
partially offset by an increase in depreciation expense of
250.5% to $3.8 million for the second quarter of 2006 compared
to $1.1 million for the second quarter of 2005. The
increase is due to additional depreciable assets resulting from
the acquisitions and capital expenditures. Our cost of revenues
consists principally of our labor costs and benefits, equipment
rentals, maintenance and repairs of our equipment, depreciation,
insurance and fuel. Because many of our costs are fixed, our
gross profit as a percentage of revenues is generally affected
by our level of revenues.
General and administrative expense was $8.1 million in the
second quarter of 2006 period compared to $3.5 million for
the second quarter of 2005. General and administrative expense
increased due to the additional expenses associated with the
acquisitions, and the hiring of additional sales and
administrative personnel. General and administrative expense
also increased because of increased accounting and consulting
fees and other expenses in connection with initiatives to
strengthen our internal control processes, costs related to
Sarbanes Oxley compliance efforts and increased corporate
accounting and administrative staff. As a percentage of
revenues, general and administrative expenses were 13.5% in the
2006 quarter and 14.7% in the 2005 quarter.
We adopted SFAS No. 123R, Share-Based Payment,
effective January 1, 2006. This statement requires all
share-based payments to employees, including grants of employee
stock options, to be recognized in the financial statements
based on their grant-date fair values. We adopted SFAS
No. 123R using the modified prospective transition method,
utilizing the Black-Scholes option pricing model for the
calculation of the fair value of our employee stock options.
Under the modified prospective method, we record compensation
cost related to unvested stock awards as of December 31,
2005 by recognizing the unamortized grant date fair value of
these awards over the remaining vesting periods of those awards
with no change in historical reported earnings. Therefore, we
recorded an expense of $0.8 million related to stock
options for the three months ended June 30, 2006, of which
$764,000 was recorded in general and administrative expense with
the balance being recorded as a direct cost. Prior to
January 1,
48
2006, we accounted for our stock-based compensation using
Accounting Principle Board Opinion No. 25. Under APB
No. 25, compensation expense is recognized for stock
options with an exercise price that is less than the market
price on the grant date of the option. Accordingly, no
compensation cost was recognized under APB No. 25.
Amortization expense was $666,000 in the second quarter of 2006
compared to $426,000 in the second quarter of 2005. The increase
in amortization expense is due to the amortization of intangible
assets in connection with our acquisitions and the amortization
of deferred financing costs.
Income from operations for the three months ended June 30,
2006 totaled $15.9 million, a 444.6% increase over income
from operations of $2.9 million for the three months ended
June 30, 2005, reflecting the increase in our revenues and
gross profit, offset in part by increased general and
administrative expenses and amortization.
Our net interest expense was $3.8 million in the second
quarter of 2006, compared to $645,000 for the second quarter of
2005. Interest expense increased in the 2006 quarter due to the
increased borrowings at a higher average interest rate. In
January of 2006 we issued $160.0 million of senior notes
bearing interest at 9.0% to fund the acquisition of Specialty,
pay off other outstanding debt and for working capital.
Minority interest in income of subsidiaries for the second
quarter of 2006 was $0 compared to $344,000 for the second
quarter of 2005 due to the acquisition of the minority interest
in AirComp as of July 11, 2005.
We had net income of $9.6 million for the second quarter of
2006, an increase of 442.3%, compared to net income of
$1.8 million for the second quarter of 2005.
The following table compares revenues and income from operations
for each of our business segments. Income (loss) from
operations consists of revenues less cost of revenues, general
and administrative expenses, and depreciation and amortization:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues | |
|
Income (Loss) from Operations | |
|
|
| |
|
| |
|
|
|
|
Three Months | |
|
|
|
|
|
Three Months | |
|
|
|
|
|
|
Ended | |
|
|
|
|
|
Ended | |
|
|
|
|
|
|
June 30, | |
|
|
|
|
|
June 30, | |
|
|
|
|
2006 | |
|
2005 | |
|
Change | |
|
2006 | |
|
2005 | |
|
Change | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(in thousands) | |
Directional drilling services
|
|
$ |
18,315 |
|
|
$ |
10,934 |
|
|
$ |
7,381 |
|
|
$ |
4,367 |
|
|
$ |
1,495 |
|
|
$ |
2,872 |
|
Rental tools
|
|
|
12,707 |
|
|
|
1,566 |
|
|
|
11,141 |
|
|
|
7,308 |
|
|
|
405 |
|
|
|
6,903 |
|
Casing and tubing services
|
|
|
14,569 |
|
|
|
3,933 |
|
|
|
10,636 |
|
|
|
4,314 |
|
|
|
1,354 |
|
|
|
2,960 |
|
Compressed air drilling services
|
|
|
10,949 |
|
|
|
4,866 |
|
|
|
6,083 |
|
|
|
3,204 |
|
|
|
1,002 |
|
|
|
2,202 |
|
Production services
|
|
|
3,930 |
|
|
|
2,289 |
|
|
|
1,641 |
|
|
|
341 |
|
|
|
36 |
|
|
|
305 |
|
General corporate
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(3,663 |
) |
|
|
(1,378 |
) |
|
|
(2,285 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
60,470 |
|
|
$ |
23,588 |
|
|
$ |
36,882 |
|
|
$ |
15,871 |
|
|
$ |
2,914 |
|
|
$ |
12,957 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional Drilling Services Segment Revenues for the
quarter ended June 30, 2006 for our directional drilling
services segment were $18.3 million, an increase of 67.5%
from the $10.9 million in revenues for the quarter ended
June 30, 2005. Income from operations increased 192.1% to
$4.4 million for the second quarter of 2006 from
$1.5 million for the comparable 2005 period. The improved
results for this segment are due to the increase in drilling
activity in the Texas and Gulf Coast areas, improved pricing for
directional and horizontal drilling services, the acquisition of
Target as of August 1, 2005, the purchase of an additional
six MWDs, the establishment of new operations in West Texas and
Oklahoma, and the addition of operations and sales personnel
which increased our capacity and market
49
presence. Our increased operating expenses as a result of the
addition of operations and personnel were more than offset by
the growth in revenues and improved pricing for our services.
Rental Tools Segment Revenues for the quarter ended
June 30, 2006 for the rental tools segment were
$12.7 million, from $1.6 million in revenues for the
quarter ended June 30, 2005. Income from operations
increased to $7.3 million in the 2006 period compared to
$405,000 in the 2005 period. Our rental tools revenues and
operating income for the second quarter of 2006 increased
compared to the prior year due primarily due to the acquisition
of Specialty. Specialty was acquired as of January 1, 2006,
the effective date of the acquisition. Safco, Delta and
Specialty were merged in February 2006 to form
Allis-Chalmers Rental Tools, Inc
Casing and Tubing Services Segment Revenues for the
quarter ended June 30, 2006 for the casing and tubing
services segment were $14.6 million, an increase of 270.4% from
the $3.9 million in revenues for the quarter ended
June 30, 2005. Revenues from domestic operations increased
to $13.0 million in the 2006 period from $2.3 million in
the 2005 period as a result of the acquisition of Rogers and the
casing and tubing assets of Patterson Services on
September 1, 2005, which resulted in increased market
penetration for our services in South Texas, East Texas,
Louisiana and the U.S. Gulf of Mexico. Revenues from Mexico
operations were $1.6 million for the second quarter of 2006
and in the second quarter of 2005. Income from operations
increased 218.6% to $4.3 million in the second quarter of
2006 from $1.4 million in the second quarter of 2005. The
increase in this segments operating income is due to our
increased revenues from domestic operations. The operating
income as a percentage of revenue decreased to 29.6% for the
three months ended June 30, 2006 compared to 34.4% for the
same period of 2005. The decrease in operating income as a
percentage of revenues is due to the increase in domestic
revenues as compared to Mexico revenues, which have higher
operating income margins.
Compressed Air Drilling Services Segment Our compressed
air drilling revenues were $10.9 million for the three
months ended June 30, 2006, an increase of 125.0% compared
to $4.9 million in revenues for the three months ended
June 30, 2005. Income from operations increased to
$3.2 million in the 2006 period compared to income from
operations of $1.0 million in the 2005 period. Our
compressed air drilling revenues and operating income for the
second quarter of 2006 increased compared to the prior year due
primarily due to the acquisition of the air drilling assets of
WT as of July 11, 2005, improved pricing for our services
and our investment in additional equipment.
Production Services Segment Operations for this segment
consist of Downhole, which was acquired December 1, 2004,
and Capcoil which was acquired May 1, 2005. Downhole and
Capcoil were merged in February 2006, to form
Allis-Chalmers Production Services, Inc. Revenues were $3.9
million for the three months ended June 30, 2006, an
increase of 71.7% compared to $2.3 million in revenues for
the three months ended June 30, 2005. Income from
operations increased to $341,000 in the 2006 period compared to
$36,000 in the 2005 period. Our production services revenues and
operating income for the second quarter of 2006 increased
compared to the prior year due to the acquisition of Capcoil and
improved pricing for our services and improved utilization of
out equipment.
General Corporate General corporate expenses increased
$2.3 million to $3.7 million for the three months
ended June 30, 2006 compared to $1.4 million for the three
months ended June 30, 2005. The increase was due to stock
option expense of $0.8 million recorded in 2006 with the
adoption of SFAS 123R, the increase in accounting and
administrative staff to support the growing organization,
increased franchise taxes based on our increased authorized
shares and cost related to our Sarbanes-Oxley compliance effort.
50
|
|
|
Comparison of Six Months
Ended June 30, 2006 and 2005 |
Our revenues for the six months ended June 30, 2006 were
$107.5 million, an increase of 150.4% compared to
$42.9 million for the six months ended June 30, 2005.
Revenues increased in all of our business segments due to
acquisitions completed in the second and third quarters of 2005
and the first and second quarters of 2006, the investment in
additional equipment, improved pricing for our services, the
addition of operations and sales personnel and the opening of
new operations offices. Revenues increased most significantly at
our rental tools segment due to the acquisition of Specialty,
effective January 1, 2006 and Delta, on April 1, 2005.
Our casing and tubing services segment recorded substantial
revenue growth due to the acquisitions of the casing and tubing
assets of Patterson Services, Inc on September 1, 2005, and
the acquisition of Rogers effective April 1, 2006, along
with improved market conditions and increased market penetration
for our services in South Texas, East Texas, Louisiana and the
U.S. Gulf of Mexico. Our directional drilling services segment
revenues increased in the 2006 period compared to the 2005
period due to improved pricing for directional drilling
services, the acquisition of Target, which provides MWD tools,
the addition of operations and sales personnel, the opening of
new operations offices and the purchase of additional down-hole
motors and MWDs which increased our capacity and market
presence. Revenues also increased at our compressed air drilling
segment due to the acquisition of the air drilling assets of WT,
on July 11, 2005, the purchase of additional equipment and
improved pricing for our services in West Texas. Also
contributing to increased revenues was the acquisition of
Capcoil, as of May 1, 2005 in our production services
segment.
Our gross profit for the six months ended June 30, 2006
increased 231.7% to $41.3 million, or 38.4% of revenues,
compared to $12.4 million, or 29.0%, of revenues for the
six months ended June 30, 2005. The increase in gross
profit as a percentage of revenues is due to the acquisition of
Specialty as of January 1, 2006 and the acquisition of
Delta as of April 1, 2005, in the high margin rental tool
business. The increase in gross profit is also due to increased
revenues at our compressed air drilling services segment,
including the acquisition of the air drilling assets of WT,
increased revenues and improved pricing in the directional
drilling services segment. Improved market conditions for our
domestic casing and tubing segment, the acquisition of
additional casing and tubing assets in September 2005 and
the acquisition of Rogers effective April 1, 2006 also
contributed to the gross profit increase. The increase in gross
profit was partially offset by an increase in depreciation
expense of 256.8% to $7.2 million for the first six months
of 2006 compared to $2.0 million for the first six months
of 2005. The increase is due to additional depreciable assets
resulting from the acquisitions and capital expenditures. Our
cost of revenues consists principally of our labor costs and
benefits, equipment rentals, maintenance and repairs of our
equipment, depreciation, insurance and fuel. Because many of our
costs are fixed, our gross profit as a percentage of revenues is
generally affected by our level of revenues.
General and administrative expense was $15.5 million in the
first six months of 2006 period compared to $6.5 million
for the first six months of 2005. General and administrative
expense increased due to the additional expenses associated with
the acquisitions, and the hiring of additional sales and
administrative personnel. General and administrative expense
also increased because of increased accounting and consulting
fees and other expenses in connection with initiatives to
strengthen our internal control processes, costs related to
Sarbanes Oxley compliance efforts and increased corporate
accounting and administrative staff. As a percentage of
revenues, general and administrative expenses were 14.4% for the
six months ended June 30, 2006 and 15.0% in the same period
of 2005.
We adopted SFAS No. 123R, Share-Based Payment,
effective January 1, 2006. This statement requires all
share-based payments to employees, including grants of employee
stock options, to be
51
recognized in the financial statements based on their grant-date
fair values. With the adoption of SFAS no. 123R, we recorded
$1.8 million of expense related to stock options during the
six months ended June 30, 2006, of which $1.6 million was
recorded as a general and administrative expense with the
balance recorded as direct costs. We adopted SFAS No. 123R
using the modified prospective transition method, utilizing the
Black-Scholes option pricing model for the calculation of the
fair value of our employee stock options. Under the modified
prospective method, we record compensation cost related to
unvested stock awards as of December 31, 2005 by
recognizing the unamortized grant date fair value of these
awards over the remaining vesting periods of those awards with
no change in historical reported earnings. Prior to
January 1, 2006, we accounted for our stock-based
compensation using Accounting Principle Board Opinion
No. 25. Under APB No. 25, compensation expense is
recognized for stock options with an exercise price that is less
than the market price on the grant date of the option.
Accordingly, no compensation cost was recognized under APB
No. 25.
Amortization expense was $1.3 million in the first six
months of 2006 compared to $820,000 in the first six months of
2005. The increase in amortization expense is due to the
amortization of intangible assets in connection with our
acquisitions and the amortization of deferred financing costs.
Income from operations for the six months ended June 30,
2006 totaled $24.5 million, a 374.8% increase over income
from operations of $5.2 million for the six months ended
June 30, 2005, reflecting the increase in our revenues and
gross profit, offset in part by increased general and
administrative expenses, and amortization.
Our net interest expense was $7.4 million in the first six
months of 2006, compared to $1.2 million for the first six
months of 2005. Interest expense increased in the 2006 period
due to the increased borrowings at a higher average interest
rate. In January of 2006 we issued $160.0 million of senior
notes bearing interest at 9.0% to fund the acquisition of
Specialty, pay off other outstanding debt and for working
capital.
Minority interest in income of subsidiaries for the six months
ended June 30, 2006 was $0 compared to $488,000 for the six
months ended June 30, 2005 due to the acquisition of the
minority interest in AirComp, as of July 11, 2005.
We had net income of $14.0 million for the first six months
of 2006, an increase of 320.2%, compared to net income of
$3.3 million for the first six months of 2005.
The following table compares revenues and income from operations
for each of our business segments. Income (loss) from
operations consists of revenues less cost of revenues, general
and administrative expenses, and depreciation and amortization:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues | |
|
Income (Loss) from Operations | |
|
|
| |
|
| |
|
|
|
|
Six Months | |
|
|
|
|
|
Six Months | |
|
|
|
|
|
|
Ended | |
|
|
|
|
|
Ended | |
|
|
|
|
|
|
June 30, | |
|
|
|
|
|
June 30, | |
|
|
|
|
2006 | |
|
2005 | |
|
Change | |
|
2006 | |
|
2005 | |
|
Change | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(in thousands) | |
Directional drilling services
|
|
$ |
33,369 |
|
|
$ |
20,835 |
|
|
$ |
12,534 |
|
|
$ |
6,972 |
|
|
$ |
3,373 |
|
|
$ |
3,599 |
|
Rental tools
|
|
|
23,128 |
|
|
|
1,940 |
|
|
|
21,188 |
|
|
|
12,306 |
|
|
|
326 |
|
|
|
11,980 |
|
Casing and tubing services
|
|
|
24,028 |
|
|
|
7,493 |
|
|
|
16,535 |
|
|
|
6,165 |
|
|
|
2,679 |
|
|
|
3,486 |
|
Compressed air drilling services
|
|
|
20,048 |
|
|
|
9,047 |
|
|
|
11,001 |
|
|
|
5,441 |
|
|
|
1,529 |
|
|
|
3,912 |
|
Production services
|
|
|
6,925 |
|
|
|
3,607 |
|
|
|
3,318 |
|
|
|
618 |
|
|
|
(2 |
) |
|
|
620 |
|
General corporate
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(6,998 |
) |
|
|
(2,744 |
) |
|
|
(4,254 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
107,498 |
|
|
$ |
42,922 |
|
|
$ |
64,576 |
|
|
$ |
24,504 |
|
|
$ |
5,161 |
|
|
$ |
19,343 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
52
Directional Drilling Services Segment Revenues for the
six months ended June 30, 2006 for our directional drilling
services segment were $33.4 million, an increase of 60.2%
from the $20.8 million in revenues for the six months ended
June 30, 2005. Income from operations increased 106.7% to
$7.0 million for the first six months of 2006 from
$3.4 million for the comparable 2005 period. The improved
results for this segment are due to the increase in drilling
activity in the Texas and Gulf Coast areas, improved pricing for
directional and horizontal drilling services, the acquisition of
Target as of August 1, 2005, the purchase of an additional
six MWDs, the establishment of new operations in West Texas and
Oklahoma, and the addition of operations and sales personnel
which increased our capacity and market presence. Our increased
operating expenses as a result of the addition of operations and
personnel were more than offset by the growth in revenues and
improved pricing for our services.
Rental Tools Segment Revenues for the six months ended
June 30, 2006 for the rental tools segment were
$23.1 million, from $1.9 million in revenues for the
six months ended June 30, 2005. Income from operations
increased to $12.3 million in the 2006 period compared to
$326,000 in the 2005 period. Our rental tools revenues and
operating income for the first six months of 2006 increased
compared to the prior year due primarily due to the acquisitions
of Specialty and Delta. Delta was acquired as of April 1,
2005, and Specialty was acquired as of January 1, 2006, the
effective date of their respective acquisitions. Safco, Delta
and Specialty were merged in February 2006 to form
Allis-Chalmers Rental Tools, Inc.
Casing and Tubing Services Segment Revenues for the six
months ended June 30, 2006 for the casing and tubing
services segment were $24.0 million, an increase of 220.7%
from the $7.5 million in revenues for the six months ended
June 30, 2005. Revenues from domestic operations increased
to $20.8 million in the 2006 period from $4.2 million
in the 2005 period as a result of the acquisitions of the casing
and tubing assets of Patterson Services on September 1,
2005 and Rogers effective April 1, 2006, which resulted in
increased market penetration for our services in South Texas,
East Texas, Louisiana and the U.S. Gulf of Mexico. Revenues from
Mexico operations decreased to $3.2 million in the first
six months of 2006 from $3.3 million in the 2005 period.
Income from operations increased 130.1% to $6.2 million in
the first six months of 2006 from $2.7 million in the first
six months of 2005. The increase in this segment’s
operating income is due to our increased revenues from domestic
operations. The operating income as a percentage of revenue
decreased to 25.7% for the six months ended June 30, 2006
compared to 35.8% for the same period of 2005. The decrease in
operating income as a percentage of revenues is due to the
increase in domestic revenues as compared to Mexico revenues,
which have higher operating income margins.
Compressed Air Drilling Services Segment Our compressed
air drilling revenues were $20.0 million for the six months
ended June 30, 2006, an increase of 121.6% compared to
$9.0 million in revenues for the six months ended
June 30, 2005. Income from operations increased to
$5.4 million in the 2006 period compared to income from
operations of $1.5 million in the 2005 period. Our
compressed air drilling revenues and operating income for the
first six months of 2006 increased compared to the prior year
due primarily due to the acquisition of the air drilling assets
of WT as of July 11, 2005, improved pricing for our
services and our investment in additional equipment.
Production Services Segment Operations for this segment
consist of Downhole which was acquired December 1, 2004,
and Capcoil which was acquired May 1, 2005. Downhole and
Capcoil were merged in February 2006, to form
Allis-Chalmers Production Services, Inc. Revenues were
$6.9 million for the six months ended June 30, 2006, an
increase of 92.0% compared to $3.6 million in revenues for
the six months ended June 30, 2005. Income from operations
increased to $618,000 in the 2006 period compared to loss from
operations of $2,000 in the 2005 period. Our production services
revenues and
53
operating income for the first six months of 2006 increased
compared to the prior year due to the acquisition of Capcoil and
improved pricing for our services and improved utilization of
our equipment.
General Corporate General corporate expenses increased
$4.3 million to $7.0 million for the six months ended
June 30, 2006 compared to $2.7 million for the six
months ended June 30, 2005. The increase was due to stock
option expense of $1.8 million recorded in 2006 with the
adoption of SFAS 123R, the increase in accounting and
administrative staff to support the growing organization,
increased franchise taxes based on our increased authorized
shares and cost related to our Sarbanes-Oxley compliance effort.
|
|
|
Comparison of Years Ended
December 31, 2005 and December 31, 2004 |
Our revenues for the year ended December 31, 2005 were
$105.3 million, an increase of 120.8% compared to
$47.7 million for the year ended December 31, 2004.
The increase in revenues was principally due to acquisitions
completed in the fourth quarter of 2004 and the second and third
quarters of 2005, the addition of operations and sales
personnel, the opening of new operations offices, and the
purchase of additional equipment. Acquisitions completed during
this period enabled us to establish our rental tool and
production services segments which resulted in an increased
offering of products and services and an expansion of our
customer base. Directional drilling services segment revenues
increased in the 2005 period compared to the 2004 period due to
the addition of operations and sales personnel, the opening of
new operations offices and the purchase of additional downhole
motors which increased our capacity and market presence.
Revenues increased at our compressed air drilling segment due to
acquisition of the air drilling assets of W.T. on July 11,
2005, the acquisitions of substantially all of the assets of
Diamond Air Drilling Services, Inc. and Marquis Bit Co., LLC,
which we refer to collectively as Diamond Air, on
November 1, 2004 and improved pricing for our services in
West Texas.
Revenues increased at our casing and tubing services segment due
to the acquisition of the casing and tubing assets of Patterson
on September 1, 2005, increased revenues from Mexico,
improved market conditions, improved market penetration for our
services in South Texas and the addition of operating personnel
and equipment which broadened our capabilities. Also
contributing to increased revenues were the acquisitions of
Safco as of September 1, 2004, Downhole as of
December 1, 2004, Delta as of April 1, 2005 and
Capcoil as of May 1, 2005. Downhole and Capcoil comprise
our production services segment and were merged in February 2006
to form Production Services. Safco and Delta comprise our
rental tool segment and were merged in February 2006 with
Specialty to form Rental Tools.
Our gross margin for the year ended December 31, 2005
increased 146.1% to $30.6 million, or 29.0% of revenues,
compared to $12.4 million, or 26.0% of revenues, for the
year ended December 31, 2004. The increase is due to
increased revenues and improved pricing in the directional
drilling services segment, increased revenues at our compressed
air drilling services segment, including revenues resulting from
the acquisition of Diamond Air and the compressed air drilling
assets of W.T., increased revenues from Mexico, improved market
conditions for our domestic casing and tubing segment and the
growth of our rental tools segment through the acquisition of
Delta on April 1, 2005. Depreciation expense increased
80.4% to $4.9 million in 2005 compared to $2.7 million
in 2004. The increase is due to additional depreciable assets
resulting from capital expenditures and acquisitions in 2004 and
2005. Our cost of revenues consists principally of our labor
costs and benefits, equipment rentals, maintenance and repairs
of our equipment, depreciation, insurance and fuel. Because many
of our costs are fixed, our gross profit as a percentage of
revenues is generally affected by our level of revenues.
General and administrative expense was $15.9 million for
the year ended December 31, 2005 compared to
$7.1 million for the year ended December 31, 2004.
General and administrative expense increased due to the
additional expenses associated with the acquisitions completed
in the second half of
54
2004 and in 2005, and the hiring of additional sales and
administrative personnel. General and administrative expense
also increased because of increased legal and accounting fees
and other expenses related to our financing and acquisition
activities, increased consulting fees in connection with our
internal controls and corporate governance process, and
increased corporate accounting and administrative staff. As a
percentage of revenues, general and administrative expenses were
15.1% for 2005 and 14.9% for 2004.
Amortization expense was $1.8 million for the year ended
December 31, 2005 compared to $0.9 million for the
year ended December 31, 2004. The increase in amortization
expense is due to the amortization of intangible assets in
connection with our acquisitions and the amortization of
deferred financing costs.
Income from operations for the year ended December 31, 2005
totaled $13.2 million, a 212.7% increase over the
$4.2 million in income from operations for the year ended
December 31, 2004, reflecting the increase in our revenues
and gross profit, offset in part by increased general and
administrative expenses.
Our interest expense was $4.4 million for the year ended
December 31, 2005, compared to $2.8 million for the
year ended December 31, 2004. Interest expense increased
during 2005 due to the increased borrowings associated with the
acquisitions completed in the second and third quarters of 2005,
equipment purchases and higher average interest rates, offset in
part by the prepayment, in December 2004, of our 12%
$2.4 million subordinated note. Additionally, in 2005, we
incurred debt retirement expense of $1.1 million related to
the refinancing of our debt. This amount includes prepayment
penalties and the write-off of deferred financing fees from a
previous financing.
Minority interest in income of subsidiaries for the year ended
December 31, 2005 was $488,000 compared to $321,000 for the
corresponding period in 2004 due to the increase in
profitability at AirComp due in part to the acquisition of
Diamond Air as of November 1, 2004. The minority interest
at AirComp was acquired on July 11, 2005 and the minority
interest in Tubular, which was 19%-owned by former director Jens
Mortensen, was acquired on September 30, 2004.
We had net income attributed to common stockholders of
$7.2 million for the year ended December 31, 2005, an
increase of 839.1%, compared to the net income attributed to
common stockholders of $0.8 million for the year ended
December 31, 2004. The net income attributed to common
stockholders in the 2004 period is after $124,000 in preferred
stock dividends were distributed.
The following table compares revenues and income from operations
for each of our business segments for the years ended
December 31, 2005 and December 31, 2004. Income from
operations consists of our revenues less cost of revenues,
general and administrative expenses, and depreciation and
amortization:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues | |
|
Income (Loss) from Operations | |
|
|
| |
|
| |
|
|
2005 | |
|
2004 | |
|
Change | |
|
2005 | |
|
2004 | |
|
Change | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands) | |
Directional drilling services
|
|
$ |
43,901 |
|
|
$ |
24,787 |
|
|
$ |
19,114 |
|
|
$ |
7,389 |
|
|
$ |
3,061 |
|
|
$ |
4,328 |
|
Compressed air drilling services
|
|
|
25,662 |
|
|
|
11,561 |
|
|
|
14,101 |
|
|
|
5,612 |
|
|
|
1,169 |
|
|
|
4,443 |
|
Casing and tubing services
|
|
|
20,932 |
|
|
|
10,391 |
|
|
|
10,541 |
|
|
|
4,994 |
|
|
|
3,217 |
|
|
|
1,777 |
|
Rental tools
|
|
|
5,059 |
|
|
|
611 |
|
|
|
4,448 |
|
|
|
1,300 |
|
|
|
(71 |
) |
|
|
1,371 |
|
Production services
|
|
|
9,790 |
|
|
|
376 |
|
|
|
9,414 |
|
|
|
(99 |
) |
|
|
4 |
|
|
|
(103 |
) |
General corporate
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(5,978 |
) |
|
|
(3,153 |
) |
|
|
(2,825 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
105,344 |
|
|
$ |
47,726 |
|
|
$ |
57,618 |
|
|
$ |
13,218 |
|
|
$ |
4,227 |
|
|
$ |
8,991 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
55
Directional Drilling Services Segment. Revenues for the
year ended December 31, 2005 for our directional drilling
services segment were $43.9 million, an increase of 77.1%
from the $24.8 million in revenues for the year ended
December 31, 2004. Income from operations increased 141.4%
to $7.4 million for 2005 from $3.1 million for 2004.
The improved results for this segment are due to the increase in
drilling activity in Texas and the Gulf Coast area, the
establishment of new operations in West Texas and Oklahoma, the
addition of operations and sales personnel, the purchase of
additional downhole motors which increased our capacity and
market presence and the acquisition of Target, a provider of
measurement-while-drilling equipment, effective August 2005. Our
operating income increased due to higher revenue explained above
and cost savings achieved as a result of the purchases of most
of the downhole motors used in directional drilling, which we
had previously rented.
Compressed Air Drilling Services Segment. Our compressed
air drilling revenues were $25.7 million for the year ended
December 31, 2005, an increase of 122.0% compared to
$11.6 million in revenues for the year ended
December 31, 2004. Income from operations increased 380.1%
to $5.6 million in 2005 compared to income from operations
of $1.2 million in 2004. Our compressed air drilling
revenues and operating income for the 2005 period increased
compared to the 2004 period due in part to the acquisition of
the air drilling assets of W.T., the acquisition of Diamond Air
as of November 1, 2004 and improved pricing in West Texas.
Casing and Tubing Services Segment. Revenues for the year
ended December 31, 2005 for the casing and tubing services
segment were $20.9 million, an increase of 101.4% from the
$10.4 million in revenues for the year ended
December 31, 2004. Revenues from domestic operations
increased to $14.5 million in 2005 from $5.2 million
in 2004 as a result of the acquisition of the casing and tubing
assets of Patterson on September 1, 2005, improved market
conditions for our services in South Texas and the addition of
personnel which added to our capabilities and our offering of
services. Revenues from Mexican operations increased to
$6.4 million in 2005 from $5.2 million in 2004 as a
result of increased drilling activity in Mexico and the addition
of equipment that increased our capacity. Income from operations
increased 55.2% to $5.0 million in 2005 from
$3.2 million in 2004. The increase in this segments
operating income is due to increased revenues both domestically
and in our Mexico operations.
Rental Tools Segment. Our rental tools revenues were
$5.1 million for the year ended December 31, 2005, an
increase of 728.0% compared to $0.6 million in revenues for
the year ended December 31, 2004. Income from operations
increased to $1.3 million in 2005 compared to a loss from
operations of $71,000 in 2004. Operations for this segment
include Safco, acquired in September 2004, and Delta, acquired
in April 2005.
Production Services Segment. Our production services
revenues were $9.8 million for the year ended
December 31, 2005, compared to $376,000 in revenues for the
year ended December 31, 2004. Loss from operations was
$99,000 in 2005 compared to an operating income of $4,000 in
2004. Operations for this segment consist of Downhole, acquired
December 1, 2004, and Capcoil, acquired May 1, 2005.
We plan to grow this segment and improve profitability by
increasing our market presence and our critical mass and adding
additional capillary and coil tubing units. Our results for the
year ended December 31, 2005 for this segment were
negatively affected by costs incurred to expand our
international presence for production services and by downtime
experienced by one of our larger coil tubing units.
|
|
|
Comparison of Years Ended
December 31, 2004 and December 31, 2003 |
Our revenues for the year ended December 31, 2004 were
$47.7 million, an increase of 45.8% compared to
$32.7 million for the year ended December 31, 2003.
Revenues increased due to increased
56
demand for our services due to the general increase in oil and
gas drilling activity. Revenues increased most significantly at
our directional drilling services segment due to the addition of
operations and sales personnel, which increased our capacity and
market presence. Additionally, our compressed air drilling
services revenues in 2004 increased compared to the year 2003
due to the inclusion, for a full year in 2004, of the business
contributed by M-I in connection with the formation of AirComp
in July 2003 and the acquisition of Diamond Air on
November 1, 2004. We have consolidated AirComp into our
financial statements beginning with the quarter ended
September 30, 2003. Also contributing to the increase in
revenues was an increase in Mexico revenues at our casing and
tubing services segment, which was offset in part by a decrease
in domestic revenues for this segment due to increased
competition for casing and tubing services in South Texas.
Finally, in the second half of 2004, we acquired Safco, our
rental tools subsidiary, as of September 1, and as of
December 1, 2004, we acquired Downhole, our production
services subsidiary.
Our gross margin for the year ended December 31, 2004
increased 42.9% to $12.4 million, or 26.0% of revenues,
compared to $8.7 million, or 26.6% of revenues for the year
ended December 31, 2003, due to the increase in revenues in
the directional drilling services segment, the compressed air
drilling services segment and from Mexico, which more than
offset lower revenues and higher costs in our domestic casing
and tubing segment. Our cost of revenues consists principally of
our labor costs and benefits, equipment rentals, maintenance and
repairs of our equipment, depreciation, insurance and fuel.
Because many of our costs are fixed, our gross profit as a
percentage of revenues is generally affected by our level of
revenues.
General and administrative expense was $7.1 million in the
2004 period compared to $5.3 million for 2003. General and
administrative expense increased in 2004 due to additional
expenses associated with the inclusion of AirComp for a full
year, the acquisitions completed in the second half of 2004, and
the hiring of additional sales and administrative personnel at
each of our subsidiaries. General and administrative expense
also increased because of increased professional fees and other
expenses related to our financing and acquisition activities,
including the listing of our common stock on the American Stock
Exchange, and increased corporate accounting and administrative
staff. As a percentage of revenues, general and administrative
expenses were 14.9% in 2004 and 16.2% in 2003.
Depreciation and amortization was $3.6 million for the year
ended December 31, 2004 compared to $2.9 million for
the year ended December 31, 2003. The increase was due to
the inclusion of AirComp for a full year and the increase in our
assets resulting from our capital expenditures and the
acquisitions completed in 2004.
Income from operations for the year ended December 31, 2004
totaled $4.2 million, a 61.0% increase over the
$2.6 million in income from operations for the prior year,
reflecting the increase in our revenues and gross profit, offset
in part by an increase in general and administrative expense.
Income from operations in the year ended December 31, 2004
includes $188,000 in additional accrued expense for
post-retirement medical benefits pursuant to our plan of
reorganization. The increase in this accrued expense was based
on the present value of the expected retiree benefit obligations
as determined by a third-party actuary. Income from operations
for the year 2003 includes income of $99,000, which resulted
from a reduction in projected post-retirement benefits based on
the third-party actuary at the end of 2003.
Our interest expense increased to $2.8 million in 2004,
compared to $2.5 million for the prior year, in spite of
the decrease in our total debt. Interest expense in 2004
includes $359,000 in warrant put amortization, including the
retirement of warrants in connection with the prepayment, in
December 2004, of our $2.4 million 12.0% subordinated
note. Interest expense in 2003 includes $216,000 in connection
with the acceleration, in 2003, of the amortization of a put
obligation related to subordinated
57
debt at Mountain Air. The subordinated debt including accrued
interest was paid off in connection with the formation of
AirComp in 2003.
Minority interest in income of subsidiaries for the year 2004
was $321,000 compared to $343,000 for the year 2003. The
increase in net income at AirComp was offset in part by the
elimination of minority interest in Tubular, which was 19%-owned
by former director Jens Mortensen until September 30, 2004.
We had net income attributed to common stockholders of $764,000
for the year ended December 31, 2004 compared to net income
attributed to common stockholders of $2.3 million for the
year ended December 31, 2003. In 2003, we recognized a
non-operating gain on sale of an interest in a subsidiary in the
amount of $2.4 million in connection with the formation of
AirComp, and recognized a one-time gain of $1.0 million in
the third quarter of 2003 as a result of settling a lawsuit
against the former owners of Mountain Air.
The following table compares revenues and income from operations
for each of our business segments for the years ended
December 31, 2004 and December 31, 2003. Income from
operations consists of our revenues less cost of revenues,
general and administrative expenses, and depreciation and
amortization:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (Loss) | |
|
|
Revenues | |
|
from Operations | |
|
|
| |
|
| |
|
|
2004 | |
|
2003 | |
|
Change | |
|
2004 | |
|
2003 | |
|
Change | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands) | |
Directional drilling services
|
|
$ |
24,787 |
|
|
$ |
16,008 |
|
|
$ |
8,779 |
|
|
$ |
3,061 |
|
|
$ |
1,103 |
|
|
$ |
1,958 |
|
Compressed air drilling services
|
|
|
11,561 |
|
|
|
6,679 |
|
|
|
4,882 |
|
|
|
1,169 |
|
|
|
17 |
|
|
|
1,152 |
|
Casing and tubing services
|
|
|
10,391 |
|
|
|
10,037 |
|
|
|
354 |
|
|
|
3,217 |
|
|
|
3,628 |
|
|
|
(411 |
) |
Other services
|
|
|
987 |
|
|
|
|
|
|
|
987 |
|
|
|
(67 |
) |
|
|
|
|
|
|
(67 |
) |
General corporate
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(3,153 |
) |
|
|
(2,123 |
) |
|
|
(1,030 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
47,726 |
|
|
$ |
32,724 |
|
|
$ |
15,002 |
|
|
$ |
4,227 |
|
|
$ |
2,625 |
|
|
$ |
1,602 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional Drilling Services Segment. Revenues for the
year ended December 31, 2004 for our directional drilling
services segment were $24.8 million, an increase of 54.8%
from the $16.0 million in revenues for the year ended
December 31, 2003. Income from operations increased by
177.5% to $3.1 million for the year ended December 31,
2004 from $1.1 million for 2003. The improved results for
this segment are due to the increase in drilling activity in
Texas and the Gulf Coast area and the addition of operations and
sales personnel which increased our capacity and market
presence. Increased operating expenses as a result of the
addition of personnel were more than offset by the growth in
revenues and cost savings as a result of purchases, in late 2003
and in 2004, of most of the down-hole motors used in directional
drilling. Previously we had leased these motors.
Compressed Air Drilling Services Segment. Our compressed
air drilling revenues were $11.6 million for the year ended
December 31, 2004, an increase of 73.1% compared to
$6.7 million in revenues for the year ended
December 31, 2003. Income from operations increased to
$1.2 million in 2004 compared to income from operations of
$17,000 in 2003. Our compressed air drilling revenues and
operating income for the year 2004 increased compared to the
prior year due to the inclusion, for a full year in 2004, of the
business contributed by
M-I, in connection with
the formation of AirComp in July 2003, and the acquisition of
Diamond Air as of November 1, 2004.
Casing and Tubing Services Segment. Revenues for the year
ended December 31, 2004 for the casing and tubing services
segment were $10.4 million, an increase of 3.5% from the
$10.0 million in
58
revenues for the year ended December 31, 2003. Revenues
from domestic operations decreased from $6.3 million in
2003 to $5.1 million in the year 2004 as a result of
increased competition in South Texas, resulting in fewer
contracts awarded to us and lower pricing for our services.
Revenues from Mexican operations, however, increased from
$3.7 million in 2003 to $5.3 million in the 2004
period as a result of increased drilling activity in Mexico and
the addition of equipment that increased our capacity. Income
from operations decreased by 11.3% to $3.2 million in 2004
from $3.6 million in 2003. The decrease in this
segments revenues and operating income is due to the
decrease in revenues from domestic operations and increases in
wages and benefits domestically, which was partially offset by
increased revenues from Mexico.
Other Services Segment. Revenues for this segment consist
of Safcos rental tool business, beginning
September 1, 2004, and Downholes production services
beginning December 1, 2004, the effective date of their
respective acquisitions. Revenues for this segment were $987,000
with a loss from operations of $67,000. It is our plan to grow
in these businesses thereby improving profitability as we
increase our market presence and our critical mass.
Liquidity and Capital Resources
Our on-going capital requirements arise primarily from our need
to service our debt, to complete acquisitions and acquire and
maintain equipment, and to fund our working capital
requirements. Our primary sources of liquidity are borrowings
under our revolving lines of credit, proceeds from the issuance
of debt and equity securities and cash flows from operations. We
had cash and cash equivalents of $6.2 million at
June 30, 2006 compared to $1.9 million at
December 31, 2005, $7.3 million at December 31,
2004 and $1.3 million at December 31, 2003.
In the six months ended June 30, 2006, our operating
activities provided $17.0 million in cash compared to
$2.9 million for the same period in 2005. Net income for
the six months ended June 30, 2006 increased to
$14.0 million, compared to $3.3 million in the 2005
period. The $14.0 million in net income for the 2006 period
includes a charge of $1.8 million related to the expensing
of stock options as required under SFAS No. 123R. Revenues
and income from operations increased in the first six months of
2006 due to acquisitions completed in the first and second
quarters of 2006 and the second and third quarters of 2005, the
investment in additional equipment, the opening of new
operations offices and the addition of operations and sales
personnel. Non-cash expenses totaled $11.0 million during
the first six months of 2006 consisting of $8.4 million of
depreciation and amortization, $1.8 million from the
expensing of stock options, $355,000 of imputed interest related
to the effective date of the Specialty acquisition, $279,000
related to increases to the allowance for doubtful accounts
receivables and $119,000 on the loss from asset retirements.
Non-cash expenses during the first six months of 2005 totaled
$3.3 million, consisting of depreciation and amortization
expense of $2.8 million and minority interest of $488,000.
During the six months ended June 30, 2006, changes in
operating assets and liabilities used $8.0 million in cash,
principally due to an increase of $13.6 million in accounts
receivable, an increase of $1.5 million in inventory, a
decrease of $1.5 million in accounts payable, offset in
part by an increase of $6.4 million in accrued interest and
an increase of $1.8 million in accrued expenses. Accounts
receivable increased due to the increase in our revenues in the
first six months of 2006. Other inventory increased primarily
due to increased activity levels. The increase in accrued
interest relates to our 9.0% senior notes issued in 2006 which
is only payable in January and July. The increase in accrued
expenses can be attributed to additional income tax liability
due to profitability and additional expenses related to higher
activity levels.
59
During the six months ended June 30, 2005, changes in
operating assets and liabilities used $3.8 million in cash,
principally due to an increase of $3.0 million in accounts
receivable, an increase of $1.1 million in inventory, and a
decrease of $296,000 in accrued expenses, offset in part by an
increase in accounts payable of $610,000. Accounts receivable
increased due to the increase in our revenues in the first six
months of 2005. The increase in inventory primarily relates to
the acquisition of Capcoil. Accounts payable increased due to
the increased level of activity.
During the six months ended June 30, 2006, we used
$119.0 million in investing activities, consisting of
$95.8 million for the acquisition of Specialty, net of cash
received, $10.7 million for the acquisition of Rogers, net
of cash received and $14.2 million for capital
expenditures, offset by $1.8 million of proceeds from
equipment sales. Included in the $14.2 million for capital
expenditures was $5.5 million for equipment used in our
casing and tubing segment, $3.0 million for the expansion
of our MWD equipment used in the directional drilling segment
and $3.0 million for additional equipment in our compressed
air drilling services segment. A majority of our equipment sales
relate to items lost in hole by our customers.
During the first six months of 2005, we used $12.6 million
in investing activities, consisting principally of the purchase
of equipment of $5.5 million, the acquisition of Delta, net
of cash received, for $4.5 million and the acquisition of
Capcoil, net of cash received, for $2.6 million. Equipment
purchases consisted primarily of $1.9 million for casing
equipment, approximately $1.2 million for the purchase of
downhole motors and approximately $1.9 million for new
compressed air drilling equipment.
During the six months ended June 30, 2006, financing
activities provided $106.3 million in cash. We received
$161.4 million in proceeds from long-term debt, repaid
$45.3 million in borrowings under long-term debt
facilities, repaid $3.0 million in related party debt,
repaid $6.4 million net under our line of credit and paid
$5.3 million in debt issuance costs. We also received $5.0
million in proceeds from the exercise of options and warrants.
During the six months ended June 30, 2005, financing activities
provided a net of $5.0 million in cash. We received
$5.2 million, net, in borrowings under long-term debt
facilities and paid $199,000 in debt issuance costs.
On January 18, 2006, we closed on a private offering of
$160.0 million aggregate principal amount of our senior
notes. The notes are due January 15, 2014 and bear interest
at 9.0%. The proceeds from the sale of the notes were used to
fund the Specialty acquisition, to repay existing debt and for
general corporate purposes.
Prior to January 18, 2006, we were party to a
July 2005 credit agreement that provided for the following
senior secured credit facilities:
|
|
|
|
|
A $13.0 million revolving line of credit. Borrowings were
limited to 85% of eligible accounts receivable plus 50% of
eligible inventory (up to a maximum of $2.0 million of
borrowings based on inventory). This line of credit was to be
used to finance working capital requirements and other general
corporate purposes, including the issuance of standby letters of
credit. Outstanding borrowings under this line of credit were
$6.4 million at a margin above prime and LIBOR rates plus margin
averaging approximately 8.1% as of December 31, 2005. |
|
|
|
Two term loans totaling $42.0 million. Outstanding
borrowings under these term loans were $42.0 million as of
December 31, 2005. These loans were at LIBOR rates plus a
margin which averages approximately 7.8% at December 31,
2005. |
60
Borrowings under the July 2005 credit facilities were to
mature in July 2007. Amounts outstanding under the term
loans as of July 2006 were to be repaid in monthly
principal payments based on a 48 month repayment schedule
with the remaining balance due at maturity. Additionally, during
the second year, we were to be required to prepay the remaining
balance of the term loans by 75% of excess cash flow, if any,
after debt service and capital expenditures. The interest rate
payable on borrowings was based on a margin over the London
Interbank Offered Rate, referred to as LIBOR, or the prime rate,
and there was a 0.5% fee on the undrawn portion of the revolving
line of credit. The margin over LIBOR was to increase by 1.0% in
the second year.
All amounts outstanding under our July 2005 credit
agreement were paid off with the proceeds of our senior notes
offering on January 18, 2006. On January 18, 2006, we
also executed an amended and restated credit agreement which
provides for a $25.0 million revolving line of credit with
a maturity of January 2010. Our January 2006 amended
and restated credit agreement contains customary events of
default and financial covenants and limits our ability to incur
additional indebtedness, make capital expenditures, pay
dividends or make other distributions, create liens and sell
assets. Our obligations under the January 2006 amended and
restated credit agreement are secured by substantially all of
our assets.
At June 30, 2006, we had $170.0 million in outstanding
indebtedness, of which $166.0 million was long term debt
and $4.0 million was the current portion of long term debt.
On July 11, 2005, we acquired from M-I its 45% equity
interest in AirComp and the subordinated note in the principal
amount of $4.8 million issued by AirComp, for which we paid
M-I $7.1 million
in cash and issued a new $4.0 million subordinated note
bearing interest at 5% per annum. The subordinated note issued
to M-I requires
quarterly interest payments and the principal amount is due
October 9, 2007. Contingent upon a future equity offering,
the subordinated note is convertible into up to 700,000 shares
of our common stock at a conversion price equal to the market
value of the common stock at the time of conversion. This note
was repaid from the proceeds of our 9.0% senior notes offering,
which we completed in August 2006.
As of December 31, 2005, Allis-Chalmers Tubular Services
Inc., or Tubular, had a subordinated note outstanding and
payable to Jens Mortensen, the seller of Tubular and one of our
former directors, in the amount of $4.0 million with a
fixed interest rate of 7.5%. Interest was payable quarterly and
the final maturity of the note was January 31, 2006. The
subordinated note was subordinated to the rights of our bank
lenders. The balance of this subordinated note was repaid in
full in January 2006 with proceeds from our senior notes
offering.
As part of the acquisition of Mountain Compressed Air Inc., or
Mountain Air, in 2001, we issued a note to the sellers of
Mountain Air in the original amount of $2.2 million
accruing interest at a rate of 5.75% per annum. The note was
reduced to $1.5 million as a result of the settlement of a
legal action against the sellers in 2003. In March 2005, we
reached an agreement with the sellers and holders of the note as
a result of an action brought against us by the sellers. Under
the terms of the agreement, we paid the holders of the note
$1.0 million in cash, and agreed to pay an additional
$350,000 on June 1, 2006, and an additional $150,000 on
June 1, 2007, in settlement of all claims. At June 30,
2006 and December 31, 2005 the outstanding amounts due were
$150,000 and $500,000, respectively.
In connection with the purchase of Delta, we issued to the
sellers a note in the amount of $350,000. The note bore interest
at 2% and the principal and accrued interest was repaid on its
maturity of April 1, 2006. In connection with the
acquisition of Rogers, we issued to the seller a note in the
amount of $750,000. The note bears interest at 5% and is due
April 3, 2009.
61
In connection with the purchase of Tubular, we agreed to pay a
total of $1.2 million to Mr. Mortensen in exchange for a
non-compete agreement. Monthly payments of $20,576 are due under
this agreement through January 31, 2007. In connection with
the purchase of Safco, we also agreed to pay a total of $150,000
to the sellers in exchange for a non-compete agreement. We are
required to make annual payments of $50,000 through
September 30, 2007. In connection with the purchase of
Capcoil, we agreed to pay a total of $500,000 to two management
employees in exchange for non-compete agreements. We are
required to make annual payments of $110,000 through
May 2008. Total amounts due under these non-compete
agreements at June 30, 2006 and December 31, 2005 were
$443,000 and $698,000, respectively.
In 2000 we compensated directors, including current directors
Nederlander and Toboroff, who served on the board of directors
from 1989 to March 31, 1999 without compensation, by
issuing promissory notes totaling $325,000. The notes bear
interest at the rate of 5.0%. At June 30, 2006 and
December 31, 2005, the principal and accrued interest on
these notes totaled approximately $32,000 and $96,000,
respectively.
We also had a real estate loan which was payable in equal
monthly installments of $4,344 with the remaining outstanding
balance due on January 1, 2010. The loan had a floating
interest rate based on prime plus 2.0%. The outstanding
principal balance was $548,000 at December 31, 2005. The
balance of this loan was repaid in full in January 2006
with proceeds from our senior notes offering.
We have various equipment financing loans with interest rates
ranging from 5% to 8.2% and terms ranging from 2 to
5 years. As of June 30, 2006 and December 31,
2005, the outstanding balances for equipment financing loans
were $2.4 million and $1.9 million, respectively. In
April 2006, we obtained an insurance premium financing in
the amount of $1.9 million with a fixed interest rate of
5.6%. Under terms of the agreement, amounts outstanding are paid
over a 10 month repayment schedule. The outstanding balance
of this note was approximately $1.6 million as of
June 30, 2006. We also have various capital leases with
terms that expire in 2008. As of June 30, 2006 and
December 31, 2005, amounts outstanding under capital leases
were $671,000 and $917,000, respectively. In January 2006,
we prepaid $350,000 of the outstanding equipment loans with
proceeds from our senior notes offering.
The following table summarizes our obligations and commitments
to make future payments under our notes payable, operating
leases, employment contracts and consulting agreements for the
periods specified as of December 31, 2005.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Payments by Period |
|
|
|
|
|
|
|
Less Than | |
|
|
|
|
Total | |
|
1 Year | |
|
2-3 Years | |
|
4-5 Years | |
|
After 5 Years |
|
|
| |
|
| |
|
| |
|
| |
|
|
|
|
(In thousands) |
Contractual Obligations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Notes payable(a)
|
|
$ |
59,652 |
|
|
$ |
5,158 |
|
|
$ |
53,887 |
|
|
$ |
607 |
|
|
$ |
|
|
Capital leases(b)
|
|
|
917 |
|
|
|
474 |
|
|
|
443 |
|
|
|
|
|
|
|
|
|
Interest payments on notes payable
|
|
|
7,076 |
|
|
|
4,186 |
|
|
|
2,839 |
|
|
|
51 |
|
|
|
|
|
Operating lease
|
|
|
2,878 |
|
|
|
926 |
|
|
|
1,462 |
|
|
|
490 |
|
|
|
|
|
Employment contracts
|
|
|
4,016 |
|
|
|
2,512 |
|
|
|
1,504 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total contractual cash obligations
|
|
$ |
74,539 |
|
|
$ |
13,256 |
|
|
$ |
60,135 |
|
|
$ |
1,148 |
|
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a) |
In January of 2006 we issued $160.0 million of senior notes
due 2014 and repaid $48.5 million of debt due in
2-3 years and
$3.1 million due in less than one year. |
|
|
(b) |
These amounts represent our minimum capital lease payments, net
of interest payments totaling $69,000. |
62
We have no off-balance sheet arrangements, other than normal
operating leases and employee contracts shown above, that have
or are likely to have a current or future material effect on our
financial condition, changes in financial condition, revenues,
expenses, results of operations, liquidity, capital expenditures
or capital resources. We do not guarantee obligations of any
unconsolidated entities.
Capital Requirements
We have identified capital expenditure projects that we expect
will require up to approximately $8.0 million for the
remainder of 2006, exclusive of any acquisitions. We believe
that our current cash generated from operations, cash available
under our credit facilities and cash on hand will provide
sufficient funds for our identified projects.
We intend to implement a growth strategy of increasing the scope
of services through both internal growth and acquisitions. We
are regularly involved in discussions with a number of potential
acquisition candidates. The acquisition of assets could require
additional financing, which we currently anticipate would be
borrowed under our bank facility. Any such borrowing would
require the consent of our lenders under our bank credit
facilities. We also expect to make capital expenditures to
acquire and to maintain our existing equipment. Our performance
and cash flow from operations will be determined by the demand
for our services which in turn are affected by our
customers expenditures for oil and gas exploration and
development, and industry perceptions and expectations of future
oil and natural gas prices in the areas where we operate. We
will need to refinance our existing debt facilities as they
become due and provide funds for capital expenditures and
acquisitions. To effect our expansion plans, we will require
additional equity or debt financing. There can be no assurance
that we will be successful in raising the additional debt or
equity capital or that we can do so on terms that will be
acceptable to us.
Recent Developments
On August 8, 2006, we entered into an amendment to our
amended and restated credit agreement dated as of
January 18, 2006. The amendment, among other things,
amended the credit agreement to (a) allow us to
(i) issue and sell $95.0 million aggregate principal
amount of our 9.0% senior notes due 2014 and (ii) issue and
sell 3,450,000 shares of our common stock, (b) allow us to
use the net proceeds from the senior notes offering and the
common stock offering to purchase all the outstanding capital
stock of DLS Drilling Logistics and Services Corporation, or
DLS, (c) exclude certain existing indebtedness and
investments of DLS and investments and indebtedness related to
the DLS acquisition from the covenants contained in the credit
agreement and (d) increase the amount of permitted lease
obligations and capital expenditures.
On August 8, 2006, we priced a public offering of
3.0 million shares of our common stock at $14.50 per share.
We granted the underwriters a
30-day option to
purchase up to an additional 450,000 shares to cover
over-allotments, if any. On August 14, 2006, we closed the
common stock offering and the underwriters elected to exercise
the over-allotment option in full. We ultimately raised
approximately $47.0 million from such registered stock offering
and applied all such amount toward the cash component of the
purchase price of DLS.
We also priced a private offering of $95.0 million
aggregate principal amount of 9.0% senior notes on
August 8, 2006. The notes were sold to investors at a price
of 100% of the principal amount thereof, plus accrued interest
from July 15, 2006. Fixed interest on the notes will be
payable on January 15 and July 15 of each year,
beginning on January 15, 2007 and the notes mature on
January 15, 2014. The sale of the notes closed on
August 14, 2006. We raised net proceeds of approximately
$92.7 million
63
through the issuance of such 9.0% senior notes, and we applied a
portion of such amount to the payment of the remainder of the
cash component of the purchase price for DLS.
On August 14, 2006, we completed the acquisition of all of
the outstanding capital stock of DLS. The purchase price of DLS
consisted of $93.7 million in cash, 2.5 million shares
of our common stock and approximately $8.6 million of
assumed debt. DLS currently operates a fleet of 51 rigs,
including 20 drilling rigs, 18 workover rigs and
12 pulling rigs in Argentina and one drilling rig in
Bolivia.
As part of the DLS acquisition, Carlos Alberto Bulgheroni and
Alejandro Pedro Bulgheroni have joined our board of directors,
filling vacancies created by the resignations of Jens H.
Mortensen, Jr. and Thomas O. Whitener, Jr. On August 21,
2006, Thomas E. Kelly resigned from our board of directors.
Critical Accounting Policies
We have identified the policies below as critical to our
business operations and the understanding of our results of
operations. The impact and any associated risks related to these
policies on our business operations is discussed throughout
Managements Discussion and Analysis of Financial Condition
and Results of Operations where such policies affect our
reported and expected financial results. For a detailed
discussion on the application of these and other accounting
policies, see Note 1 in the Notes to the Consolidated
Financial Statements included elsewhere in this prospectus. Our
preparation of this prospectus requires us to make estimates and
assumptions that affect the reported amount of assets and
liabilities, disclosure of contingent assets and liabilities at
the date of our financial statements, and the reported amounts
of revenue and expenses during the reporting period. There can
be no assurance that actual results will not differ from those
estimates.
Allowance for doubtful accounts. The determination of the
collectibility of amounts due from our customers requires us to
use estimates and make judgments regarding future events and
trends, including monitoring our customer payment history and
current credit worthiness to determine that collectibility is
reasonably assured, as well as consideration of the overall
business climate in which our customers operate. Those
uncertainties require us to make frequent judgments and
estimates regarding our customers ability to pay amounts
due us in order to determine the appropriate amount of valuation
allowances required for doubtful accounts. Provisions for
doubtful accounts are recorded when it becomes evident that the
customers will not be able to make the required payments at
either contractual due dates or in the future.
Revenue recognition. We provide rental equipment and
drilling services to our customers at per day and per job
contractual rates and recognize the drilling related revenue as
the work progresses and when collectibility is reasonably
assured. The Securities and Exchange Commissions Staff
Accounting Bulletin No. 104, Revenue
Recognition in Financial Statements, provides guidance
on the SEC staffs views on application of generally
accepted accounting principles to selected revenue recognition
issues. Our revenue recognition policy is in accordance with
generally accepted accounting principles and
SAB No. 104.
Impairment of long-lived assets. Long-lived assets, which
include property, plant and equipment, goodwill and other
intangibles, comprise a significant amount of our total assets.
We make judgments and estimates in conjunction with the carrying
value of these assets, including amounts to be capitalized,
depreciation and amortization methods and useful lives.
Additionally, the carrying values of these assets are reviewed
for impairment or whenever events or changes in circumstances
indicate that the carrying amounts may not be recoverable. An
impairment loss is recorded in the period in which it is
determined that the carrying amount is not recoverable. This
requires us to make long-term forecasts of our future revenues
and costs related to the assets subject to review. These
forecasts require assumptions about demand for our products and
services, future market conditions and technological
developments.
64
Significant and unanticipated changes to these assumptions could
require a provision for impairment in a future period.
Goodwill and other intangibles. As of December 31,
2005, we have recorded approximately $12.4 million of
goodwill and $6.8 million of other identifiable intangible
assets. We perform purchase price allocations to intangible
assets when we make a business combination. Business
combinations and purchase price allocations have been
consummated for acquisitions in all of our reportable segments.
The excess of the purchase price after allocation of fair values
to tangible assets is allocated to identifiable intangibles and
thereafter to goodwill. Subsequently, we perform our initial
impairment tests and annual impairment tests in accordance with
Financial Accounting Standards Board No. 141,
Business Combinations, and Financial
Accounting Standards Board No. 142, Goodwill and
Other Intangible Assets. These initial valuations used
two approaches to determine the carrying amount of the
individual reporting units. The first approach is the Discounted
Cash Flow Method, which focuses on our expected cash flow. In
applying this approach, the cash flow available for distribution
is projected for a finite period of years. Cash flow available
for distribution is defined as the amount of cash that could be
distributed as a dividend without impairing our future
profitability or operations. The cash flow available for
distribution and the terminal value (our value at the end of the
estimation period) are then discounted to present value to
derive an indication of value of the business enterprise. This
valuation method is dependent upon the assumptions made
regarding future cash flow and cash requirements. The second
approach is the Guideline Company Method which focuses on
comparing us to selected reasonably similar publicly traded
companies. Under this method, valuation multiples are:
(i) derived from operating data of selected similar
companies; (ii) evaluated and adjusted based on our
strengths and weaknesses relative to the selected guideline
companies; and (iii) applied to our operating data to
arrive at an indication of value. This valuation method is
dependent upon the assumption that our value can be evaluated by
analysis of our earnings and our strengths and weaknesses
relative to the selected similar companies. Significant and
unanticipated changes to these assumptions could require a
provision for impairment in a future period.
Recently Issued Accounting Standards
In July 2006, the FASB issued FASB Interpretation No. 48,
Accounting for Uncertainty in Income Taxes an
interpretation of FASB Statement
No. 109 (FIN 48). FIN 48
clarifies the accounting for uncertainty in income taxes
recognized in an enterprises financial statements in
accordance with SFAS No. 109, Accounting for Income
Taxes. It prescribes a recognition threshold and measurement
attribute for financial statement recognition and measurement of
a tax position taken or expected to be taken in a tax return.
This interpretation is effective for fiscal years beginning
after December 15, 2006. We are currently evaluating the
provisions of FIN 48 and have not yet determined the
impact, if any, on our financial statements.
In May 2005, the FASB issued SFAS No. 154,
Accounting Changes and Error Corrections.
SFAS No. 154 requires retroactive application of a
voluntary change in accounting principle to prior period
financial statements unless it is impracticable.
SFAS No. 154 also requires that a change in method of
depreciation, amortization or depletion for long-lived,
non-financial assets be accounted for as a change in accounting
estimate that is affected by a change in accounting principle.
SFAS No. 154 replaces APB Opinion No. 20,
Accounting Changes and SFAS No. 3, Reporting
Accounting Changes in Interim Financial Statement.
SFAS No. 154 is effective for fiscal years beginning
after December 15, 2005. We adopted the provisions of
SFAS No. 154 as of January 1, 2006 and the
adoption did not have a material impact on our results of
operations.
In December 2004, the FASB issued SFAS No. 123R,
Share-Based Payment. SFAS No. 123R revises
SFAS No. 123, Accounting for Stock-Based
Compensation, and focuses on accounting for share-
65
based payments for services by employer to employee. The
statement requires all share-based payments to employees,
including grants of employee stock options, to be recognized in
the financial statements based on their fair values. We adopted
SFAS No. 123R as of January 1, 2006 and used the
modified prospective transition method, utilizing the
Black-Scholes option pricing model for the calculation of the
fair value of our employee stock options. Under the modified
prospective method, stock option awards that are granted,
modified or settled after January 1, 2006 will be measured
and accounted for in accordance with SFAS No. 123R.
Compensation cost for awards granted prior to, but not vested,
as of January 1, 2006 would be based on the grant date
attributes originally used to value those awards for pro forma
purposes under SFAS No. 123. See Note 3 of our
unaudited consolidated condensed financial statements for the
six months ended June 30, 2006, for a more detailed
description of our adoption of SFAS No. 123R.
In November 2004, the FASB issued SFAS No. 151,
Inventory Costs an Amendment of ARB
No. 43, Chapter 4, which amends the guidance in ARB
No. 43 to clarify the accounting for abnormal amounts of
idle facility expense, freight, handling costs and wasted
material. SFAS No. 151 requires that these items be
recognized as current period charges. In addition,
SFAS No. 151 requires the allocation of fixed
production overheads to inventory based on the normal capacity
of the production facilities. We adopted the provisions of
SFAS No. 151, on a prospective basis, as of
January 1, 2006 and the adoption did not have a material
impact on our results of operations.
Quantitative and Qualitative Disclosure About Market Risk
We are exposed to market risk primarily from changes in interest
rates and foreign currency exchange risks.
Interest Rate Risk. Fluctuations in the general level of
interest rates on our current and future fixed and variable rate
debt obligations expose us to market risk. We are vulnerable to
significant fluctuations in interest rates affecting our
adjustable rate debt, and any future refinancing of our fixed
rate debt and our future debt.
At December 31, 2005, we were exposed to interest rate
fluctuations on approximately $49.0 million of notes
payable and bank credit facility borrowings carrying variable
interest rates. During the three months ended March 31,
2006, we repaid all variable interest rate debt.
We have also been subject to interest rate market risk for
short-term invested cash and cash equivalents. The principal of
such invested funds would not be subject to fluctuating value
because of their highly liquid short-term nature. As of
June 30, 2006, we had $4.2 million invested in
short-term maturing investments.
Foreign Currency Exchange Rate Risk. We conduct business
in Mexico through our Mexican partner, Matyep. This business
exposes us to foreign exchange risk. To control this risk, we
provide for payment in U.S. dollars. However, we have
historically provided our partner a discount upon payment equal
to 50% of any loss suffered by our partner as a result of
devaluation of the Mexican peso between the date of invoicing
and the date of payment. To date, such payments have not been
material in amount.
66
OUR BUSINESS
Our Company
We provide services and equipment to oil and natural gas
exploration and production companies, domestically in Texas,
Louisiana, New Mexico, Colorado, Oklahoma, Mississippi, Utah,
Wyoming, offshore in the Gulf of Mexico, and internationally in
Mexico. DLS, which we acquired on August 14, 2006, is a
leading provider of drilling, completion, repair and related
services for oil and gas wells in Argentina. We operate in five
sectors of the oil and natural gas service industry: directional
drilling services; compressed air drilling services; casing and
tubing services; rental tools; and production services.
Providing high-quality, technologically advanced services and
equipment is central to our operating strategy. As a result of
our commitment to customer service, we have developed strong
relationships with many of the leading oil and natural gas
companies, including both independents and majors.
Our growth strategy is focused on identifying and pursuing
opportunities in markets we believe are growing faster than the
overall oilfield services industry in which we believe we can
capitalize on our competitive strengths. Over the past several
years, we have significantly expanded the geographic scope of
our operations and the range of services we provide through
internal growth and strategic acquisitions. Our organic growth
has primarily been achieved through expanding our geographic
scope, acquiring complementary equipment, hiring personnel to
service new regions and cross-selling our products and services
from existing operating locations. Since 2001, we have completed
16 acquisitions, including six in 2005 and three in 2006. In
January 2006, we acquired 100% of the outstanding stock of
Specialty for $96.0 million. Our acquisition of Specialty
not only balances our revenue mix generated between rental tools
and service operations and between onshore and offshore
operations, but also enhances the scope, capacity and customer
base in our rental tools business. In April 2006, we acquired
100% of the outstanding stock of Rogers for approximately
$13.7 million. Our acquisition of Rogers not only enhanced
our casing and tubing operations with its tubing, tongs and
casings services, but also increased our rental tools operations
with its inventory of rental equipment, including drill pipe
tongs, accessories, hydraulic power units and hydraulic tong
positioners. On August 14, 2006, we acquired 100% of the
outstanding stock of DLS for approximately $93.7 million in
cash, 2.5 million newly issued shares of our common stock
and approximately $8.6 million of assumed debt. Our
acquisition of DLS has given us a significant entry into the
international drilling, workover and production business, and we
expect this entry to facilitate further international growth and
increase our opportunities to cross-sell existing Allis-Chalmers
products and services in the international markets. Giving
pro forma as adjusted effect to the Specialty transactions,
our recent acquisition of Rogers and the DLS transactions, we
would have generated revenues of $281.3 million, net income
of $7.1 million and EBITDA of $68.6 million for the
fiscal year ended December 31, 2005. Giving pro forma as
adjusted effect to the Rogers and DLS acquisitions, we would
have generated revenues of $191.6 million, net income of
$18.1 million and EBITDA of $51.6 million for the six
months ended June 30, 2006.
Our History
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We were incorporated in 1913 under Delaware law. |
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We reorganized in bankruptcy in 1988 and sold all of our major
businesses. From 1988 to May 2001 we had only one operating
company in the equipment repair business. |
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In May 2001, under new management we consummated a merger in
which we acquired OilQuip Rentals, Inc., or OilQuip, and its
wholly-owned subsidiary, Mountain Compressed Air, Inc., or
Mountain Air. |
67
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In December 2001, we sold Houston Dynamic Services, Inc., our
last pre-bankruptcy business. |
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In February 2002, we acquired approximately 81% of the capital
stock of Allis-Chalmers Tubular Services Inc., or Tubular,
formerly known as Jens Oilfield Service, Inc. and
substantially all of the capital stock of Strata Directional
Technology, Inc., or Strata. |
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In July 2003, we entered into a limited liability company
operating agreement with M-I LLC, or M-I, a joint venture
between Smith International and Schlumberger N.V., to form a
Delaware limited liability company named AirComp LLC, or
AirComp. Pursuant to this agreement, we owned 55% and
M-I owned 45% of
AirComp. |
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In September 2004, we acquired the remaining 19% of the capital
stock of Tubular. |
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In September 2004, we acquired all of the outstanding stock of
Safco-Oil Field Products, Inc., or Safco. |
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In November 2004, AirComp acquired substantially all of the
assets of Diamond Air Drilling Services, Inc. and Marquis Bit
Co., LLC, which we refer to collectively as Diamond Air. |
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In December 2004, we acquired Downhole Injection Services, LLC,
or Downhole. |
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In January 2005, we changed our name from Allis-Chalmers
Corporation to Allis-Chalmers Energy Inc. |
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In April 2005, we acquired Delta Rental Service, Inc., or Delta,
and, in May 2005, we acquired Capcoil Tubing Services, Inc. or
Capcoil. |
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In July 2005, we acquired
M-Is interest in
AirComp, and acquired the compressed air drilling assets of W.T.
Enterprises, Inc., or W.T. |
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Effective August 2005, we acquired all of the outstanding stock
of Target Energy Inc., or Target. |
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In September 2005, we acquired the casing and tubing assets of
IHS/Spindletop, a division of Patterson Services, Inc., or
Patterson a subsidiary of RPC, Inc. |
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In January 2006, we acquired all of the outstanding stock of
Specialty. |
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In April 2006, we acquired all of the outstanding capital stock
of Rogers. |
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On August 14, 2006, we acquired all of the outstanding
capital stock of DLS. |
As a result of these transactions, our prior results may not be
indicative of current or future operations of those sectors.
Overview of Oilfield Services Industry
We provide products and services primarily to domestic onshore
and offshore oil and natural gas exploration and production
companies. The main factor influencing demand for our products
and services is the level of drilling activity by oil and
natural gas companies, which, in turn, depends largely on
current and anticipated future crude oil and natural gas prices
and production depletion rates. According to the Energy
Information Agency of the U.S. Department of Energy, or
EIA, from 1990 to 2005, demand for oil and natural gas in the
United States grew at an average annual rate of 1.5%, while
supply decreased at an average annual rate of just over 2%.
Current industry forecasts suggest an increasing demand for oil
and natural gas coupled with a flat or declining production
curve, which we believe should result in the continuation of
historically high crude oil and natural gas commodity prices.
The EIA forecasts that U.S. oil and natural gas consumption
will increase at an average annual rate of
68
1.4% and 1.3% through 2025, respectively. Conversely, the EIA
estimates that U.S. oil production will remain flat, and
natural gas production will increase at an average annual rate
of 0.6%.
We anticipate that oil and natural gas exploration and
production companies will continue to increase capital spending
for their exploration and drilling programs. In recent years,
much of this expansion has focused on natural gas drilling
activities. According to Baker Hughes rig count data, the
average total rig count in the United States increased 92% from
918 in 2000 to 1,762 on August 18, 2006, while the
average natural gas rig count increased 98% from 720 in 2000 to
1,427 on August 18, 2006. While the number of rigs
drilling for natural gas has increased by approximately 200%
since the beginning of 1996, natural gas production has only
increased by approximately 1.5% over the same period of time.
This is largely a function of increasing decline rates for
natural gas wells in the United States. We believe that a
continued increase in drilling activity will be required for the
natural gas industry to help meet the expected increased demand
for natural gas in the United States.
We believe oil and natural gas producers are becoming
increasingly focused on their core competencies in identifying
reserves and reducing burdensome capital and maintenance costs.
In addition, we believe our customers are currently
consolidating their supplier bases to streamline their
purchasing operations and benefit from economies of scale.
Competitive Strengths
We believe the following competitive strengths will enable us to
capitalize on future opportunities:
Strategic position in high growth markets. We focus on
markets we believe are growing faster than the overall oilfield
services industry and in which we can capitalize on our
competitive strengths. Pursuant to this strategy, we have become
a leading provider of products and services in what we believe
to be two of the fastest growing segments of the oilfield
services industry: directional drilling and air drilling. We
employ approximately 75 full-time directional drillers, and
we believe our ability to attract and retain experienced
drillers has made us a leader in the segment. We also believe we
are one of the largest air drillers based on amount of air
drilling equipment. In addition, we have significant operations
in what we believe will be among the higher growth oil and
natural gas producing regions within the United States and
internationally, including the Barnett Shale in North Texas,
onshore and offshore Louisiana, the Piceance Basin in Southern
Colorado and all five oil and natural gas producing regions in
Mexico.
Strong relationships with diversified customer base. Our
diverse customer base is characterized by strong relationships
with many of the major and independent oil and natural gas
producers and service companies throughout Texas, Louisiana, New
Mexico, Colorado, Oklahoma, Mississippi, Utah, Wyoming, offshore
in the Gulf of Mexico and Mexico. Our largest customers include
Burlington Resources, ConocoPhilips, BP, ChevronTexaco,
Kerr-McGee, Dominion Resources, Remington Oil and Gas, Petrohawk
Energy, Newfield Exploration, El Paso Corporation, Matyep
and Anadarko Petroleum. Since 2002, we have broadened our
customer base as a result of our acquisitions, technical
expertise and reputation for quality customer service and by
providing customers with technologically advanced equipment and
highly skilled operating personnel.
Successful execution of growth strategy. Over the past
five years, we have grown both organically and through
successful acquisitions of competing businesses. Since 2001, we
have completed 16 acquisitions. Our approach is to improve the
operating performance of the businesses we acquire by increasing
their asset utilization and operating efficiency. These
acquisitions have expanded our geographic presence and customer
base and, in turn, have enabled us to cross-sell various
products and services through our existing operating locations.
69
Experienced and dedicated management team. The members of
our executive management team have extensive experience in the
energy sector, and consequently have developed strong and
longstanding relationships with many of the major and
independent exploration and production companies. We believe
that our management team has demonstrated its ability to grow
our businesses organically, make strategic acquisitions and
successfully integrate these acquired businesses into our
operations.
Business Strategy
The key elements of our growth strategy include:
Expand geographically to provide greater access and service
to key customer segments. We have recently opened new
locations in Texas, New Mexico, Colorado, Oklahoma and Louisiana
in order to enhance our proximity to customers and more
efficiently serve their needs. We intend to continue to
establish new locations in active oil and natural gas producing
regions in the United States and internationally in order to
increase the utilization of our equipment and personnel. Our
acquisition of DLS will also allow us to provide a platform for
further international growth and increase our opportunities to
cross-sell existing Allis-Chalmers products and services in the
international markets.
Prudently pursue strategic acquisitions. To complement
our organic growth, we seek to opportunistically complete, at
attractive valuations, strategic acquisitions that will
complement our products and services, expand our geographic
footprint and market presence, further diversify our customer
base and be accretive to earnings.
Expand products and services provided in existing operating
locations. Since the beginning of 2003, we have invested
approximately $42.0 million in capital expenditures to grow
our business organically by expanding our product and service
offerings in existing operating locations. This strategy is
consistent with our belief that oil and natural gas producers
more heavily favor integrated suppliers that can provide a broad
product and service offering in many geographic locations.
Increase utilization of assets. We seek to grow revenues
and enhance margins by continuing to increase the utilization of
our rental assets with new and existing customers. We expect to
accomplish this through leveraging longstanding relationships
with our customers and cross-selling our suite of services and
equipment, while taking advantage of continued improvements in
industry fundamentals. We also expect to continue to implement
this strategy in our recently expanded rental tools segment,
thus improving the utilization and profitability of this newly
acquired business with minimal additional investment.
Target services in which we have a competitive advantage.
Consolidation in the oilfield services industry has created an
opportunity for us to compete effectively in markets that are
underserved by the large oilfield services and equipment
companies. In addition, we believe we can provide a more
comprehensive range of products and services than many of our
smaller competitors.
Business Segments
Prior to our acquisition of DLS, our five business segments were:
Directional Drilling Services. Through Strata and Target,
we utilize
state-of-the-art
equipment to provide well planning and engineering services,
directional drilling packages, downhole motor technology, well
site directional supervision, exploratory and development
re-entry drilling, downhole guidance services and other drilling
services to our customers. We also provide
logging-while-drilling and measurement-while-drilling services.
We have a team of approximately 75 full-time directional
drillers and maintain a selection of approximately 150 drilling
motors. According to Baker Hughes, as of February 2006, 40% of
all wells in the United States are drilled directionally and/or
horizontally. We
70
expect that figure to grow over the next several years as
companies seek to exploit maturing fields and sensitive
formations. Management believes directional drilling offers
several advantages over conventional drilling including:
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improvement of total cumulative recoverable reserves; |
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improved reservoir production performance beyond conventional
vertical wells; and |
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reduction of the number of field development wells. |
Since 2002, we have increased our team of directional drillers
from ten to approximately 75. Our straight hole drilling motors
offer opportunity to capture additional market share. We have
also recently expanded our directional drilling services segment
with the acquisition of all of the outstanding capital stock of
Target.
Rental Tools. We provide specialized rental equipment,
including premium drill pipe, heavy weight spiral drill pipe,
tubing work strings, blow out preventors, choke manifolds and
various valves and handling tools, for both onshore and offshore
well drilling, completion and workover operations. Most wells
drilled for oil and natural gas require some form of rental
tools in the completion phase of a well. Our rental tools
segment was established with the acquisition of Safco in
September 2004 and of Delta in April 2005.
We have an inventory of specialized equipment consisting of
heavy weight spiral drill pipe, double studded adaptors, test
plugs, wear bushings, adaptor spools, baskets and spacer spools
and other assorted handling tools in various sizes to meet our
customers demands. We charge customers for rental
equipment on a daily basis. The customer is liable for the cost
of inspection and repairs or lost equipment. We currently
provide rental tool equipment in Texas, Oklahoma, Louisiana,
Mississippi, Colorado and offshore in the Gulf of Mexico.
We significantly expanded our rental tools segment in January
2006 with the acquisition of Specialty. Specialty has been in
the rental tools business for over 25 years, providing oil
and natural gas operators and oilfield services companies with
rental equipment. Specialty rents drill pipe, heavy weight
spiral drill pipe, tubing work strings, blow out preventors,
choke manifolds and various valves and handling tools for oil
and natural gas drilling. The acquisition of Specialty gives us
a broader scope of rental tools to offer our existing customer
base, which we believe will allow us to better compete in deep
water drilling operations in the area of premium rental drill
pipe and handling equipment. We also expect that the acquisition
of Specialty will add new customer relationships and enhance our
relationships with key existing customers. In February of 2006,
we merged Specialty and Delta into Safco and named the new
entity, Allis-Chalmers Rental Tools, Inc. or Rental Tools.
Casing and Tubing Services. Through Tubular, we provide
specialized equipment and trained operators to perform a variety
of pipe handling services, including installing casing and
tubing, changing out drill pipe and retrieving production tubing
for both onshore and offshore drilling and workover operations,
which we refer to as casing and tubing services. All wells
drilled for oil and natural gas require casing to be installed
for drilling, and if the well is producing, tubing will be
required in the completion phase. We currently provide casing
and tubing services primarily in Texas, Louisiana and both
onshore and offshore in the Gulf of Mexico and Mexico. We
expanded our casing and tubing services in September 2005 by
acquiring the casing and tubing assets of IHS/ Spindletop, a
division of Patterson, a subsidiary of RPC, Inc. We paid
$15.7 million for RPC, Inc.s casing and tubing
assets, which consisted of casing and tubing installation
equipment, including hammers, elevators, trucks, pickups, power
units, laydown machines, casing tools and torque turn equipment.
71
The acquisition of RPC, Inc.s casing and tubing assets
increased our capability in casing and tubing services and
expanded our geographic capability. We opened new field offices
in Corpus Christi, Texas, Kilgore, Texas, Lafayette, Louisiana
and Houma, Louisiana. The acquisition allowed us to enter the
East Texas and Louisiana market for casing and tubing services
as well as offshore in the Gulf of Mexico. Additionally, the
acquisition greatly expanded our premium tubing services.
We provide equipment used in casing and tubing services in
Mexico to Materiales y Equipo Petroleo, S.A. de C.V., or Matyep.
Matyep provides equipment and services for offshore and onshore
drilling operations to Petroleos Mexicanos, known as Pemex, in
Villahermosa, Reynosa, Veracruz and Ciudad del Carmen, Mexico.
Matyep provides all personnel, repairs, maintenance, insurance
and supervision for provision of the casing and tubing crew and
torque turn service. The term of the lease agreement pursuant to
which we provide the equipment and Matyep provides the above
listed items continues for as long as Matyep is successful in
maintaining its casing and tubing business with Pemex. Services
to offshore drilling operations in Mexico are traditionally
seasonal, with less activity during the first quarter of each
calendar year due to weather conditions.
For the years ended December 31, 2005, 2004 and 2003, our
Mexico operations accounted for approximately $6.4 million,
$5.1 million and $3.7 million, respectively, of our
revenues. We provide extended payment terms to Matyep and
maintain a high accounts receivable balance due to these terms.
The accounts receivable balance was approximately
$2.2 million at December 31, 2005 and approximately
$968,000 at December 31, 2004. Tubular has been providing
services to Pemex in association with Matyep since 1997.
Compressed Air Drilling Services. Through AirComp, we
provide compressed air, drilling chemicals and other specialized
drilling products for underbalanced drilling applications, which
we refer to as compressed air drilling services. With a combined
fleet of over 130 compressors and boosters, we believe we are
one of the worlds largest providers of compressed air, or
underbalanced, drilling services. We also provide premium air
hammers and bits to oil and natural gas companies for use in
underbalanced drilling. Our broad and diversified product line
enables us to compete in the underbalanced drilling market with
an equipment package engineered and customized to specifically
meet customer requirements.
Underbalanced drilling shortens the time required to drill a
well and enhances production by minimizing formation damage.
There is a trend in the industry to drill, complete and workover
wells with underbalanced drilling operations and we expect the
market to continue to grow.
In July 2005, we purchased the compressed air drilling assets of
W.T., operating in West Texas and acquired the remaining 45%
equity interest in AirComp from M-I. The acquired assets include
air compressors, boosters, mist pumps, rolling stock and other
equipment. These assets were integrated into AirComps
assets and complement and add to AirComps product and
service offerings. We currently provide compressed air drilling
services in Texas, Oklahoma, New Mexico, Colorado, Utah and
Wyoming. We are also in the process of expanding our services to
Arkansas.
Production Services. We supply specialized equipment and
trained operators to install and retrieve capillary tubing,
through which chemicals are injected into producing wells to
increase production and reduce corrosion. In addition, we
perform workover services with coiled tubing units. Chemicals
are injected through the tubing to targeted zones up to depths
of approximately 20,000 feet. The result is improved
production from treatment of downhole corrosion, scale, paraffin
and salt build-up in
producing wells. Natural gas wells with low bottom pressures can
experience fluid accumulation in the tubing and well bore. This
injection system can inject a foaming agent which lightens the
fluids allowing them to flow out of the well. Additionally,
corrosion inhibitors can be introduced to reduce corrosion in
the well. Our production services segment was established with
the acquisition of Downhole, in
72
December 2004, and the acquisition of Capcoil, in May 2005. In
February of 2006, we merged Downhole into Capcoil and named the
new entity Allis-Chalmers Production Services, Inc., or
Production Services.
We have an inventory of specialized equipment consisting of
capillary and coil tubing units in various sizes ranging from
1/4
to
11/4
along with nitrogen pumping and transportation equipment. We
have placed orders for two additional capillary units and two
additional coil tubing units for delivery in 2006. The new coil
tubing units range in size from
11/4
to
13/4.
We also maintain a full range of stainless and carbon steel
coiled tubing and related supplies used in the installation of
the tubing. We sell or rent the tubing and charge a fee for its
installation, servicing and removal, which includes the service
personnel and associated equipment on a turn key hourly basis.
We do not provide the chemicals injected into the well.
In addition to the businesses mentioned above, we recently
entered into the contract drilling and repair services business
in Argentina and Bolivia when we completed our acquisition of
DLS on August 14, 2006. See DLS
Business.
Cyclical Nature of Oilfield Services Industry
The oilfield services industry is highly cyclical. The most
critical factor in assessing the outlook for the industry is the
worldwide supply and demand for oil and the domestic supply and
demand for natural gas. The peaks and valleys of demand are
further apart than those of many other cyclical industries. This
is primarily a result of the industry being driven by commodity
demand and corresponding price increases. As demand increases,
producers raise their prices. The price escalation enables
producers to increase their capital expenditures. The increased
capital expenditures ultimately result in greater revenues and
profits for services and equipment companies. The increased
capital expenditures also ultimately result in greater
production which historically has resulted in increased supplies
and reduced prices.
Demand for our services has been strong throughout 2003, 2004
and 2005. Management believes demand will remain strong
throughout 2006 due to high oil and natural gas prices and the
capital expenditure plans of the exploration and production
companies. Because of these market fundamentals for natural gas,
management believes the long-term trend of activity in our
markets is favorable. However, these factors could be more than
offset by other developments affecting the worldwide supply and
demand for oil and natural gas products.
Customers
In 2005, none of our customers accounted for more than 10% of
our revenues. Our customers are the major independent oil and
natural gas companies operating in the United States and Mexico.
In 2004, Matyep in Mexico represented 10.8% and Burlington
Resources Inc. represented 10.1% of our consolidated revenues.
In 2003, Matyep represented 10.2%, Burlington Resources Inc.
represented 11.1% and El Paso Corporation represented
14.1%, of our revenues. The loss without replacement of our
larger existing customers could have a material adverse effect
on our results of operations.
Suppliers
The equipment utilized in our business is generally available
new from manufacturers or at auction. Currently, due to the high
level of activity in the oilfield services industry, there is a
high demand for new and used equipment. Consequently, there is a
limited amount of many types of equipment available at auction
and significant backlogs on new equipment. We own sufficient
equipment for our projected operations over the next twelve
months, and we believe the shortage of equipment will result in
73
increased demand for our services. However, the cost of
acquiring new equipment to expand our business could increase as
a result of the high demand for equipment in the industry.
Competition
We experience significant competition in all areas of our
business. In general, the markets in which we compete are highly
fragmented, and a large number of companies offer services that
overlap and are competitive with our services and products. We
believe that the principal competitive factors are technical and
mechanical capabilities, management experience, past performance
and price. While we have considerable experience, there are many
other companies that have comparable skills. Many of our
competitors are larger and have greater financial resources than
we do.
We believe that there are five major directional drilling
companies, Schlumberger, Halliburton, Baker Hughes, W-H Energy
Services (Pathfinder) and Weatherford, that market both
worldwide and in the United States as well as numerous small
regional players.
Our largest competitor for compressed air drilling services is
Weatherford. Weatherford focuses on large projects, but also
competes in the more common compressed air, mist, foam and
aerated mud drilling applications. Other competition comes from
smaller regional companies.
Two large companies, Franks Casing Crew and Rental Tools
and Weatherford, have a substantial portion of the casing and
tubing market in South Texas. The market remains highly
competitive and fragmented with numerous casing and tubing crew
companies working in the United States. Our primary competitors
in Mexico are South American Enterprises and Weatherford, both
of which provide similar products and services.
There are two other significant competitors in the chemical
injection services portion of the production services market,
Weatherford and Dyna Coil. We believe we own approximately 30%
of the capillary tubing units in the southwestern United States
that are used for chemical injection services.
The rental tool business is highly fragmented with hundreds of
companies offering various rental tool services. Our largest
competitors include Weatherford, Oil and Gas Rental Tools, Quail
Rental Tools and Knight Rental Tools.
Backlog
We do not view backlog of orders as a significant measure for
our business because our jobs are short-term in nature,
typically one to 30 days, without significant on-going
commitments.
Employees
Our strategy includes acquiring companies with strong management
and entering into long-term employment contracts with key
employees in order to preserve customer relationships and assure
continuity following acquisition. We believe we have good
relations with our employees, none of whom are represented by a
union. We actively train employees across various functions,
which we believe is crucial to motivate our workforce and
maximize efficiency. Employees showing a higher level of
skill are trained on more technologically complex equipment
and given greater responsibility. All employees are responsible
for on-going quality assurance. At August 1, 2006, we had
approximately 780 employees.
74
Insurance
We carry a variety of insurance coverages for our operations,
and we are partially self-insured for certain claims in amounts
that we believe to be customary and reasonable. However, there
is a risk that our insurance may not be sufficient to cover any
particular loss or that insurance may not cover all losses.
Finally, insurance rates have in the past been subject to wide
fluctuation, and changes in coverage could result in less
coverage, increases in cost or higher deductibles and retentions.
Federal Regulations and Environmental Matters
Our operations are subject to federal, state and local laws and
regulations relating to the energy industry in general and the
environment in particular. Environmental laws have in recent
years become more stringent and have generally sought to impose
greater liability on a larger number of potentially responsible
parties. Because we provide services to companies producing oil
and natural gas, which are toxic substances, we may become
subject to claims relating to the release of such substances
into the environment. While we are not currently aware of any
situation involving an environmental claim that would likely
have a material adverse effect on us, it is possible that an
environmental claim could arise that could cause our business to
suffer. We do not anticipate any material expenditures to comply
with environmental regulations affecting our operations.
In addition to claims based on our current operations, we are
from time to time named in environmental claims relating to our
activities prior to our reorganization in 1988. See
Legal Proceedings.
Intellectual Property Rights
Except for our relationships with our customers and suppliers
described above, we do not own any patents, trademarks,
licenses, franchises or concessions which we believe are
material to the success of our business. As part of our overall
corporate strategy to focus on our core business of providing
services to the oil and natural gas industry and to increase
stockholder value, we are investigating the sale or license of
our worldwide rights to trade names and logos for products and
services outside the energy sector.
Description of Properties
The following table describes the location and general character
of the principal physical properties used in each of our
companys businesses as of August 1, 2006. All of the
properties are leased by us except for our property in Edinburg,
Texas.
|
|
|
Business Segment |
|
Location |
|
|
|
Directional Drilling Services
|
|
Houston, Texas |
|
|
Corpus Christi, Texas |
|
|
Oklahoma City, Oklahoma |
|
|
Lafayette, Louisiana |
75
|
|
|
Business Segment |
|
Location |
|
|
|
Compressed Air Drilling Services
|
|
Houston, Texas |
|
|
San Angelo, Texas |
|
|
Fort Stockton, Texas |
|
|
Farmington, New Mexico |
|
|
Grand Junction, Colorado |
|
|
Wilburton, Oklahoma |
|
|
Sonora, Texas |
|
|
Grandbury, Texas |
|
|
Denver, Colorado |
|
|
Carlsbad, New Mexico |
|
Casing and Tubing Services
|
|
Edinburg, Texas |
|
|
Pearsall, Texas |
|
|
Corpus Christi, Texas |
|
|
Kilgore, Texas |
|
|
Broussard, Louisiana |
|
|
Houma, Louisiana |
|
|
Buffalo, Texas |
|
Rental Tools
|
|
Houston, Texas |
|
|
Broussard, Louisiana |
|
|
Lafayette, Louisiana |
|
Production Services
|
|
Midland, Texas |
|
|
Corpus Christi, Texas |
|
|
Kilgore, Texas |
|
|
Carthage, Texas |
|
|
Cordell, Oklahoma |
|
General Corporate
|
|
Houston, Texas |
The yard in Buffalo, Texas is co-owned by David Wilde, who is
one of our executive officers.
Legal Proceedings
On June 29, 1987, we filed for reorganization under
Chapter 11 of the United States Bankruptcy Code. Our plan
of reorganization was confirmed by the Bankruptcy Court after
acceptance by our creditors and stockholders, and was
consummated on December 2, 1988.
At confirmation of our plan of reorganization, the United States
Bankruptcy Court approved the establishment of the A-C
Reorganization Trust as the primary vehicle for distributions
and the administration of claims under our plan of
reorganization, two trust funds to service health care and life
insurance programs for retired employees and a trust fund to
process and liquidate future product liability claims. The
trusts assumed responsibility for substantially all remaining
cash distributions to be made to holders of claims and interests
pursuant to our plan of reorganization. We were thereby
discharged of all debts that arose before confirmation of our
plan of reorganization.
We do not administer any of the aforementioned trusts and retain
no responsibility for the assets transferred to or distributions
to be made by such trusts pursuant to our plan of reorganization.
As part of our plan of reorganization, we settled
U.S. Environmental Protection Agency claims for cleanup
costs at all known sites where we were alleged to have disposed
of hazardous waste. The EPA settlement included both past and
future cleanup costs at these sites and released us of liability
to other
76
potentially responsible parties in connection with these
specific sites. In addition, we negotiated settlements of
various environmental claims asserted by certain state
environmental protection agencies.
Subsequent to our bankruptcy reorganization, the EPA and state
environmental protection agencies have in a few cases asserted
that we are liable for cleanup costs or fines in connection with
several hazardous waste disposal sites containing products
manufactured by us prior to consummation of our plan of
reorganization. In each instance, we have taken the position
that the cleanup costs and all other liabilities related to
these sites were discharged in the bankruptcy, and the cases
have been disposed of without material cost. A number of Federal
Courts of Appeal have issued rulings consistent with this
position, and based on such rulings, we believe that we will
continue to prevail in our position that our liability to the
EPA and third parties for claims for environmental cleanup costs
that had pre-petition triggers have been discharged. A number of
claimants have asserted claims for environmental cleanup costs
that had pre-petition triggers, and in each event, the A-C
Reorganization Trust, under its mandate to provide plan of
reorganization implementation services to us, has responded to
such claims, generally, by informing claimants that our
liabilities were discharged in the bankruptcy. Each of such
claims has been disposed of without material cost. However,
there can be no assurance that we will not be subject to
environmental claims relating to pre-bankruptcy activities that
would have a material, adverse effect on us.
The EPA and certain state agencies continue from time to time to
request information in connection with various waste disposal
sites containing products manufactured by us before consummation
of the plan of reorganization that were disposed of by other
parties. Although we have been discharged of liabilities with
respect to hazardous waste sites, we are under a continuing
obligation to provide information with respect to our products
to federal and state agencies. The A-C Reorganization Trust,
under its mandate to provide plan of reorganization
implementation services to us, has responded to these
informational requests because pre-bankruptcy activities are
involved.
We were advised in late 2005 that the A-C Reorganization Trust
is in the process of terminating and distributing its assets,
and as a result, we will assume the responsibility of responding
to claimants and to the EPA and state agencies previously
undertaken by the A-C Reorganization Trust. However, we have
been advised by the A-C Reorganization Trust that its cost of
providing these services has not been material in the past, and
therefore we do not expect to incur material expenses as a
result of responding to such requests. However, there can be no
assurance that we will not be subject to environmental claims
relating to pre-bankruptcy activities that would have a
material, adverse effect on us.
We are named as a defendant from time to time in product
liability lawsuits alleging personal injuries resulting from our
activities prior to our reorganization involving asbestos. These
claims are referred to and handled by a special products
liability trust formed to be responsible for such claims in
connection with our reorganization. As with environmental
claims, we do not believe we are liable for product liability
claims relating to our business prior to our bankruptcy;
moreover, the products liability trust continues to defend all
such claims. However, there can be no assurance that we will not
be subject to material product liability claims in the future.
We are involved in various other legal proceedings in the
ordinary course of businesses. The legal proceedings are at
different stages; however, we believe that the likelihood of
material loss relating to any such legal proceeding is remote.
77
DLS Business
General
DLS is a leading provider of drilling, completion, repair and
related services for oil and gas wells in Argentina, with,
through its predecessors, over 40 years experience in the
contract drilling and oilfield services industry. DLS previously
operated under different names and was established under its
existing name in the British Virgin Islands in 1993.
Headquartered in Buenos Aires, DLS operates out of the
San Jorge, Cuyan, Neuquén, Austral and Noroeste basins
of Argentina and the Subandina basin in Bolivia.
With approximately 1,566 employees, DLS currently services
several of the major and independent oil and natural gas
producing companies, including Pan American Energy, Repsol-YPF,
Apache Corporation (formerly Pioneer Natural Resources),
Occidental Petroleum Corporation (formerly Vintage Petroleum)
and Total Austral SA. Major competitors of DLS include Pride
International, Inc., Servicios WellTech, S.A., Ensign Energy
Services Inc. (formerly ODE), Nabors Industries Ltd. and
Helmerich & Payne, Inc.
DLS specializes in contract drilling, oil well completion and
repair services. DLS also offers a wide variety of other
oilfield services such as drilling fluids and completion fluids,
engineering, field maintenance and logistics to complement its
customers field organization. For the year ended
December 31, 2005, DLS generated revenues of
$71.6 million in its drilling rigs segment,
$39.4 million in its completion and repair segment (which
includes workover and pulling functions) and $18.8 million
in its drilling fluids/other services segment. For the six
months ended June 30, 2006, DLS generated revenues of
$48.3 million in its drilling segment, $24.0 million
in its completion and repair segment (which includes workover
and pulling functions) and $9.7 million in its drilling
fluids /other services segment.
DLS operates a fleet of 51 rigs, including 20 drilling rigs, 18
workover rigs and 12 pulling rigs in Argentina and one drilling
rig in Bolivia. Argentine rig operations are generally conducted
in remote regions of the country and require substantial
infrastructure and support. DLS believes that its established
infrastructure and scale of operations provide it with a
competitive advantage in this market. In Bolivia, DLS operates
one drilling rig. As of August 1, 2006, all of DLS
rig fleet was actively marketed, except for one drilling rig
that is presently inactive and requires approximately
$6.0 million in capital expenditures for upgrades.
Equipment and Services
A land drilling rig basically consists of a drawworks or hoist,
a derrick, a power plant, rotating equipment, pumps to circulate
the drilling fluid and the drill string. Power requirements for
drilling jobs may vary considerably, but most land drilling rigs
employ several engines to generate between 500 and 3,000
horsepower, depending on well depth and rig design. There are
numerous factors that differentiate land drilling rigs,
including their power generation systems and their drilling
depth capabilities.
The size and type of rig utilized depends, among other factors,
upon well depth and site conditions. An active maintenance and
replacement program during the life of a drilling rig permits
upgrading of components on an individual basis. Over the life of
a typical rig, due to the normal wear and tear of operating up
to 24 hours a day, several of the major components, such as
engines, air compressors, boosters and drill pipe, are replaced
or rebuilt on a periodic basis as required. Other components,
such as the substructure, mast and drawworks, can be utilized
for extended periods of time with proper maintenance.
78
As of August 1, 2006, DLS owned 21 drilling rigs, all of
which were actively marketed, except for one drilling rig that
is currently inactive and requires approximately
$6.0 million in capital expenditures for upgrades.
The workover rigs are quite similar to the drilling rigs,
however, they are smaller than the drilling rig for the same
depth of well. These rigs are used to complete the drilled wells
or to repair them whenever necessary.
The well completion process, to prepare a newly drilled oil or
natural gas well for production, involves selectively
perforating the well casing to access producing zones,
eventually stimulating and testing these zones and installing
the downhole equipment. The well completion process typically
requires a few days to several weeks, depending on the nature
and type of the completion. The demand for well completion
services is directly related to drilling activity levels, which
are highly sensitive to expectations relating to, and changes
in, oil and natural gas prices.
Workover services are performed to enhance the production of
existing wells or to repair the wells.
The workover rigs, identical to the rigs used for completion,
are used to seal off depleted zones in existing wellbores, open
new producing zones to enhance production or activate producing
zones using fracturing or acidifying processes. Workover rigs
are also used to convert former producing wells into water
injection wells through which water or carbon dioxide is pumped
into the formation to enhance the production of an oil field.
Other workover services include major subsurface repairs such as
casing repairs or replacement of deteriorated downhole equipment.
DLS workover rig fleet consisted of 18 rigs as of
August 1, 2006.
A pulling rig is a type of well-servicing rig used to pull
downhole equipment, such as tubing, rods or the pumps from a
well, and replace them when necessary. A pulling rig is also
used to set downhole tools and perform lighter jobs.
As of August 1, 2006, DLS operated a fleet of 12 pulling
rigs.
This segment consists of drilling fluids and completion fluids
supply and field maintenance.
Drilling fluid services. The required drilling fluid
characteristics depend on the type of formation drilled, the
encountered formation pressures and on the type of well. The
service provided by DLS is to determine the best mud for the
projected well and the consequent supply and engineering of the
drilling fluid.
Completion fluid services. Completion fluids are used
when completing an oil or gas well. This fluid is placed in the
well to control the wellbore pressures driving the completion
and prior to initiation of production, such as setting packers,
downhole valves and shooting perforations into the producing
zone. DLS engineers and supplies completion fluids for oil and
gas wells.
Field maintenance. DLS renders services for the operation
and maintenance of oilfields surface equipment and facilities.
These services may include constructing, repairing and
maintaining roads, laying-down production lines, maintaining
surface equipment and facilities, transporting solid and liquid
cargos and personnel, monitoring oil and gas delivery and
overall field management.
79
DLS drilling contracts are obtained either through
competitive bidding or through direct negotiations with its
customers. The majority of these contracts provide for
compensation on a dayrate basis. Under dayrate
contracts, DLS provides a drilling rig with the required
personnel to perform the drilling of the well. DLS is typically
paid based on a negotiated rate per day, comprised of both
U.S. dollars and Argentine pesos, while the rig is
utilized. The Argentine pesos portion is subject to inflation
adjustment. Additionally, most of these contracts are terminable
by either party on short notice. As a result, the contracts tend
to be subject to renegotiation.
The rates for DLS services depend on market and
competitive conditions, the nature of the operations to be
performed, the duration of the work, the equipment and services
to be provided, the geographic area involved and other
variables. Lower rates may be paid when the rig is in transit,
or when drilling operations are interrupted or restricted by
conditions beyond control. In addition, dayrate contracts
typically provide for a separate amount to cover the cost of
mobilization and demobilization of the drilling rig. Dayrate
drilling contracts specify the type of equipment to be used, the
general characteristic of the hole and the depth of the well.
Under a dayrate drilling contract, the customer bears a large
portion of
out-of-pocket costs of
drilling and DLS does not bear any part of the usual capital
risks associated with oil and natural gas exploration.
Pan American Energy contract. DLS and Pan American
Energy, a company that is 40% owned by an affiliate of the
current owners of DLS and 60% owned by British Petroleum,
entered into a five-year strategic agreement for the purpose of
solidifying a long-term alliance for the drilling of oil and gas
wells in the San Jorge basin. The completion and repair of
all wells in the area is also part of the agreement. The
strategic agreement expires on June 30, 2008 and DLS is
currently in negotiations to extend this agreement to December
2010. Pan American Energy represented approximately 55% of
DLS revenue in 2005. Pan American Energy may terminate the
agreement without cause on 60 days notice or in the
case of a spin-off or merger of DLS that is not consented to by
Pan American Energy. There is no provision allowing early
termination by DLS and there are no change of control
provisions. In accordance with the strategic agreement, DLS
shall ensure the availability of at least three drilling rigs,
eight workover rigs and five pulling rigs in order to meet Pan
American Energys drilling plans but, in turn, Pan American
Energy will provide DLS a sufficient number of drilling
locations to keep all such rigs and associated equipment working
during the term of the strategic agreement, provided that there
are no material changes in the price of oil or adverse results
of the production forecasts. The drilling rigs rates under the
agreement are subject to an efficiency factor for drilling
depths up to 2,700 meters. The agreement incorporates a standard
drilling time in hours for a typical drilling prospect up to
2,700 meters. Drilling beyond 2,700 meters or drilling prospects
with non-standard procedures are at agreed upon hourly rates
plus reimbursable materials and expenses.
DLS completion, workover or pulling contracts are obtained
in the same way and provide for compensation on a dayrate basis
comprised of both U.S. dollars and Argentine pesos and are
subject to inflation adjustment.
The most important drilling fluid service contract of DLS is
with Repsol-YPF, in the Neuquén basin. The term of the
contract expires in September 2006, and this contract covers
drilling and fluid services required in the area where
Repsol-YPF is drilling.
80
Other Business Data
DLS purchases a wide variety of raw materials as well as
components made by other manufacturers and suppliers for use in
its operations. Many of the products used by DLS are
manufactured by other parties. DLS is not dependent on any
single source of supply for any of its raw materials; however,
DLS has a long-term agreement with Tanus, who is a supplier of
chemical specialties used in drilling and completion fluid
service.
DLS principal customers consist of major and independent
oil and natural gas producing companies. Key customers include
Pan American Energy, Repsol-YPF, Apache Corporation (formerly
Pioneer Natural Resources), Occidental Petroleum Corporation
(formerly Vintage Petroleum) and Total Austral SA.
|
|
|
Government and Environmental
Regulations |
DLS drilling operations are subject to many hazards,
including blowouts and well fires, which could cause personal
injury, suspend drilling operations, seriously damage or destroy
the equipment involved and cause substantial damage to producing
formations or to the surrounding areas.
Many aspects of DLS operations are subject to government
regulation, as in the areas of equipping and operating vessels,
drilling practices and disposal of waste. In addition, various
countries have regulations relating to environmental protection
and pollution control. Recent events in the oil industry have
also increased the sensitivity of the oil and gas industry to
environmental matters.
DLS believes that its safety and environmental protection
standards are better than industry averages and that it complies
in all material respects with legislation and regulations
affecting the drilling of oil and gas wells and the discharge of
wastes. Regulatory compliance has not materially affected the
capital expenditures, earnings or competitive position of DLS to
date, although such measures do increase drilling costs. Further
regulations may reasonably be anticipated, but any effects
thereof on DLS drilling operations cannot be accurately
predicted.
Although DLS is subject to various ongoing items of litigation,
almost all of which relate to labor contracts, and DLS does not
believe any of the items of litigation to which it is currently
subject will result in any material uninsured losses to it. It
is possible, however, an unexpected judgment could be rendered
against DLS in the cases in which it is involved that could be
uninsured and beyond the amounts it currently has reserved.
DLS currently carries a variety of insurance for its operations
involving third-party liability insurance. DLS is partially
self-insured for certain claims in amounts it believes to be
customary and reasonable. DLS believes that it is adequately
insured for physical damage to its rigs, workers
compensation, automobile liability and for various other types
of exposures customarily encountered in its operations. Certain
of DLS liability insurance policies specifically exclude
coverage for fines, penalties and punitive or exemplary damages.
DLS anticipates that its present insurance coverage will be
maintained, but no assurance can be given that insurance
coverage will continue to be available at rates considered
reasonable, that self-
81
insured amounts or deductibles will not increase or that certain
types of coverage will be available at any cost.
As of August 1, 2006, DLS employed approximately 1,566
employees, including approximately 1,499 employees in Argentina
and approximately 67 employees in Bolivia. Almost all of
its operations are subject to collective bargaining agreements.
DLS believes that its relationship with its employees is very
good. Approximately 50% of its personnel have been with DLS for
more than five years and approximately 30% of its personnel have
been with DLS for more than ten years. In addition, DLS
maintains a satisfactory relationship with the unions.
82
OUR MANAGEMENT
Board of Directors and Executive Officers
Our executive officers and directors are:
|
|
|
|
|
|
|
Name |
|
Age | |
|
Position |
|
|
| |
|
|
Munawar H. Hidayatallah..
|
|
|
62 |
|
|
Chairman and Chief Executive Officer |
David Wilde
|
|
|
51 |
|
|
President and Chief Operating Officer |
Victor M. Perez
|
|
|
53 |
|
|
Chief Financial Officer |
Theodore F. Pound III
|
|
|
52 |
|
|
General Counsel and Secretary |
Bruce Sauers
|
|
|
42 |
|
|
Vice President and Corporate Controller |
David K. Bryan
|
|
|
49 |
|
|
President and Chief Operating Officer of Strata Directional
Technology, Inc. |
Steven Collins
|
|
|
54 |
|
|
President of Allis-Chalmers Production Services, Inc. |
James Davey
|
|
|
52 |
|
|
President of Allis-Chalmers Rental Tools Inc. |
Gary Edwards
|
|
|
54 |
|
|
President of Allis-Chalmers Tubular Services Inc. |
Terrence P. Keane
|
|
|
54 |
|
|
President and Chief Executive Officer of AirComp L.L.C |
Alejandro P. Bulgheroni
|
|
|
62 |
|
|
Director |
Carlos A. Bulgheroni
|
|
|
61 |
|
|
Director |
John E. McConnaughy, Jr.
|
|
|
77 |
|
|
Director(1) |
Victor F. Germack
|
|
|
66 |
|
|
Director(1) |
Robert E. Nederlander
|
|
|
73 |
|
|
Director(1) |
Jeffrey R. Freedman
|
|
|
59 |
|
|
Director |
Leonard Toboroff
|
|
|
73 |
|
|
Vice Chairman |
|
|
(1) |
Member of Audit Committee. |
Munawar H. Hidayatallah has served as our Chairman of the
Board and Chief Executive Officer since May 2001, and was
President from May 2001 through February 2003.
Mr. Hidayatallah was Chief Executive Officer of OilQuip
from its formation in February 2000 until it merged with us in
May 2001. From December 1994 until August 1999,
Mr. Hidayatallah was the Chief Financial Officer and a
director of IRI International, Inc., which was acquired by
National Oilwell, Inc. in early 2000. IRI International, Inc.
manufactured, sold and rented oilfield equipment to the oilfield
and natural gas exploration and production sectors. From August
1999 until February 2001, Mr. Hidayatallah worked as a
consultant to IRI International, Inc. and Riddell Sports Inc.
David Wilde became our President and Chief Operating
Officer in February 2005. Mr. Wilde was President and Chief
Executive Officer of Strata from October 2003 through February
2005 and served as Stratas President and Chief Operating
Officer from July 2003 until October 2003. From February 2002
until July 2003, Mr. Wilde was our Executive Vice President
of Sales and Marketing. From May 1999 until February 2002,
Mr. Wilde served as Sales and Operations Manager at Strata.
Mr. Wilde has more than 30 years experience in
the directional drilling and rental tool sectors of the oilfield
services industry.
Victor M. Perez became our Chief Financial Officer in
August 2004. From July 2003 to July 2004, Mr. Perez was a
private consultant engaged in corporate and international
finance advisory. From February 1995 to June 2003,
Mr. Perez was Vice President and Chief Financial Officer of
Trico Marine Services, Inc., a marine transportation company
serving the offshore energy industry. Trico Marine
83
Services, Inc. filed a petition under the federal bankruptcy
laws in December 2004. Mr. Perez was Vice President of
Corporate Finance with Offshore Pipelines, Inc., an oilfield
marine construction company, from October 1990 to January 1995,
when that company merged with a subsidiary of McDermott
International. Mr. Perez also has 15 years of
experience in international energy banking. Mr. Perez is a
director of Safeguard Security Holdings.
Theodore F. Pound III became our General Counsel in
October 2004 and was elected Secretary in January 2005. For ten
years prior to joining us, he practiced law with the law firm of
Wilson, Cribbs & Goren, P.C., Houston, Texas.
Mr. Pound has practiced law for more than 25 years.
Mr. Pound represented us as our lead counsel in each of our
acquisitions beginning in 2001.
Bruce Sauers has served as our Vice President and
Corporate Controller since July 2005. From January 2005 until
July 2005, Mr. Sauers was Controller of Blast Energy Inc.,
an oilfield services company. From June 2004 until January 2005,
Mr. Sauers worked as a financial and accounting consultant.
From July 2003 until June 2004, Mr. Sauers served as
controller for HMT, Inc., an above ground storage tank company.
From February 2003 until July 2003, Mr. Sauers served as
assistant controller at Todco, an offshore drilling contractor.
From August 2002 until January 2003, Mr. Sauers acted as a
consultant on SEC accounting and financial matters. From
December 2001 through June 2002, Mr. Sauers was corporate
controller at OSCA, Inc., an oilfield services company, which
merged with BJ Service Company. From December 1996 until
December 2001, Mr. Sauers was a corporate controller at UTI
Energy Corp., a land drilling contractor, which merged and
became Patterson-UTI Energy, Inc. Mr. Sauers is a certified
public accountant and has served as an accountant for
approximately 20 years.
David K. Bryan has served as President and Chief
Operating Officer of Strata since February 2005. Mr. Bryan
served as Vice President of Strata from June 2002 until February
2005. From February 2002 to June 2002, he served as General
Manager, and from May 1999 through February 2002, he served as
Operations Manager of Strata. Mr. Bryan has been involved
in the directional drilling sector since 1979.
Steven Collins has served as President of Production
Services since December 2005. Mr. Collins was our corporate
Vice President of Sales and Marketing from June 2005 to December
2005. From 2002 to 2005, Mr. Collins served as Sales
Manager of Well Testing and Corporate Strategic
Accounts Manager for TETRA Technologies. From 1997 to 2002,
Mr. Collins was in sales for Production Well Testers.
Mr. Collins has over 25 years experience in
various sales and management positions in the oilfield services
industry.
James Davey has served as President of Rental Tools since
April 2005. Mr. Davey was President of Safco Oilfield
Products from September 2004 through 2005 and served as our
Executive Vice President of Business Development and
Acquisitions in October 2003 until 2004. Prior to joining us,
Mr. Davey had been employed with CooperCameron for
28 years in various positions.
Gary Edwards has served as President of Tubular since
December 2005 after serving as Executive Vice President of
Tubular since September 2005. From April 1997 to September 2005,
Mr. Edwards served as Operations Manager for IHS/
Spindletop Tubular Services, a division of Patterson.
Mr. Edwards has been in the casing and tubing industry for
the past 29 years.
Terrence P. Keane has served as President and Chief
Executive Officer of our AirComp subsidiary since its formation
on July 1, 2003, and served as a consultant to M-I in the
area of compressed air drilling from July 2002 until June 2003.
From March 1999 until June 2002, Mr. Keane served as Vice
President and General Manager Exploration,
Production and Processing Services for Gas Technology Institute
where Mr. Keane was responsible for all sales, marketing,
operations and research and development of the exploration,
production and processing business unit. For more than ten years
prior
84
to joining the Gas Technology Institute, Mr. Keane had
various positions with Smith International, Inc., Houston,
Texas, most recently in the position of Vice President Worldwide
Operations and Sales for Smith Tool.
Alejandro P. Bulgheroni was appointed to our board of
directors on August 14, 2006. Mr. Bulgheroni has
served as the Chairman of the Management Committee of Pan
American Energy LLC, an oil and gas company, since November
1997. He also served as the Chairman of Bridas SAPIC from 1988
until 1997. He has served as Vice-Chairman and Executive
Vice-President of Bridas Corporation since 1993. He also serves
as Chairman of Associated Petroleum Investors Ltd., an
international oil and gas holding company, and as Chairman and
President of Bridas International Holdings Ltd.
Mr. Bulgheroni is a member of the Petroleum and Gas
Argentine Institute and of the Society of Petroleum Engineers
(USA), Vice-President of the Argentine Chamber of Hydrocarbons
Producers (CEPH), Vice-President of the Argentine-Uruguayan
Chamber of Commerce, Counselor of the Buenos Aires Stock
Exchange and Counselor of the Argentine Business Council for
Sustainable Development (CEADS). Mr. Bulgheroni is a
graduate of the University of Buenos Aires with a degree in
Industrial Engineering.
Carlos A. Bulgheroni was appointed to our board of
directors on August 14, 2006. Mr. Bulgheroni has
served as the Chairman and President of Bridas Corporation, an
international oil and gas holding company, since 1993. He has
been a member of the Management Committee of Pan American Energy
LLC since November 1997. He is also a member of the
International Council of the Center for Strategic and
International Studies (CSIS-Washington), of the International
Committee of The Kennedy Center for the Performing Arts and of
the Executive Board of the International Chamber of Commerce
(ICC-Paris). Mr. Bulgheroni is a graduate of the University
of Buenos Aires Law School.
John E. McConnaughy, Jr. was appointed to our board
of directors in May 2004. Mr. McConnaughy has served as
Chairman and Chief Executive Officer of JEMC Corporation, a
personal holding company, since he founded it in 1985. His
career includes positions of management with Westinghouse
Electric and the Singer Company, as well as service as a
director of numerous public and private companies. In addition,
he previously served as Chairman and Chief Executive Officer of
Peabody International Corp. and Chairman and Chief Executive
Officer of GEO International Corp. He retired from Peabody in
February 1986 and GEO in October 1992. Mr. McConnaughy
currently serves on the boards of Wave Systems Corp., Consumer
Portfolio Services, Inc., Overhill Farms, Inc., Levcor
International, Inc. and Arrow Resources Development Inc. He also
serves as Chairman of the Board of Trustees of the Strang Cancer
Prevention Center and as Chairman Emeritus for the Harlem School
of the Arts.
Victor F. Germack was appointed to our board of directors
in January 2005. Mr. Germack has served since 1980 as
President of Heritage Capital Corp., a company engaged in
investment banking services. In addition, Mr. Germack
formed, and since 2002 has been President of, RateFinancials
Inc., a company that rates and ranks the financial reporting of
U.S. public companies.
Robert E. Nederlander has served as our director since
May 1989. Mr. Nederlander served as our Chairman of the
board of directors from May 1989 to 1993, and as our Vice
Chairman of the board of directors from 1993 to 1996.
Mr. Nederlander has been a Director of Cendant Corp. since
December 1997 and Chairman of the Corporate Governance Committee
of Cendant Corp. since 2002. Mr. Nederlander was a director
of HFS, Inc. from July 1995 to December 1997. Since November
1981, Mr. Nederlander has been President and/or Director of
the Nederlander Organization, Inc., owner and operator of
legitimate theaters in New York City. Since December 1998,
Mr. Nederlander has been a managing partner of the
Nederlander Company, LLC, operator of legitimate theaters
outside New York City. Mr. Nederlander was Chairman of the
board of directors of Varsity Brands, Inc. (formerly Riddell
85
Sports Inc.) from April 1988 to September 2003 and was the Chief
Executive Officer of such corporation from 1988 through
April 1, 1993. Mr. Nederlander has been a limited
partner and a director of the New York Yankees since 1973.
Mr. Nederlander has been President of Nederlander
Television and Film Productions, Inc. since October 1985. In
addition, from January 1988 to January 2002,
Mr. Nederlander was Chairman of the Board and Chief
Executive Officer of Mego Financial Corp., beginning in January
1988 and resigned all positions in January 2002. The new
management changed Megos name to Leisure Industries
Corporation of America and later filed a voluntary petition
under Chapter 11 of the U.S. federal bankruptcy code
in July 2003.
Jeffrey R. Freedman was appointed to our board of
directors in January 2005. Mr. Freedman served as our
Executive Vice President Corporate Development from
January 2002 to November 2002. Since January 2003,
Mr. Freedman has been involved in real estate development
in South Florida. From 1994 through March 2002,
Mr. Freedman was Managing Director Oil Services
and Equipment for Prudential Securities with responsibilities
for institutional equity research of oilfield services and
contract drilling companies in the U.S. public markets.
Mr. Freedman has been involved and held various positions
with major institutional brokerage firms in equity research
relating to the oil service sector over the last 20 years.
Leonard Toboroff has served as our director and Vice
Chairman of the board of directors since May 1989 and served as
our Executive Vice President from May 1989 until February 2002.
Mr. Toboroff served as a director and Vice President of
Varsity Brands, Inc. (formerly Riddell Sports Inc.) from April
1988 through October 2003, and he is also a director of Engex
Corp. and NOVT Corporation. Mr. Toboroff is currently a
managing (executive) director of Corinthian Capital, a
private equity firm. Mr. Toboroff has been a practicing
attorney continuously since 1961.
Board of Directors; Committees
Our board currently has nine members who serve for a term of one
year or until their successors are elected and take office. Our
board of directors currently has three standing committees: the
Audit Committee, the Nominating Committee and the Compensation
Committee.
Our Audit Committee consists of three directors,
Mr. McConnaughy and Mr. Germack, who serve as
Co-Chairmen, and Mr. Nederlander. All of our Audit
Committee members are independent under the
applicable American Stock Exchange and SEC rules regarding audit
committee membership. Our board of directors has determined that
Mr. Germack qualifies as an audit committee financial
expert under applicable SEC rules and regulations
governing the composition of the Audit Committee. We pay
Mr. Germack an additional $30,000 per year for serving as
our audit committee financial expert.
The Audit Committee assists our board of directors in fulfilling
its oversight responsibility by overseeing and evaluating
(i) the conduct of our accounting and financial reporting
process and the integrity of the financial statements that will
be provided to stockholders and others; (ii) the
functioning of our systems of internal accounting and financial
controls; and (iii) the engagement, compensation,
performance, qualifications and independence of our independent
auditors. Our board of directors adopted a written Audit
Committee charter in March 2002, which was amended in May 2004.
The charter is reviewed annually and revised as appropriate. A
copy of the Audit Committee charter is available on our website
(www.alchenergy.com). Information on our website is not
incorporated into this prospectus and is not a part of this
prospectus.
86
The independent auditors have unrestricted access and report
directly to the Audit Committee. The Audit Committee meets
privately with, and has unrestricted access to, the independent
auditors and all of our personnel.
The Audit Committee has selected UHY Mann Frankfort
Stein & Lipp CPAs, LLP as our independent auditors for
the fiscal year ended December 31, 2005 and initially
selected UHY Mann Frankfort Stein & Lipp CPAs, LLP as our
independent auditors for the fiscal year ended December 31,
2006. On June 1, 2006, the partners of UHY Mann Frankfort
Stein & Lipp CPAs, LLP announced that they were joining
UHY LLP, a New York limited liability partnership. UHY LLP is
the independent registered public accounting firm with which UHY
Mann Frankfort Stein & Lipp CPAs, LLP has an
affiliation. UHY LLP is a legal entity that is separate from UHY
Mann Frankfort Stein & Lipp CPAs, LLP. On June 15,
2006, UHY Mann Frankfort Stein & Lipp CPAs, LLP
notified us that it has ceased to provide audit services to us,
and accordingly, resigned as our independent auditors on that
date. On June 15, 2006, the Audit Committee engaged UHY LLP
as our independent auditors for our fiscal year ending
December 31, 2006.
The Compensation Committee formulates and oversees the execution
of our compensation strategies, including by making
recommendations to our board of directors with respect to
compensation arrangements for senior management, directors and
other key employees. The Compensation Committee also administers
our 2003 Incentive Stock Plan. Our board of directors has
adopted a charter for the Compensation Committee, a copy of
which is available on our website (www.alchenergy.com).
Information on our website is not incorporated into this
prospectus and is not a part of this prospectus.
The Nominating Committee of our board of directors was
established in January 2005 to select nominees for the board of
directors. We have no formal procedure pursuant to which
stockholders may recommend nominees to our board of directors or
Nominating Committee, and the board of directors believes that
the lack of a formal procedure will not hinder the consideration
of qualified nominees. The Nominating Committee utilizes a
variety of methods for identifying and evaluating nominees for
directors. Candidates may come to the attention of the
Nominating Committee through current board members, stockholders
and other persons. Our board of directors has adopted a charter
for the Nominating Committee, a copy of which is available on
our website (www.alchenergy.com). Information on our
website is not incorporated into this prospectus and is not a
part of this prospectus.
87
Executive Compensation
The following table sets forth the compensation paid or awarded
by us in 2005, 2004 and 2003 to (i) our Chief Executive
Officer and (ii) our four other most highly compensated
executive officers as of December 31, 2005. In this
prospectus, we refer to the individuals described in the
immediately preceding sentence as our named executive officers.
Summary Compensation Table
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long Term | |
|
|
|
|
Compensation | |
|
|
Annual Compensation | |
|
Awards | |
|
|
| |
|
| |
|
|
|
|
Salary | |
|
Bonus | |
|
Other Annual | |
|
Securities Underlying | |
Name and Principal Position |
|
Year | |
|
($) | |
|
($) | |
|
Compensation(1) | |
|
Options/SARs (#) | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
Munawar H. Hidayatallah,
|
|
|
2005 |
|
|
|
395,833 |
|
|
|
200,000 |
|
|
|
3,000 |
|
|
|
725,000 |
|
|
Chairman & Chief Executive Officer |
|
|
2004 |
|
|
|
337,500 |
|
|
|
580,000 |
(2)(3) |
|
|
3,375 |
|
|
|
|
|
|
|
|
|
2003 |
|
|
|
300,000 |
(4) |
|
|
81,775 |
(3) |
|
|
3,000 |
|
|
|
400,000 |
|
David Wilde,
|
|
|
2005 |
|
|
|
299,004 |
|
|
|
100,000 |
|
|
|
2,340 |
|
|
|
290,000 |
|
|
President and Chief Operating |
|
|
2004 |
|
|
|
209,964 |
|
|
|
275,000 |
(6) |
|
|
1,672 |
|
|
|
110,000 |
|
|
Officer(5) |
|
|
2003 |
|
|
|
137,500 |
|
|
|
75,445 |
(7) |
|
|
1,876 |
|
|
|
100,000 |
|
Victor M. Perez,
|
|
|
2005 |
|
|
|
240,000 |
|
|
|
60,000 |
|
|
|
600 |
|
|
|
45,000 |
|
|
Chief Financial Officer(8) |
|
|
2004 |
|
|
|
105,000 |
|
|
|
5,500 |
|
|
|
2,500 |
|
|
|
55,000 |
|
Terrence P. Keane,
|
|
|
2005 |
|
|
|
164,000 |
|
|
|
82,000 |
(10) |
|
|
1,640 |
|
|
|
50,000 |
|
|
Divisional President and Chief |
|
|
2004 |
|
|
|
146,308 |
|
|
|
51,650 |
(11) |
|
|
|
|
|
|
|
|
|
Executive Officer of AirComp(9) |
|
|
2003 |
|
|
|
68,440 |
|
|
|
|
|
|
|
|
|
|
|
|
|
David Bryan,
|
|
|
2005 |
|
|
|
176,917 |
|
|
|
150,000 |
(13) |
|
|
1,849 |
|
|
|
40,000 |
|
|
President and Chief Operating Officer |
|
|
2004 |
|
|
|
156,050 |
|
|
|
100,000 |
(14) |
|
|
1,800 |
|
|
|
|
|
|
of Strata(12) |
|
|
2003 |
|
|
|
140,000 |
|
|
|
14,000 |
(15) |
|
|
4,050 |
|
|
|
30,000 |
|
|
|
|
(1) |
Represents contributions to 401(k) plans. We match contributions
made by all employees up to a maximum 1% of each employees
salary. |
|
|
|
(2) |
Of this amount $175,000 was paid in 2005. |
|
|
|
(3) |
The bonus awarded to Mr. Hidayatallah for fiscal year 2003
was determined pursuant to his 2001 employment agreement, based
on acquisitions completed for fiscal year 2003, and the bonus
for fiscal year 2004 was based on Mr. Hidayatallahs
attaining certain strategic objectives set forth in his 2004
employment agreement (see Employment
Agreements with Management below). |
|
|
|
(4) |
Of this amount, $60,000 was deferred and paid during 2004. |
|
|
|
(5) |
Mr. Wilde was President and Chief Executive Officer of
Strata, one of our subsidiaries, until February 2005, when he
was named as our President and Chief Operating Officer. |
|
|
|
(6) |
Of this amount, $62,500 was paid in 2005. |
|
|
|
(7) |
Of this amount, $30,000 was paid in 2004. |
|
|
|
(8) |
Mr. Perez became our Chief Financial Officer in August 2004. |
|
|
|
(9) |
Mr. Keane serves as the President and Chief Executive
Officer of AirComp, one of our subsidiaries and, as such, is
considered an executive officer. |
|
|
|
|
(10) |
Of this amount, $82,000 was paid in 2006. |
|
|
|
(11) |
Of this amount, $16,150 was paid in 2005. |
|
|
|
(12) |
Mr. Bryan serves as the President and Chief Operating
Officer of Strata and, as such, is considered an executive
officer. |
|
|
|
(13) |
Of this amount, $20,794 was paid in 2006. |
|
88
|
|
|
(14) |
Of this amount, $31,250 was paid in 2005. |
|
|
|
(15) |
Of this amount, $14,000 was paid in 2004. |
|
|
|
|
Option Grants In Last Fiscal
Year |
The following table provides information concerning stock
options granted to our named executive officers during 2005. All
the grants were options to purchase shares of common stock and
were made under our 2003 Incentive Stock Plan. No stock
appreciation rights were granted during 2005.
|
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|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Individual Grants | |
|
Potential Realized | |
|
|
| |
|
Value at Assumed Annual | |
|
|
Number of | |
|
% of Total | |
|
|
|
Rates of Stock Price | |
|
|
Securities | |
|
Options/SARs | |
|
Exercise | |
|
|
|
Appreciation for Option | |
|
|
Underlying | |
|
Granted to | |
|
Price | |
|
|
|
Terms(3) | |
|
|
Options/SARs | |
|
Employees | |
|
per Share | |
|
Expiration | |
|
| |
Name |
|
Granted(1) | |
|
in 2005 | |
|
($/Sh)(2) | |
|
Date | |
|
5% ($) | |
|
10% ($) | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Munawar H. Hidayatallah
|
|
|
125,000 |
|
|
|
7.47 |
% |
|
$ |
10.85 |
|
|
|
12/16/2015 |
|
|
$ |
852,938 |
|
|
$ |
2,161,513 |
|
|
|
|
|
600,000 |
|
|
|
35.86 |
% |
|
$ |
3.86 |
|
|
|
2/02/2015 |
|
|
$ |
1,456,520 |
|
|
$ |
3,691,108 |
|
David Wilde
|
|
|
90,000 |
|
|
|
5.38 |
% |
|
$ |
10.85 |
|
|
|
12/16/2015 |
|
|
$ |
614,116 |
|
|
$ |
1,556,290 |
|
|
|
|
|
200,000 |
|
|
|
11.95 |
% |
|
$ |
3.86 |
|
|
|
2/02/2015 |
|
|
$ |
485,507 |
|
|
$ |
1,230,369 |
|
Victor M. Perez
|
|
|
45,000 |
|
|
|
2.69 |
% |
|
$ |
10.85 |
|
|
|
12/16/2015 |
|
|
$ |
307,058 |
|
|
$ |
778,145 |
|
Terrence P. Keane
|
|
|
25,000 |
|
|
|
1.49 |
% |
|
$ |
4.87 |
|
|
|
5/25/2015 |
|
|
$ |
76,568 |
|
|
$ |
194,038 |
|
|
|
|
|
25,000 |
|
|
|
1.49 |
% |
|
$ |
10.85 |
|
|
|
12/16/2015 |
|
|
$ |
170,588 |
|
|
$ |
432,303 |
|
David Bryan
|
|
|
20,000 |
|
|
|
1.20 |
% |
|
$ |
3.86 |
|
|
|
2/02/2015 |
|
|
$ |
48,551 |
|
|
$ |
123,037 |
|
|
|
|
|
20,000 |
|
|
|
1.20 |
% |
|
$ |
4.87 |
|
|
|
5/25/2015 |
|
|
$ |
61,254 |
|
|
$ |
155,231 |
|
|
|
|
(1) |
All options were granted under our 2003 Incentive Stock Plan.
All options granted by us to date vest and become exercisable in
three equal installments, one of which vested upon the grant of
the options and one of which will vest upon each of the first
and second anniversaries of the date of grant of option,
provided that all options will become fully exercisable upon the
occurrence of a change of control (as defined in the 2003
Incentive Stock Plan). |
|
|
|
(2) |
The exercise price for these options is equal to the fair market
value of the common stock on the date of grant. The exercise
price may be paid in cash or in shares of common stock valued at
the fair market value on the exercise date. |
|
|
|
(3) |
The 5% and 10% assumed rates of appreciation are prescribed by
the rules and regulations of the SEC and do not represent our
estimate or projection of the future trading prices of our
common stock. The calculations assume annual compounding and
continued retention of the options or the underlying common
stock by the optionee for the full option term of ten years.
Unless the market price of the common stock actually appreciates
over the option term, no value will be realized by the optionee
from these option grants. Actual gains, if any, on stock option
exercises are dependent on numerous factors, including, without
limitation, our future performance, overall business and market
conditions, and the optionees continued employment with us
throughout the entire vesting period and option term, which
factors are not reflected in this table. |
|
|
|
|
Option Exercises and Year-End
Option Values |
The following table sets forth, with respect to our named
executive officers, the number of options exercised during 2005,
the value of unexercised options held at December 31, 2005,
and the value of all
89
options held by such persons on December 31, 2005, based
upon the closing price of our common stock on such date.
Aggregated Option/ SAR Exercises In Last Fiscal Year
and FY-End Option/ SAR Values
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Number of Securities | |
|
Value of Unexercised | |
|
|
|
|
|
|
Underlying Unexercised | |
|
In-the-Money | |
|
|
|
|
|
|
Options/SARs | |
|
Options/SARs | |
|
|
|
|
|
|
at Fiscal Year-End (#) | |
|
at Fiscal Year-End ($)(1) | |
|
|
Shares | |
|
Value Realized | |
|
| |
|
| |
|
|
Acquired (#) | |
|
($) | |
|
Exercisable | |
|
Unexercisable | |
|
Exercisable | |
|
Unexercisable | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Munawar H. Hidayatallah
|
|
|
|
|
|
|
|
|
|
|
841,667 |
|
|
|
283,333 |
|
|
|
7,399,501 |
|
|
|
1,856,995 |
|
David Wilde
|
|
|
|
|
|
|
|
|
|
|
336,666 |
|
|
|
163,334 |
|
|
|
2,727,395 |
|
|
|
950,605 |
|
Victor M. Perez
|
|
|
|
|
|
|
|
|
|
|
51,667 |
|
|
|
48,333 |
|
|
|
303,703 |
|
|
|
188,297 |
|
Terrence P. Keane
|
|
|
|
|
|
|
|
|
|
|
16,666 |
|
|
|
33,334 |
|
|
|
76,830 |
|
|
|
153,620 |
|
David Bryan
|
|
|
|
|
|
|
|
|
|
|
50,000 |
|
|
|
20,000 |
|
|
|
457,066 |
|
|
|
158,734 |
|
|
|
(1) |
Based on a value of $12.47 per share, the closing price per
share on the American Stock Exchange on December 31, 2005,
less the exercise price. |
|
|
|
Employment Agreements With
Management |
We have entered into written employment agreements with our
executive officers as described below. Each employment agreement
(other than the agreement of Mr. Keane, which is described
below) provides that if the executive officers employment
is terminated by us for any reason other than cause,
as defined in the employment agreement, or death or disability,
or if the executive officer is Constructively
Terminated, as defined in the agreement (which definition
includes a change in control of us if the executive officer does
not continue employment with us or our successor), then he is
entitled to receive his then current salary for the entire term
of his contract, reduced by any amounts he earns for services
during the severance period.
Munawar H. Hidayatallah serves as our Chairman and Chief
Executive Officer pursuant to the terms of a three-year
employment agreement dated as of April 1, 2004. Under the
terms of the employment agreement, Mr. Hidayatallah
receives an annual base salary of $400,000 subject to annual
increase in the discretion of the board of directors. In
addition, Mr. Hidayatallah is entitled to receive a bonus
in an amount equal to 100% of his base salary if he meets
certain strategic objectives specified in the agreement, and if
he meets some but not all of such objectives may be granted a
bonus as determined by the Compensation Committee of the board
of directors. Mr. Hidayatallah received a signing bonus of
$230,000 but will be required to return a pro rata portion of
such bonus if his employment is terminated for any reason prior
to April 1, 2007. Pursuant to the agreement, we also
maintain a term life insurance policy in the amount of
$2,500,000 the proceeds of which would be used to repurchase
shares of our common stock from Mr. Hidayatallahs
estate in the event of his death. The number of shares purchased
would be determined based upon the fair market value of our
common stock, as determined by a third party experienced in
valuations of this type, appointed by us.
David Wilde serves as President and Chief Operating Officer
pursuant to the terms of a three-year employment agreement dated
as of April 1, 2004. Under the terms of the employment
agreement, Mr. Wilde receives an annual base salary of
$300,000 subject to annual review and potentially an increase by
our board of directors, and Mr. Wilde is entitled to
receive a bonus in an amount equal to up to 100% of his base
salary, 50% of which is based on meeting quarterly and annual
operating income targets. The bonus calculation is subject to
adjustment in subsequent years.
90
Victor M. Perez serves as our Chief Financial Officer pursuant
to the terms of a three-year employment agreement dated as of
July 26, 2004. Under the terms of the employment agreement,
Mr. Perez receives an annual base salary of $240,000
subject to annual review and potentially an increase by our
board of directors. In addition, Mr. Perez is entitled to
receive a bonus in an amount equal to up to 50% of his base
salary if he meets certain strategic objectives specified in his
employment agreement.
Terrence P. Keane, President and Chief Executive Officer of our
subsidiary AirComp L.L.C., a Delaware limited liability company,
is employed pursuant to an employment agreement dated
July 1, 2003, which has a term of four years. Under the
terms of this agreement, Mr. Keane is entitled to base
salary of $164,000 and to a bonus of up to 90% of his base
salary based upon AirComp meeting earnings targets established
by AirComps Management Committee. If Mr. Keanes
employment is terminated by AirComp without cause or by
Mr. Keane for good reason (as such terms are defined in the
agreement), Mr. Keane will be entitled to receive his
accrued bonus, if any, and to continue to receive salary and
medical benefits for a period of six months. In addition, if a
change in control (as defined in the agreement) occurs with
respect to AirComp, and Mr. Keane does not accept
employment with AirComps successor, then Mr. Keane
will be entitled to receive his accrued bonus, if any, to
continue to receive salary for a period of 24 months, and
to continue to receive medical benefits for a period of
12 months.
David Bryan was appointed as the President and Chief Operating
Officer of Strata in February 2005 pursuant to the terms of a
three-year employment agreement dated as of April 1, 2004.
Under the terms of the employment agreement, Mr. Bryan
receives an annual base salary of $175,000 subject to annual
review and potentially an increase by our board of directors. In
addition, Mr. Bryan is entitled to receive a bonus based on
Stratas earnings before taxes, interest and depreciation
provided that Strata met designated minimum earnings targets and
provided further that such bonus shall not exceed 100% of
Mr. Bryans base salary. The bonus calculation is
subject to adjustment in subsequent years.
Board Compensation
Our policy is to pay our independent directors a fee of
$5,000 per quarter beginning in 2005.
Messrs. Hidayatallah, Mortensen and Toboroff are not deemed
independent for this purpose. Each independent director serving
on a committee of the board of directors will receive $1,250
quarterly for service on such committee and each independent
director serving as chairman of a committee of the board of
directors will receive an additional $1,250 per quarter for
acting as chairman of such committee. In addition, our
audit committee financial expert receives $7,500 on
a quarterly basis. In 2004 we did not pay directors any
compensation for their services as directors. Directors are also
compensated for
out-of-pocket travel
expenses.
In April 2004, we entered into an oral consulting agreement with
Mr. Toboroff pursuant to which we paid him $10,000 per
month during the 2005 fiscal year to advise us regarding
financing and acquisition opportunities. Effective as of the
first quarter of 2006, we pay Mr. Toboroff $12,000 per
month pursuant to the agreement.
Compensation Committee Interlocks And Insider
Participation
No current executive officer has ever served as a member of the
board of directors or compensation committee of any other entity
(other than our subsidiaries) that has or has had one or more
executive officers serving as a member of our board or our
Compensation Committee.
91
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
On August 14, 2006, in connection with the consummation of
the DLS acquisition (and the related transactions contemplated
by the stock purchase agreement governing the DLS acquisition),
we entered into an investors rights agreement with the DLS
sellers pursuant to which we:
|
|
|
|
|
granted the DLS sellers the right to designate two nominees for
election to our board of directors, |
|
|
|
agreed to support the nominations of the persons designated by
the DLS sellers, and |
|
|
|
agreed to use our best efforts to cause the board (and our
nominating committee) to recommend the inclusion of such persons
in the slate of nominees recommended to stockholders for
election as directors at each annual meeting of our stockholders. |
Effective upon the closing of the DLS acquisition, Thomas O.
Whitener, Jr. and Jens H. Mortensen, Jr. resigned as
directors of our company, and the DLS sellers (pursuant their
rights as set forth in the investors rights agreement)
designated Alejandro P. Bulgheroni and Carlos A. Bulgheroni as
nominees to fill the board vacancies created by the resignations
of Mr. Whitener and Mr. Mortensen. In accordance with
the provisions of the investors rights agreement, the board
appointed Alejandro P. Bulgheroni and Carlos A. Bulgheroni to
the board upon receipt of the nominations.
Alejandro P. Bulgheroni and Carlos A. Bulgheroni indirectly
beneficially own substantially all of the outstanding capital
stock of the DLS sellers and, as a result, have a material
interest in the transactions contemplated by the stock purchase
agreement and the investors rights agreement, including our
acquisition of DLS. Alejandro P. Bulgheroni indirectly
beneficially owns approximately 1.5 million shares and
Carlos A. Bulgheroni indirectly beneficially owns approximately
1.0 million shares, in each case, out of the
2.5 million shares of our common stock that was issued to
the DLS sellers as the stock component of the purchase price for
the DLS acquisition.
As more fully discussed in this prospectus under the heading
Risk Factors, a majority of DLS revenues are
currently received pursuant to a strategic agreement with Pan
American Energy, a joint venture that is owned 60% by British
Petroleum and 40% by Bridas Corporation, an affiliate of the DLS
sellers. Alejandro P. Bulgheroni and Carlos A. Bulgheroni
indirectly beneficially own substantially all of the outstanding
capital stock of Bridas Corporation and, as a result, have a
material interest in the transactions contemplated by the
strategic agreement between DLS and Pan American Energy.
92
SECURITY OWNERSHIP OF
CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The following table sets forth the beneficial ownership of our
outstanding common stock as of August 15, 2006 for:
|
|
|
|
|
our chief executive officer and each of our four other most
highly compensated executive officers as of December 31,
2005; |
|
|
|
each of our directors; |
|
|
|
all of our directors and executive officers as a group; and |
|
|
|
each other person known by us to be a beneficial owner of more
than 5.0% of our outstanding common stock. |
Beneficial ownership is determined in accordance with the rules
of the SEC. Under the rules of the SEC, a person is deemed to be
a beneficial owner of a security if that person has
or shares voting power, which includes the power to
vote or to direct the voting of such security, or
investment power, which includes the power to
dispose of or to direct the disposition of such security. A
person is also deemed to be a beneficial owner of any securities
of which that person has a right to acquire beneficial ownership
within 60 days. Under these rules, more than one person may
be deemed a beneficial owner of the same securities and a person
may be deemed a beneficial owner of securities as to which he
has no economic interest. Except as indicated by footnote, the
persons named in the table below have sole voting and investment
power with respect to all shares shown as beneficially owned by
them, subject to community property laws where applicable.
|
|
|
|
|
|
|
|
|
|
|
|
Number of | |
|
Percentage of | |
|
|
Shares | |
|
Common Stock | |
|
|
Beneficially | |
|
Beneficially | |
Name and Address |
|
Owned | |
|
Owned(1) | |
|
|
| |
|
| |
Named executive officers:
|
|
|
|
|
|
|
|
|
|
Munawar H. Hidayatallah(2)
|
|
|
1,686,666 |
|
|
|
6.9 |
|
|
David Wilde(3)
|
|
|
286,633 |
|
|
|
1.2 |
|
|
Victor M. Perez(4)
|
|
|
70,000 |
|
|
|
* |
|
|
Terence P. Keane(5)
|
|
|
25,000 |
|
|
|
* |
|
|
David Bryan(6)
|
|
|
68,666 |
|
|
|
* |
|
Directors:
|
|
|
|
|
|
|
|
|
|
Alejandro P. Bulgheroni(7)
|
|
|
1,500,000 |
|
|
|
6.1 |
|
|
Carlos A. Bulgheroni(8)
|
|
|
1,000,000 |
|
|
|
4.1 |
|
|
John E. McConnaughy, Jr.(9)
|
|
|
100,000 |
|
|
|
* |
|
|
Victor F. Germack(10)
|
|
|
|
|
|
|
|
|
|
Robert E. Nederlander(11)
|
|
|
715,594 |
|
|
|
2.9 |
|
|
Jeffrey R. Freedman(12)
|
|
|
119,000 |
|
|
|
* |
|
|
Leonard Toboroff(13)
|
|
|
695,594 |
|
|
|
2.8 |
|
All directors and executive officers as a group
(17 persons)
|
|
|
6,402,152 |
|
|
|
25.6 |
|
Other 5% holders:
|
|
|
|
|
|
|
|
|
|
Palo Alto Investors(14)
|
|
|
2,208,767 |
|
|
|
9.0 |
|
|
Jens H. Mortensen, Jr.(15)
|
|
|
1,600,591 |
|
|
|
6.5 |
|
93
|
|
(1) |
Based upon an aggregate of 24,464,260 shares outstanding as
of August 15, 2006. |
|
|
(2) |
Mr. Hidayatallah is the trustee of the Hidayatallah Family
Trust, which is the record owner of 1,686,666 shares of our
common stock, and Mr. Hidayatallah holds options to
purchase 283,333 shares of common stock, none of which
options are exercisable within 60 days.
Mr. Hidayatallahs address is 5075 Westheimer,
Suite 890, Houston, TX 77056. |
|
(3) |
Mr. Wilde holds options to
purchase 408,300 shares of common stock, of which
281,633 are exercisable within 60 days.
Mr. Wildes address is 5075 Westheimer,
Suite 890, Houston, TX 77056. |
|
(4) |
Mr. Perez holds options to
purchase 100,000 shares of common stock, of which
70,000 are exercisable within 60 days.
Mr. Perezs address is 5075 Westheimer,
Suite 890, Houston, TX 77056. |
|
(5) |
Mr. Keane holds options to purchase 50,000 shares
of common stock, of which 25,000 are exercisable within
60 days. Mr. Keanes address is
5075 Westheimer, Suite 890, Houston, TX 77056. |
|
(6) |
Mr. Bryan holds options to
purchase 70,000 shares of common stock, of which
56,666 are exercisable within 60 days.
Mr. Bryans address is 5075 Westheimer,
Suite 890, Houston, TX 77056. |
|
(7) |
Includes (i) 1,000,000 shares held of record by Bridas
International Holdings Limited, a British Virgin Islands
international business company, and
(ii) 500,000 shares held of record by Associated
Petroleum Investors Ltd., a British Virgin Islands international
business company. Each such entity is indirectly beneficially
owned by Mr. Bulgheroni. Mr. Bulgheronis address
is 5075 Westheimer, Suite 890, Houston, TX 77056. |
|
(8) |
Includes 1,000,000 shares held of record by Bridas Central
Company Ltd., a British Virgin Islands international business
company, which is indirectly beneficially owned by
Mr. Bulgheroni. Mr. Bulgheronis address is 5075
Westheimer, Suite 890, Houston, TX 77056. |
|
(9) |
Mr. McConnaughys address is 2 Parklands Drive,
Darien, CT 06820. |
|
(10) |
Mr. Germacks address is 845 3rd Avenue,
Suite 1410, New York, NY 10022. |
|
(11) |
Includes 715,594 shares of common stock owned directly by
Mr. Nederlander or by RER Corp. or QEN Corp., corporations
controlled by Mr. Nederlander. Mr. Nederlanders
address is 1450 Broadway, Suite 2001, New York, NY
10018. |
|
(12) |
Mr. Freedmans address is 123 Via Verde Way, Palm
Beach, FL 33418. |
|
(13) |
Mr. Toboroffs address is 1450 Broadway,
Suite 2001, New York, NY 10018. |
|
(14) |
Owned collectively by Micro Cap Partners, L.P., UBTI Free, L.P.
and Palo Alto Global Energy Fund, L.P. Palo Alto Investors, LLC
acts as the general partner of Micro Cap Partners, L.P., UBTI
Free, L.P. and Palo Alto Global Energy Fund, L.P. Palo Alto
Investors, Inc. is the manager of Palo Alto Investors, LLC, and
William L. Edwards is the President of Palo Alto Investors, Inc.
Palo Alto Investors, LLC, Palo Alto Investors, Inc. and William
L. Edwards each have investment and voting authority with
respect to the shares owned by this stockholder. The business
address for each of these persons is 470 University Avenue,
Palo Alto, CA 94301. |
|
|
(15) |
Mr. Mortensens address is 5075 Westheimer,
Suite 890, Houston, TX 77056. |
94
DESCRIPTION OF OTHER INDEBTEDNESS
New Senior Secured Credit Facility
On January 18, 2006, we amended and restated our previous
credit agreement (which we signed in July 2005), resulting in a
new four-year, $25.0 million senior secured revolving
credit facility with a syndicate of lenders led by Royal Bank of
Canada, as administrative agent and collateral agent. Our
borrowing capacity under this new facility is available to
finance working capital requirements and other general corporate
purposes, including permitted acquisitions (as defined in the
credit agreement) and the issuance of standby letters of credit.
The terms of this facility are as described below.
Borrowings under the credit agreement will mature on
January 18, 2010. The credit agreement requires us to repay
the facility prior to maturity by an amount equal to
(i) 100% of the net cash proceeds of certain asset sales
(other than inventory and obsolete equipment in the ordinary
course of business) by us or our subsidiaries (including sales
of stock of our subsidiaries) and 100% of insurance proceeds, to
the extent such proceeds exceed a cumulative basket equal to 5%
of our consolidated assets (as determined in accordance with the
credit agreement), subject to a
180-day reinvestment
period, (ii) 100% of the net cash proceeds from the
issuance of any unsecured debt after January 18, 2006
(subject to permitted exceptions, including the issuance of the
notes and (iii) 100% of the net cash proceeds from the
issuance of our equity securities after such date (subject to
permitted exceptions). Amounts under the facility may be repaid
and reborrowed prior to the final maturity date. As of
June 30, 2006, after giving effect to the DLS transactions,
as if each such transaction had occurred on that date, we would
have had approximately $11.7 million of unused availability
under our credit facility.
All borrowings under our new facility are subject to the
satisfaction of usual and customary conditions, including the
accuracy of representations and warranties and the absence of
defaults.
All of our existing and future direct and indirect subsidiaries
are required to guarantee our obligations under the credit
agreement. Borrowings under the credit facility and any related
guarantees are secured by a first priority lien on (i) all
of our and our subsidiaries fixed assets and (ii) all
of our and our subsidiaries accounts receivable,
inventory, equipment, general intangibles, deposit accounts and
other material assets and properties, including the stock and
other outstanding equity interests of our subsidiaries.
The interest under the credit agreement is payable at rates per
annum based on the London Interbank Offered Rate, or LIBOR, or
an alternate base rate, or ABR. Under the credit agreement, ABR
loans may be prepaid at any time without penalty. LIBOR loans
may be prepaid without penalty, subject to our reimbursement of
certain breakage and redeployment costs.
|
|
|
Covenants and Events of
Default |
The credit agreement contains covenants customary for agreements
of this type, including, but not limited to, limitations on our
ability to: (i) incur additional indebtedness and
guarantees, (ii) create liens and other encumbrances on our
assets, (iii) consolidate, merge or sell assets,
(iv) pay dividends and other distributions or repurchase
stock, (v) make certain investments, loans and advances,
(vi) make capital expenditures, (vii) enter into
operating leases and sale/leaseback transactions,
(viii) enter into transactions with our affiliates,
(ix) change the character of our business, (x) engage
in hedging activities
95
unless certain requirements are satisfied and (xi) prepay
other debt. Also, we are required to comply with certain
financial tests and maintain certain financial ratios. These
financial tests and ratios include requirements to maintain:
(i) a maximum ratio of total funded debt to EBITDA,
(ii) a maximum ratio of senior secured debt to EBITDA,
(iii) a minimum ratio of EBITDA to interest expense,
(iv) a minimum tangible net worth, (v) a minimum
current ratio and (vi) a minimum fixed asset coverage ratio.
The credit agreement also includes customary representations,
warranties and events of default, including events of default
relating to non-payment of principal, interest or fees,
violation of covenants, inaccuracy of representations and
warranties, the termination of or default under any material
agreement, the result of which could reasonably be expected to
have a material adverse effect, material and uncured judgments,
bankruptcy and insolvency events, cross-defaults and a default
in the event of a change of control. An event of default under
the credit agreement will permit the lenders to accelerate the
maturity of the indebtedness under the facility, and may result
in one or more cross-defaults under other indebtedness,
including the notes. Similarly, a default generally under the
indenture governing the notes will constitute an event of
default under the credit agreement.
Of the aggregate $25.0 million of capacity under the credit
agreement, $5.0 million is available for the issuance of
standby letters of credit.
On August 8, 2006, we entered into an amendment to the
credit agreement. The amendment, among other things, amended the
credit agreement to (a) allow us to (i) issue and sell
$95.0 million aggregate principal amount of our old notes
and (ii) issue and sell 3,450,000 shares of our common
stock, (b) allow us to use the net proceeds from the notes
offering and the common stock offering to purchase all the
outstanding capital stock of DLS, (c) exclude certain
existing indebtedness and investments of DLS and investments and
indebtedness related to the DLS acquisition from the covenants
contained in the credit agreement and (d) increase the
amount of permitted lease obligations and capital expenditures.
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THE EXCHANGE OFFER
Exchange Terms
Old notes in an aggregate principal amount of $255,000,000 are
currently issued and outstanding. The maximum aggregate
principal amount of new notes that will be issued in exchange
for old notes is $255,000,000. The terms of the new notes and
the old notes are substantially the same in all material
respects, except that the new notes will not contain terms with
respect to transfer restrictions, registration rights and
payments of liquidated damages.
The new notes will bear interest at a rate of 9.0% per
year, payable semi-annually on January 15 and July 15
of each year, beginning on January 15, 2007. Holders of new
notes will receive interest from July 15, 2006, the date of
the last payment of interest on the old notes. Holders of new
notes will not receive any interest on old notes tendered and
accepted for exchange. In order to exchange your old notes for
transferable new notes in the exchange offer, you will be
required to make the following representations, which are
included in the letter of transmittal:
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any new notes that you receive will be acquired in the ordinary
course of your business; |
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you are not participating, and have no arrangement or
understanding with any person or entity to participate, in the
distribution of the new notes; |
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you are not our affiliate, as defined in
Rule 405 under the Securities Act, or a broker-dealer
tendering old notes acquired directly from us for resale
pursuant to Rule 144A or any other available exemption
under the Securities Act; and |
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if you are not a broker-dealer, that you are not engaged in and
do not intend to engage in the distribution of the new notes. |
Upon the terms and subject to the conditions set forth in this
prospectus and in the letter of transmittal, we will accept for
exchange any old notes properly tendered in the exchange offer,
and the exchange agent will deliver the new notes promptly after
the expiration date of the exchange offer.
If you tender your old notes, you will not be required to pay
brokerage commissions or fees or, subject to the instructions in
the letter of transmittal, transfer taxes with respect to the
exchange of the old notes in connection with the exchange offer.
We will pay all charges, expenses and transfer taxes in
connection with the exchange offer, other than the taxes
described below under Transfer Taxes.
We make no recommendation to you as to whether you should
tender or refrain from tendering all or any portion of your
existing old notes into this exchange offer. In addition, no one
has been authorized to make this recommendation. You must make
your own decision whether to tender into this exchange offer
and, if so, the aggregate amount of old notes to tender after
reading this prospectus and the letter of transmittal and
consulting with your advisors, if any, based on your financial
position and requirements.
Expiration Date; Extensions; Termination; Amendments
The exchange offer expires at 5:00 p.m., New York City
time,
on ,
2006, unless we extend the exchange offer, in which case the
expiration date will be the latest date and time to which we
extend the exchange offer.
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We expressly reserve the right, so long as applicable law allows:
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to delay our acceptance of old notes for exchange; |
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to terminate the exchange offer if any of the conditions set
forth under Conditions of the Exchange
Offer exist; |
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to waive any condition to the exchange offer; |
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to amend any of the terms of the exchange offer; and |
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to extend the expiration date and retain all old notes tendered
in the exchange offer, subject to your right to withdraw your
tendered old notes as described under
Withdrawal of Tenders. |
Any waiver or amendment to the exchange offer will apply to all
old notes tendered, regardless of when or in what order the old
notes were tendered. If the exchange offer is amended in a
manner that we think constitutes a material change, or if we
waive a material condition of the exchange offer, we will
promptly disclose the amendment or waiver by means of a
prospectus supplement that will be distributed to the registered
holders of the old notes, and we will extend the exchange offer
to the extent required by
Rule 14e-1 under
the Exchange Act.
We will promptly follow any delay in acceptance, termination,
extension or amendment by oral or written notice of the event to
the exchange agent, followed promptly by oral or written notice
to the registered holders. Should we choose to delay, extend,
amend or terminate the exchange offer, we will have no
obligation to publish, advertise or otherwise communicate this
announcement, other than by making a timely release to an
appropriate news agency.
In the event we terminate the exchange offer, all old notes
previously tendered and not accepted for payment will be
returned promptly to the tendering holders.
In the event that the exchange offer is withdrawn or otherwise
not completed, new notes will not be given to holders of old
notes who have validly tendered their old notes.
Resale of New Notes
Based on interpretations of the SEC staff set forth in no action
letters issued to third parties, we believe that new notes
issued under the exchange offer in exchange for old notes may be
offered for resale, resold and otherwise transferred by you
without compliance with the registration and prospectus delivery
requirements of the Securities Act, if:
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you are acquiring new notes in the ordinary course of your
business; |
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you are not participating, and have no arrangement or
understanding with any person to participate, in the
distribution of the new notes; |
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you are not our affiliate within the meaning of
Rule 405 under the Securities Act; and |
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you are not a broker-dealer who purchased old notes directly
from us for resale pursuant to Rule 144A or any other
available exemption under the Securities Act. |
If you tender old notes in the exchange offer with the intention
of participating in any manner in a distribution of the new
notes:
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you cannot rely on those interpretations by the SEC
staff, and |
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you must comply with the registration and prospectus delivery
requirements of the Securities Act in connection with a
secondary resale transaction and that such a secondary resale
transaction |
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must be covered by an effective
registration statement containing the selling security holder
information required by Item 507 or 508, as applicable, of
Regulation S-K. |
Only broker-dealers that acquired the old notes as a result of
market-making activities or other trading activities may
participate in the exchange offer. Each broker-dealer that
receives new notes for its own account in exchange for old
notes, where such old notes were acquired by such broker-dealer
as a result of market-making activities or other trading
activities, must acknowledge that it will deliver a prospectus
in connection with any resale of the new notes. Please read the
section captioned Plan of Distribution for more
details regarding the transfer of new notes.
Acceptance of Old Notes for Exchange
We will accept for exchange old notes validly tendered pursuant
to the exchange offer, or defectively tendered, if such defect
has been waived by us. We will not accept old notes for exchange
subsequent to the expiration date of the exchange offer. Tenders
of old notes will be accepted only in minimum denominations of
$2,000 and integral multiples of $1,000 in excess thereof.
We expressly reserve the right, in our sole discretion, to:
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delay acceptance for exchange of old notes tendered under the
exchange offer, subject to
Rule 14e-1 under
the Exchange Act, which requires that an offeror pay the
consideration offered or return the securities deposited by or
on behalf of the holders promptly after the termination or
withdrawal of a tender offer, or |
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terminate the exchange offer and not accept for exchange any old
notes not theretofore accepted for exchange, if any of the
conditions set forth below under Conditions of
the Exchange Offer have not been satisfied or waived by us
or in order to comply in whole or in part with any applicable
law. |
In all cases, new notes will be issued only after timely receipt
by the exchange agent of certificates representing old notes, or
confirmation of book-entry transfer, a properly completed and
duly executed letter of transmittal, or a manually signed
facsimile thereof, and any other required documents. For
purposes of the exchange offer, we will be deemed to have
accepted for exchange validly tendered old notes, or defectively
tendered old notes with respect to which we have waived such
defect, if, as and when we give oral, confirmed in writing, or
written notice to the exchange agent. Promptly after the
expiration date, we will deposit the new notes with the exchange
agent, who will act as agent for the tendering holders for the
purpose of receiving the new notes and transmitting them to the
holders. The exchange agent will deliver the new notes to
holders of old notes accepted for exchange after the exchange
agent receives the new notes.
If, for any reason, we delay acceptance for exchange of validly
tendered old notes or we are unable to accept for exchange
validly tendered old notes, then the exchange agent may,
nevertheless, on our behalf, retain tendered old notes, without
prejudice to our rights described under
Expiration Date; Extensions; Termination;
Amendments, Withdrawal of Tenders
and Conditions of the Exchange Offer,
subject to
Rule 14e-1 under
the Exchange Act, which requires that an offeror pay the
consideration offered or return the securities deposited by or
on behalf of the holders thereof promptly after the termination
or withdrawal of a tender offer.
If any tendered old notes are not accepted for exchange for any
reason, or if certificates are submitted evidencing more old
notes than those that are tendered, certificates evidencing old
notes that are not exchanged will be returned, without expense,
to the tendering holder, or, in the case of old notes tendered
by book-entry transfer into the exchange agents account at
a book-entry transfer facility under the procedure set forth
under Procedures for Tendering Old
Notes Book-Entry Transfer, such
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old notes will be credited to the account maintained at such
book-entry transfer facility from which such old notes were
delivered, unless otherwise requested by such holder under
Special Delivery Instructions in the letter of
transmittal, promptly following the expiration date or the
termination of the exchange offer.
Tendering holders of old notes exchanged in the exchange offer
will not be obligated to pay brokerage commissions or transfer
taxes with respect to the exchange of their old notes other than
as described in Transfer Taxes or in
Instruction 7 to the letter of transmittal. We will pay all
other charges and expenses in connection with the exchange offer.
Procedures for Tendering Old Notes
Any beneficial owner whose old notes are registered in the name
of a broker, dealer, commercial bank, trust company or other
nominee or held through a book-entry transfer facility and who
wishes to tender old notes should contact such registered holder
promptly and instruct such registered holder to tender old notes
on such beneficial owners behalf.
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Tender of Old
Notes Held Through Depository Trust Company |
The exchange agent and Depository Trust Company, or DTC, have
confirmed that the exchange offer is eligible for the DTCs
automated tender offer program. Accordingly, DTC participants
may electronically transmit their acceptance of the exchange
offer by causing DTC to transfer old notes to the exchange agent
in accordance with DTCs automated tender offer program
procedures for transfer. DTC will then send an agents
message to the exchange agent.
The term agents message means a message
transmitted by DTC, received by the exchange agent and forming
part of the book-entry confirmation, which states that DTC has
received an express acknowledgment from the participant in DTC
tendering old notes that are the subject of that book-entry
confirmation that the participant has received and agrees to be
bound by the terms of the letter of transmittal, and that we may
enforce such agreement against such participant. In the case of
an agents message relating to guaranteed delivery, the
term means a message transmitted by DTC and received by the
exchange agent which states that DTC has received an express
acknowledgment from the participant in DTC tendering old notes
that they have received and agree to be bound by the notice of
guaranteed delivery.
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Tender of Old
Notes Held in Certificated Form |
For a holder to validly tender old notes held in certificated
form:
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the exchange agent must receive at its address set forth in this
prospectus a properly completed and validly executed letter of
transmittal, or a manually signed facsimile thereof, together
with any signature guarantees and any other documents required
by the instructions to the letter of transmittal, and |
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the exchange agent must receive certificates for tendered old
notes at such address, or such old notes must be transferred
pursuant to the procedures for book-entry transfer described
below. |
A confirmation of such book-entry transfer must be received by
the exchange agent prior to the expiration date of the exchange
offer. A holder who desires to tender old notes and who cannot
comply with the procedures set forth herein for tender on a
timely basis or whose old notes are not immediately available
must comply with the procedures for guaranteed delivery set
forth below.
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Letters of transmittal and old notes should be sent only to
the exchange agent, and not to us or to DTC.
The method of delivery of old notes, letters of transmittal
and all other required documents to the exchange agent is at the
election and risk of the holder tendering old notes. Delivery of
such documents will be deemed made only when actually received
by the exchange agent. If such delivery is by mail, we suggest
that the holder use properly insured, registered mail with
return receipt requested, and that the mailing be made
sufficiently in advance of the expiration date of the exchange
offer to permit delivery to the exchange agent prior to such
date. No alternative, conditional or contingent tenders of old
notes will be accepted.
Signatures on the letter of transmittal must be guaranteed by an
eligible institution unless:
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the letter of transmittal is signed by the registered holder of
the old notes tendered therewith, or by a participant in one of
the book-entry transfer facilities whose name appears on a
security position listing it as the owner of those old notes and
the new notes are to be issued directly to such registered
holder(s), or, if tendered by a participant in one of the
book-entry transfer facilities, any old notes for principal
amounts not tendered or not accepted for exchange are to be
credited to the participants account at the book-entry
transfer facility, and neither the Special Issuance
Instructions nor the Special Delivery
Instructions box on the letter of transmittal has been
completed, or |
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the old notes are tendered for the account of an eligible
institution. |
An eligible institution is a firm that is a member of a
registered national securities exchange or of the National
Association of Securities Dealers, Inc., a commercial bank or a
trust company having an office or correspondent in the United
States or an eligible guarantor institution within
the meaning of Rule 17Ad-15 under the Exchange Act.
The exchange agent will seek to establish a new account or
utilize an existing account with respect to the old notes at DTC
promptly after the date of this prospectus. Any financial
institution that is a participant in the DTC system and whose
name appears on a security position listing as the owner of the
old notes may make book-entry delivery of old notes by causing
DTC to transfer such old notes into the exchange agents
account. However, although delivery of old notes may be
effected through book-entry transfer into the exchange
agents account at DTC, a properly completed and validly
executed letter of transmittal, or a manually signed facsimile
thereof, must be received by the exchange agent at one of its
addresses set forth in this prospectus on or prior to the
expiration date of the exchange offer, or else the guaranteed
delivery procedures described below must be complied with.
The confirmation of a book-entry transfer of old notes into the
exchange agents account at DTC is referred to in this
prospectus as a book-entry confirmation. Delivery of
documents to DTC in accordance with DTCs procedures does
not constitute delivery to the exchange agent.
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If you wish to tender your old notes and:
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(1) certificates representing your old notes are not lost
but are not immediately available, |
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(2) time will not permit your letter of transmittal,
certificates representing your old notes and all other required
documents to reach the exchange agent on or prior to the
expiration date of the exchange offer, or |
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(3) the procedures for book-entry transfer cannot be
completed on or prior to the expiration date of the exchange
offer, |
you may nevertheless tender if all of the following conditions
are complied with:
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your tender is made by or through an eligible
institution; and |
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on or prior to the expiration date of the exchange offer, the
exchange agent has received from the eligible institution a
properly completed and validly executed notice of guaranteed
delivery, by manually signed facsimile transmission, overnight
courier, registered or certified mail or hand delivery, in
substantially the form provided with this prospectus. The notice
of guaranteed delivery must: |
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(a) set forth your name and address, the registered
number(s) of your old notes and the principal amount of old
notes tendered; |
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(b) state that the tender is being made thereby; |
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(c) guarantee that, within three New York Stock Exchange
trading days after the expiration date, the letter of
transmittal or facsimile thereof properly completed and validly
executed, together with certificates representing the old notes,
or a book-entry confirmation, and any other documents required
by the letter of transmittal and the instructions thereto, will
be deposited by the eligible institution with the exchange
agent; and |
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(d) the exchange agent receives the properly completed and
validly executed letter of transmittal or facsimile thereof with
any required signature guarantees, together with certificates
for all old notes in proper form for transfer, or a book-entry
confirmation, and any other required documents, within three New
York Stock Exchange trading days after the expiration date. |
New notes will be issued in exchange for old notes accepted for
exchange only after timely receipt by the exchange agent of:
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certificates for (or a timely book-entry confirmation with
respect to) your old notes, |
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a properly completed and duly executed letter of transmittal or
facsimile thereof with any required signature guarantees, or, in
the case of a book-entry transfer, an agents
message, and |
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any other documents required by the letter of transmittal. |
We will determine, in our sole discretion, all questions as to
the form of all documents and the validity, eligibility,
including time of receipt, acceptance and withdrawal of all
tenders of old notes. Our determination will be final and
binding on all parties. Alternative, conditional or
contingent tenders of old notes will not be considered valid. We
reserve the absolute right to reject any or all tenders of old
notes not properly tendered or the acceptance of which, in our
opinion, would be unlawful. We
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also reserve the right to waive any defects, irregularities
or conditions of tender as to particular old notes.
Our interpretation of the terms and conditions of the exchange
offer, including the instructions in the letter of transmittal,
will be final and binding.
Any defect or irregularity in connection with tenders of old
notes must be cured within the time we determine, unless waived
by us. We will not consider the tender of old notes to have been
validly made until all defects and irregularities have been
waived by us or cured. Neither we, the exchange agent, or any
other person will be under any duty to give notice of any
defects or irregularities in tenders of old notes, or will incur
any liability to holders for failure to give any such notice.
Withdrawal of Tenders
Except as otherwise provided in this prospectus, you may
withdraw your tender of old notes at any time prior to the
expiration date.
For a withdrawal to be effective:
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the exchange agent must receive a written notice of withdrawal
at one of the addresses set forth below under
Exchange Agent, or |
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you must comply with the appropriate procedures of DTCs
automated tender offer program system. |
Any notice of withdrawal must:
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specify the name of the person who tendered the old notes to be
withdrawn, and |
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identify the old notes to be withdrawn, including the principal
amount of the old notes. |
If old notes have been tendered pursuant to the procedure for
book-entry transfer described above, any notice of withdrawal
must specify the name and number of the account at DTC to be
credited with the withdrawn old notes and otherwise comply with
the procedures of DTC.
We will determine all questions as to validity, form,
eligibility and time of receipt of any withdrawal notices. Our
determination will be final and binding on all parties. We will
deem any old notes so withdrawn not to have been validly
tendered for exchange for purposes of the exchange offer.
Any old notes that have been tendered for exchange but that are
not exchanged for any reason will be returned to their holder
without cost to the holder or, in the case of old notes tendered
by book-entry transfer into the exchange agents account at
DTC according to the procedures described above, such old notes
will be credited to an account maintained with DTC for the old
notes. This return or crediting will take place as soon as
practicable after withdrawal, rejection of tender or termination
of the exchange offer. You may retender properly withdrawn old
notes by following one of the procedures described under
Procedures for Tendering Old Notes at
any time on or prior to the expiration date.
Conditions of the Exchange Offer
Notwithstanding any other provisions of the exchange offer, if,
on or prior to the expiration date, we determine, in our
reasonable judgment, that the exchange offer, or the making of
an exchange by a holder of old notes, would violate applicable
law or any applicable interpretation of the staff of the SEC, we
will not be required to accept for exchange, or to exchange, any
tendered old notes. We may also terminate, waive any conditions
to or amend the exchange offer. In addition, we may postpone the
acceptance for exchange of tendered old notes, subject to
Rule 14e-1 under
the Exchange Act, which
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requires that an offeror pay the consideration offered or return
the securities deposited by or on behalf of the holders thereof
promptly after the termination or withdrawal of the exchange
offer.
Transfer Taxes
We will pay all transfer taxes applicable to the transfer and
exchange of old notes pursuant to the exchange offer. If,
however:
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new notes or old notes for principal amounts not exchanged, are
to be delivered to or registered or issued in the name of, any
person other than the registered holder of the old notes
tendered; |
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tendered certificates for old notes are registered in the name
of any person other than the person signing any letter of
transmittal; or |
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a transfer tax is imposed for any reason other than the transfer
and exchange of old notes to us or our order pursuant to the
exchange offer, |
the amount of any such transfer taxes, whether imposed on the
registered holder or any other person, will be payable by the
tendering holder prior to the issuance of the new notes or
delivery or registering of the old notes.
Consequences of Failing to Exchange
If you do not exchange your old notes for new notes in the
exchange offer, you will remain subject to the restrictions on
transfer of the old notes:
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as set forth in the legend printed on the old notes as a
consequence of the issuance of the old notes pursuant to the
exemptions from, or in transactions not subject to, the
registration requirements of the Securities Act and applicable
state securities laws; and |
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otherwise set forth in the offering memoranda distributed in
connection with the private offerings of the old notes. |
In general, you may not offer or sell the old notes unless they
are registered under the Securities Act, or if the offer or sale
is exempt from registration under the Securities Act and
applicable state securities laws. Except as required by the
registration rights agreements, we do not intend to register
resales of the old notes under the Securities Act.
Accounting Treatment
The new notes will be recorded at the same carrying value as the
old notes, as reflected in our accounting records on the date of
the exchange. Accordingly, we will not recognize any gain or
loss for accounting purposes upon the consummation of the
exchange offer. We will amortize the expenses of the exchange
offer over the term of the new notes.
Exchange Agent
Wells Fargo Bank, N.A. has been appointed as exchange agent for
the exchange offer. You should direct questions and requests for
assistance, requests for additional copies of this prospectus,
the letter of transmittal or any other documents to the exchange
agent. You should send certificates for old notes, letters of
transmittal and any other required documents to the exchange
agent addressed as follows:
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The exchange agent for the exchange offer is:
Wells Fargo Bank, N.A.
By Registered or Certified Mail:
Wells Fargo Bank, N.A.
MAC N9303-121
P.O. Box 1517
Minneapolis, MN 55480-1517
Attn: Corporate Trust Operations
By Regular Mail/ Hand/ Overnight Delivery:
Wells Fargo Bank, N.A.
Sixth and Marquette
MAC N9303-121
Minneapolis, MN 55479
Attn: Corporate Trust Operations
For Assistance Call:
800-344-5128
Fax Number (for eligible institutions only):
612-667-4927
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DESCRIPTION OF NOTES
Allis-Chalmers will issue the new notes under an indenture among
itself, the Guarantors and Wells Fargo Bank, N.A., as trustee.
The terms of the notes include those stated in the indenture and
those made part of the indenture by reference to the Trust
Indenture Act of 1939, as amended (the Trust Indenture
Act).
On January 18, 2006, we issued $160.0 million in
aggregate principal amount of old notes under the indenture. On
August 14, 2006, we issued an additional $95.0 million
principal amount of old notes under the indenture, which are
treated together with the old notes issued in January 2006 as a
single class of debt securities under the indenture.
The following description is a summary of select provisions of
the indenture. It does not restate such agreement in its
entirety. We urge you to read the indenture because it, and not
this description, defines your rights as Holders of the notes.
Anyone who receives this prospectus may obtain a copy of the
indenture without charge by writing to Allis-Chalmers
Energy Inc., 5075 Westheimer, Suite 890, Houston,
TX 77056, Attention: General Counsel.
You can find the definitions of certain terms used in this
description below under the caption
Definitions. Some defined terms used in
this description but not defined below under the caption
Definitions have the meanings assigned
to them in the indenture. In this description, the words
we, us and our and the term
Allis-Chalmers refer only to Allis-Chalmers Energy
Inc. and not to any of its subsidiaries. This description
assumes that all outstanding old notes will be exchanged for new
notes in the exchange offer. Therefore, except where the context
requires otherwise, all references to the notes in this
description are to the new notes.
The registered Holder of a note will be treated as the owner of
it for all purposes. Only registered Holders will have rights
under the indenture.
Brief Description of the Notes
The notes:
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are our general unsecured obligations; |
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are effectively subordinated to all our existing and any future
secured Indebtedness, including our Indebtedness under the
Credit Agreement, to the extent of the assets securing such
Indebtedness, and to all existing and any future liabilities of
our subsidiaries that are not Guarantors, to the extent of the
assets of such subsidiaries; |
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are pari passu in right of payment with all our existing
and any future unsecured, unsubordinated Indebtedness; |
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are senior in right of payment to all our existing and any
future subordinated Indebtedness; and |
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are guaranteed by the Guarantors on a senior unsecured basis. |
Assuming the August 2006 offering of the old notes had been
completed as of June 30, 2006 and that the net proceeds had
been applied as intended, we would have had $257.6 million
of indebtedness outstanding, $130,000 of which would have been
secured indebtedness.
As of the date of the indenture, all of our subsidiaries were
Restricted Subsidiaries, and all of them had
guaranteed the notes. However, under the circumstances described
below under the caption Covenants
Designation of Restricted and Unrestricted Subsidiaries,
we will be permitted to
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designate certain of our subsidiaries as Unrestricted
Subsidiaries. Any Unrestricted Subsidiaries will not be
subject to any of the restrictive covenants in the indenture and
will not guarantee the notes. Furthermore, our current and
future Foreign Subsidiaries (such as DLS and its subsidiaries)
will not guarantee the notes.
Principal, Maturity and Interest
We will issue $255.0 million in aggregate principal amount
of notes in the exchange offer. The indenture provides for our
issuance of notes with an unlimited principal amount, and we may
issue additional notes from time to time after this offering.
Any offering of additional notes is subject to the covenant
described below under the caption
Covenants Incurrence of
Indebtedness. The notes and any additional notes
subsequently issued under the indenture would be treated as a
single class for all purposes under the indenture, including,
without limitation, waivers, amendments, redemptions and offers
to purchase. Unless otherwise provided or the context otherwise
requires, for all purposes of the indenture and this
Description of Notes, references to the notes
include the notes and any further additional notes actually
issued.
We will issue notes in minimum denominations of $2,000 and
integral multiples of $1,000 in excess thereof. The notes will
mature on January 15, 2014.
Interest on the notes will accrue at the rate of 9.0% per
annum and will be payable semi-annually in arrears on
January 15 and July 15, commencing on January 15,
2007. Interest on overdue principal and interest and Liquidated
Damages, if any, will accrue at the applicable interest rate on
the notes. We will make each interest payment to the Holders of
record on the immediately preceding January 1 and
July 1. Any Liquidated Damages due will be paid on the same
dates as interest on the notes.
Interest on the notes will accrue from July 15, 2006.
Interest will be computed on the basis of a
360-day year comprised
of twelve 30-day
months. If an interest payment date falls on a day that is not a
business day, the interest payment to be made on such interest
payment date will be made on the next succeeding business day
with the same force and effect as if made on such interest
payment date, and no additional interest will accrue as a result
of such delayed payment.
Methods of Receiving Payments on the Notes
If a Holder has given wire transfer instructions to us, we will
pay all principal, interest and premium and Liquidated Damages,
if any, on that Holders notes in accordance with those
instructions. All other payments on notes will be made at the
office or agency of the paying agent and registrar within the
City and State of New York unless we elect to make interest
payments by check mailed to the Holders at their addresses set
forth in the register of Holders.
Paying Agent and Registrar for the Notes
The trustee will initially act as paying agent and registrar. We
may change the paying agent or registrar without prior notice to
the Holders, and we or any of our Subsidiaries may act as paying
agent or registrar.
Transfer and Exchange
A Holder may transfer or exchange notes in accordance with the
indenture. The registrar and the trustee may require a Holder,
among other things, to furnish appropriate endorsements and
transfer documents and we may require a Holder to pay any taxes
and fees required by law or permitted by the indenture. We are
not required to transfer or exchange any note selected for
redemption. Also, we are
107
not required to transfer or exchange any note for a period of
15 days before a selection of notes to be redeemed.
The registered Holder of a note will be treated as the owner of
it for all purposes.
Subsidiary Guarantees
The notes will be guaranteed, jointly and severally, by all of
our current Domestic Subsidiaries and, except under certain
circumstances described under the caption
Covenants Subsidiary
Guarantees, by all of our Domestic Subsidiaries that we
create or acquire in the future. Our current and future Foreign
Subsidiaries (such as DLS and its subsidiaries) will not
guarantee the notes.
Each Subsidiary Guarantee:
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is a general unsecured obligation of the Guarantor; |
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is effectively subordinated to all existing and any future
secured Indebtedness of the Guarantor, including the guarantee
of the Guarantor under the Credit Agreement; |
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is pari passu in right of payment with all existing and
any future unsecured, unsubordinated Indebtedness of the
Guarantor; and |
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is senior in right of payment to all existing and any future
subordinated Indebtedness of the Guarantor. |
The obligations of each Guarantor under its Subsidiary Guarantee
will be limited as necessary to prevent that Subsidiary
Guarantee from constituting a fraudulent conveyance under
applicable law. See Risk Factors Federal and
state statutes allow courts, under specific circumstances, to
void guarantees and require note holders to return payments
received from guarantors. Assuming the August 2006
offering of the old notes had been completed as of June 30,
2006 and that the net proceeds had been applied as intended, the
Guarantors would have had $267.3 million of indebtedness
outstanding, $3.1 million of which would have been secured
indebtedness.
Subsidiary Guarantees may be released in certain circumstances.
See Covenants Subsidiary
Guarantees.
Optional Redemption
At any time prior to January 15, 2010, we may redeem the
notes, in whole or in part, at the
Make-Whole Price, plus
accrued and unpaid interest and Liquidated Damages, if any, to
the redemption date. Make-Whole Price with
respect to a note means the greater of:
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(1) the sum of the outstanding principal amount and
Make-Whole Amount of such note; and |
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(2) the redemption price of such note on January 15,
2010, determined pursuant to the indenture (104.500% of the
principal amount). |
Make-Whole Amount with respect to a note
means an amount equal to the excess, if any, of:
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(1) the present value of the remaining interest, premium,
if any, and principal payments due on such note as if such note
were redeemed on January 15, 2010 computed using a discount
rate equal to the Treasury Rate plus 50 basis points, over |
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(2) the outstanding principal amount of such note. |
Treasury Rate is defined as the yield to
maturity at the time of the computation of United States
Treasury securities with a constant maturity (as compiled by and
published in the most recent Federal
108
Reserve Statistical Release H.15(519), which has become publicly
available at least two business days prior to the date of the
redemption notice or, if such Statistical Release is no longer
published, any publicly available source of similar market date)
most nearly equal to the then remaining maturity of the notes
assuming redemption of the notes on January 15, 2010;
provided, however, that if the Make-Whole Average Life of
such note is not equal to the constant maturity of the United
States Treasury security for which a weekly average yield is
given, the Treasury Rate shall be obtained by linear
interpolation (calculated to the nearest one-twelfth of a year)
from the weekly average yields of United States Treasury
securities for which such yields are given, except that if the
Make-Whole Average Life of such notes is less than one year, the
weekly average yield on actually traded United States Treasury
securities adjusted to a constant maturity of one year shall be
used. Make-Whole Average Life means the
number of years (calculated to the nearest one-twelfth) between
the date of redemption and January 15, 2010.
On or after January 15, 2010, we may redeem all or a part
of the notes upon not less than 30 nor more than
60 days notice, at the redemption prices (expressed
as percentages of principal amount) set forth below plus accrued
and unpaid interest and Liquidated Damages, if any, to the
applicable redemption date, if redeemed during the twelve-month
period beginning on January 15, of the years indicated
below, subject to the rights of Holders on the relevant record
date to receive interest on the relevant interest payment date:
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Percentage | |
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2010
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104.500 |
% |
2011
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102.250 |
% |
2012 and thereafter
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100.000 |
% |
At any time prior to January 15, 2009, we may, on one or
more occasions, redeem up to 35% of the aggregate principal
amount of notes issued under the indenture (including any
additional notes) at a redemption price of 109.000% of the
principal amount thereof, plus accrued and unpaid interest and
Liquidated Damages, if any, to the redemption date, with the net
cash proceeds of one or more Equity Offerings; provided
that:
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(1) |
notes in an aggregate principal amount equal to at least 65% of
the aggregate principal amount of notes issued under the
indenture on the Issue Date remain outstanding immediately after
the occurrence of such redemption (excluding notes held by us or
our Affiliates); and |
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(2) |
the redemption must occur within 180 days of the date of
the closing of such Equity Offering. |
Unless we default in the payment of the redemption price,
interest will cease to accrue on the notes or portions thereof
called for redemption on the applicable redemption date.
Selection and Notice
If less than all of the notes are to be redeemed at any time,
the trustee will select notes for redemption as follows:
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(1) |
if the notes are listed on any national securities exchange, in
compliance with the requirements of such principal national
securities exchange; or |
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(2) |
if the notes are not so listed, on a pro rata basis, by lot or
by such method as the trustee will deem fair and appropriate. |
109
No notes of $2,000 or less will be redeemed in part. Notices of
redemption will be mailed by first class mail at least 30 but
not more than 60 days before the redemption date to each
Holder of notes to be redeemed at its registered address, except
that redemption notices may be mailed more than 60 days
prior to a redemption date if the notice is issued in connection
with a defeasance of the notes or a satisfaction and discharge
of the indenture. Notices of redemption may be conditional and
our obligation to redeem notes may be subject to any one or more
conditions that we, in our sole discretion, include in such a
notice.
If any note is to be redeemed in part only, the notice of
redemption that relates to that note will state the portion of
the principal amount thereof to be redeemed. A new note in
principal amount equal to the unredeemed portion of the original
note will be issued in the name of the Holder thereof upon
cancellation of the original note. Notes called for redemption
become due on the date fixed for redemption. On and after the
redemption date, interest ceases to accrue on notes or portions
of them called for redemption.
Open Market Purchases; No Mandatory Redemption or Sinking
Fund
We may at any time and from time to time purchase notes in the
open market or otherwise, in each case without any restriction
under the indenture. We are not required to make mandatory
redemption or sinking fund payments with respect to the notes.
Repurchase at the Option of Holders
If a Change of Control occurs, each Holder of notes will have
the right to require Allis-Chalmers to repurchase all or any
part (equal to $2,000 and integral multiples of $1,000 in excess
thereof) of that Holders notes pursuant to an offer (a
Change of Control Offer) on the terms set
forth in the indenture. In the Change of Control Offer,
Allis-Chalmers will offer payment (a Change of Control
Payment) in cash equal to not less than 101% of the
aggregate principal amount of notes repurchased plus accrued and
unpaid interest and Liquidated Damages, if any, to the date of
repurchase (the Change of Control Payment
Date, which date will be no earlier than the date of
such Change of Control). No later than 30 days following
any Change of Control, Allis-Chalmers will mail a notice to each
Holder describing the transaction or transactions that
constitute the Change of Control and offering to repurchase
notes on the Change of Control Payment Date specified in such
notice, which date will be no earlier than 30 days and no
later than 60 days from the date such notice is mailed,
pursuant to the procedures required by the indenture and
described in such notice. Allis-Chalmers will comply with the
requirements of
Rule 14e-1 under
the Exchange Act and any other securities laws and regulations
thereunder to the extent such laws and regulations are
applicable in connection with the repurchase of the notes as a
result of a Change of Control. To the extent that the provisions
of any securities laws or regulations conflict with the Change
of Control provisions of the indenture, or compliance with the
Change of Control provisions of the indenture would constitute a
violation of any such laws or regulations, Allis-Chalmers will
comply with the applicable securities laws and regulations and
will not be deemed to have breached its obligations under the
Change of Control provisions of the indenture by virtue of such
compliance.
On or before the Change of Control Payment Date, Allis-Chalmers
will, to the extent lawful:
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(1) |
accept for payment all notes or portions thereof properly
tendered pursuant to the Change of Control Offer; |
110
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(2) |
deposit with the paying agent an amount equal to the Change of
Control Payment in respect of all notes or portions thereof
properly tendered; and |
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(3) |
deliver or cause to be delivered to the trustee, the notes so
accepted together with an Officers Certificate stating the
aggregate principal amount of notes or portions thereof being
purchased by Allis-Chalmers. |
The paying agent will promptly mail or wire transfer to each
Holder of notes properly tendered the Change of Control Payment
for such notes, and the trustee will promptly authenticate and
mail (or cause to be transferred by book entry) to each Holder a
new note equal in principal amount to any unpurchased portion of
the notes surrendered, if any; provided that each such
new note will be in a principal amount of $2,000 or an integral
multiple of $1,000 in excess thereof.
Allis-Chalmers will publicly announce the results of the Change
of Control Offer on or as soon as practicable after the Change
of Control Payment Date.
If Holders of not less than 95% in aggregate principal amount of
the outstanding notes validly tender and do not withdraw such
notes in a Change of Control Offer and Allis-Chalmers, or any
third party making a Change of Control Offer in lieu of
Allis-Chalmers as described above, purchases all of the notes
validly tendered and not withdrawn by such Holders,
Allis-Chalmers will have the right, upon not less than 30 nor
more than 60 days prior notice, given not more than
30 days following such purchase pursuant to the Change of
Control Offer described above, to redeem all notes that remain
outstanding following such purchase at a redemption price in
cash equal to the applicable Change of Control Payment plus, to
the extent not included in the Change of Control Payment,
accrued and unpaid interest, if any, and Liquidated Damages, if
any thereon, to the date of redemption.
The Credit Agreement prohibits us from purchasing any notes and
provides that certain change of control events with respect to
us constitute a default under the Credit Agreement. Any future
credit agreements or other similar agreements to which we become
a party may contain similar restrictions and provisions. In the
event a Change of Control occurs at a time when we are
prohibited from purchasing notes, we could seek the consent of
its lenders to the purchase of notes or could attempt to
refinance the borrowings that contain such prohibition. If we do
not obtain such a consent or repay such borrowings, we will
remain prohibited from purchasing notes. In such case, our
failure to purchase tendered notes would constitute an Event of
Default under the indenture which would, in turn, constitute a
default under such other agreements.
The provisions described above that require us to make a Change
of Control Offer following a Change of Control will be
applicable regardless of whether any other provisions of the
indenture are applicable. Except as described above with respect
to a Change of Control, the indenture does not contain
provisions that permit the Holders of the notes to require that
we repurchase or redeem the notes in the event of a takeover,
recapitalization or similar transaction.
We will not be required to make a Change of Control Offer upon a
Change of Control if (1) a third party makes the Change of
Control Offer in the manner, at the times and otherwise in
compliance with the requirements set forth in the indenture
applicable to a Change of Control Offer made by us and purchases
all notes properly tendered and not withdrawn under the Change
of Control Offer or (2) notice of redemption has been given
pursuant to the indenture as described above under the caption
Optional Redemption, unless and until
there is a default in payment of the applicable redemption price.
The definition of Change of Control includes a phrase relating
to the direct or indirect sale, transfer, conveyance or other
disposition of all or substantially all of our
properties or assets and its Restricted Subsidiaries taken as a
whole. Although there is a limited body of case law interpreting
the
111
phrase substantially all, there is no precise
established definition of the phrase under applicable law.
Accordingly, the ability of a Holder of notes to require us to
repurchase such notes as a result of a sale, transfer,
conveyance or other disposition of less than all of our assets
and our Restricted Subsidiaries taken as a whole to another
Person or group may be uncertain.
Allis-Chalmers will not, and will not permit any of its
Restricted Subsidiaries to, consummate an Asset Sale unless:
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(1) |
Allis-Chalmers (or the Restricted Subsidiary, as the case may
be) receives consideration in respect of such Asset Sale at
least equal to the Fair Market Value of the assets or Equity
Interests issued or sold or otherwise disposed of; and |
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(2) |
either (x) at least 75% of the consideration therefor
received by Allis-Chalmers or such Restricted Subsidiary is in
the form of cash, Cash Equivalents or Replacement Assets or a
combination thereof or (y) the Fair Market Value of the
aggregate of all consideration other than cash, Cash Equivalents
or Replacement Assets for all Asset Sales since the Issue Date
would not exceed 10% of Consolidated Tangible Assets of
Allis-Chalmers after giving effect to such Asset Sales. For
purposes of this provision, each of the following will be deemed
to be cash: |
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(a) |
any liabilities, as shown on Allis-Chalmers or such
Restricted Subsidiarys most recent consolidated balance
sheet (or as would be shown on Allis-Chalmers consolidated
balance sheet as of the date of such Asset Sale) of
Allis-Chalmers or any Restricted Subsidiary (other than
contingent liabilities, Indebtedness that is by its terms
subordinated to the notes or any Subsidiary Guarantee) that are
assumed by the transferee of any such assets or Equity Interests
pursuant to (1) a written novation agreement that releases
Allis-Chalmers or such Restricted Subsidiary from further
liability therefor or (2) an assignment agreement that
includes, in lieu of such a release, the agreement of the
transferee or its parent company to indemnify and hold harmless
Allis-Chalmers or such Restricted Subsidiary from and against
any loss, liability or cost in respect of such assumed liability; |
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(b) |
any securities, notes or other obligations received by
Allis-Chalmers or any such Restricted Subsidiary from such
transferee that are converted by Allis-Chalmers or such
Restricted Subsidiary into cash within 270 days after such
Asset Sale, to the extent of the cash received in that
conversion; and |
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(c) |
accounts receivables of a business retained by Allis-Chalmers or
any of its Restricted Subsidiaries following the sale of such
business; provided that (i) such accounts
receivables are not more than 60 days past due and
(ii) do not have a payment date greater than 90 days
from the date of the invoice creating such accounts receivable. |
Any Asset Sale pursuant to a condemnation, appropriation or
other similar taking, including by deed in lieu of condemnation,
or pursuant to the foreclosure or other enforcement of a
Permitted Lien or exercise by the related lienholder of rights
with respect thereto, including by deed or assignment in lieu of
foreclosure shall not be required to satisfy the conditions set
forth in clauses (1) and (2) of the first paragraph of
this covenant.
Notwithstanding the foregoing, the 75% limitation referred to
above shall be deemed satisfied with respect to any Asset Sale
in which the cash or Cash Equivalents portion of the
consideration received therefrom, determined in accordance with
the foregoing provision on an after-tax basis, is equal to or
112
greater than what the after-tax proceeds would have been had
such Asset Sale complied with the aforementioned 75% limitation.
Within 360 days after the receipt of any Net Proceeds from
an Asset Sale, Allis-Chalmers or its Restricted Subsidiaries may
apply an amount equal to such Net Proceeds at its option:
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(1) |
to repay Indebtedness for borrowed money (other than
Subordinated Indebtedness); or |
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(2) |
to make any capital expenditure or to purchase Replacement
Assets (or enter into a binding agreement to make such capital
expenditure or to purchase such Replacement Assets; provided
that (a) such capital expenditure or purchase is
consummated within the later of (x) 360 days after the
receipt of the Net Proceeds from the related Asset Sale and
(y) 180 days after the date of such binding agreement
and (b) if such capital expenditure or purchase is not
consummated within the period set forth in subclause (a),
the amount not so applied will be deemed to be Excess Proceeds
(as defined below)). |
Pending the final application of any such Net Proceeds,
Allis-Chalmers may temporarily reduce revolving credit
borrowings or otherwise invest such Net Proceeds in any manner
that is not prohibited by the indenture.
An amount equal to any Net Proceeds from Asset Sales that are
not applied or invested as provided in the preceding paragraphs
will constitute Excess Proceeds. If on any
date, the aggregate amount of Excess Proceeds exceeds
$10.0 million, then within ten business days after such
date, Allis-Chalmers will make an offer (an Asset Sale
Offer) to all Holders of notes and all holders of
other Indebtedness that is pari passu with the notes
containing provisions similar to those set forth in the
indenture with respect to offers to purchase or redeem with the
proceeds of sales of assets, to purchase the maximum principal
amount of notes and such other pari passu Indebtedness
that may be purchased out of the Excess Proceeds. The offer
price in any Asset Sale Offer will be equal to 100% of principal
amount plus accrued and unpaid interest and Liquidated Damages,
if any, to the date of purchase, and will be payable in cash. If
any Excess Proceeds remain unapplied after consummation of an
Asset Sale Offer, Allis-Chalmers and its Restricted Subsidiaries
may use those Excess Proceeds for any purpose not otherwise
prohibited by the indenture. If the aggregate principal amount
of notes and other pari passu Indebtedness tendered into
such Asset Sale Offer exceeds the amount of Excess Proceeds, the
trustee will select the notes and such other pari passu
Indebtedness to be purchased on a pro rata basis. Upon
completion of each Asset Sale Offer, the amount of Excess
Proceeds will be reset at zero.
Notwithstanding the foregoing, the sale, conveyance or other
disposition of all or substantially all of the assets of
Allis-Chalmers and its Restricted Subsidiaries, taken as a
whole, will be governed by the provisions of the indenture
described under the caption Repurchase at the
Option of Holders Change of Control and/or the
provisions described under the caption
Covenants Merger, Consolidation or
Sale of Assets and not by the provisions of the Asset Sale
covenant.
Allis-Chalmers will comply with the requirements of
Rule 14e-1 under
the Exchange Act and any other securities laws and regulations
thereunder to the extent such laws and regulations are
applicable in connection with each repurchase of notes pursuant
to an Asset Sale Offer. To the extent that the provisions of any
securities laws or regulations conflict with the Asset Sales
provisions of the indenture, or compliance with the Asset Sale
provisions of the indenture would constitute a violation of any
such laws or regulations, Allis-Chalmers will comply with the
applicable securities laws and regulations and will not be
deemed to have breached its obligations under the Asset Sale
provisions of the indenture by virtue of such compliance.
The Credit Agreement prohibits Allis-Chalmers from purchasing
any notes and also provides that certain asset sale events with
respect to Allis-Chalmers constitute a default under the Credit
Agreement.
113
Any future credit agreements or other similar agreements to
which Allis-Chalmers becomes a party may contain similar
restrictions and provisions. In the event an Asset Sale occurs
at a time when Allis-Chalmers is prohibited from purchasing
notes, Allis-Chalmers could seek the consent of its lenders to
the purchase of notes or could attempt to refinance the
borrowings that contain such prohibition. If Allis-Chalmers does
not obtain such a consent or repay such borrowings,
Allis-Chalmers will remain prohibited from purchasing notes. In
such case, Allis-Chalmers failure to purchase tendered
notes would constitute an Event of Default under the indenture
which would, in turn, constitute a default under such other
agreements. Also, Allis-Chalmers ability to pay cash to
the Holders of notes upon a repurchase may be limited by
Allis-Chalmers then existing financial resources. See
Risk Factors Risks Associated with the Notes
and Our Indebtedness We may not be able to finance a
change of control offer required by the indenture governing the
notes.
Covenants
(A) Allis-Chalmers will not, and will not permit any of its
Restricted Subsidiaries to, directly or indirectly:
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(1) |
declare or pay (without duplication) any dividend or make any
other payment or distribution on account of Allis-Chalmers
or any of its Restricted Subsidiaries Equity Interests or
to the direct or indirect holders of Allis-Chalmers or any
of its Restricted Subsidiaries Equity Interests in their
capacity as such (other than dividends, payments or
distributions (x) payable in Equity Interests (other than
Disqualified Stock) of Allis-Chalmers or (y) to
Allis-Chalmers or a Restricted Subsidiary of Allis-Chalmers); |
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(2) |
purchase, redeem or otherwise acquire or retire for value any
Equity Interests of
Allis-Chalmers or any
Restricted Subsidiary thereof held by Persons other than
Allis-Chalmers or any of its Restricted Subsidiaries; |
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(3) |
make any payment on or with respect to, or purchase, redeem,
defease or otherwise acquire or retire for value any
Subordinated Indebtedness (other than intercompany Indebtedness
between Allis-Chalmers and any of its Restricted Subsidiaries),
except (a) a payment of interest or principal at the Stated
Maturity thereof or (b) the purchase, repurchase or other
acquisition of any such Indebtedness in anticipation of
satisfying a sinking fund obligation, principal installment or
final maturity, in each case due within one year of the date of
such purchase, repurchase or other acquisition; or |
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(4) |
make any Restricted Investment |
(all such payments and other actions set forth in
clauses (1) through (4) above being collectively referred
to as Restricted Payments), unless, at the
time of and after giving effect to such Restricted Payment:
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(1) |
no Default or Event of Default will have occurred and be
continuing or would occur as a consequence thereof; and |
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(2) |
Allis-Chalmers would, at the time of such Restricted Payment and
after giving pro forma effect thereto as if such Restricted
Payment had been made at the beginning of the applicable
four-quarter period,
have been permitted to Incur at least $1.00 of additional
Indebtedness pursuant to the Fixed Charge Coverage Ratio test
set forth in the first paragraph of the covenant described below
under the caption Incurrence of
Indebtedness; and |
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(3) |
such Restricted Payment, together with the aggregate amount of
all other Restricted Payments made by Allis-Chalmers and its
Restricted Subsidiaries after the Issue Date (excluding
Restricted Payments permitted by clauses (2), (3), (4),
(5), (6), (8), (10) and (12) of the next succeeding
paragraph (B)), is less than the sum, without duplication,
of: |
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(a) |
50% of the Consolidated Net Income of Allis-Chalmers for the
period (taken as one accounting period) from the beginning of
the first fiscal quarter commencing after the Issue Date to the
end of Allis-Chalmers most recently ended fiscal quarter
for which internal financial statements are available at the
time of such Restricted Payment (or, if such Consolidated Net
Income for such period is a deficit, less 100% of such deficit),
plus |
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(b) |
100% of (A) (i) the aggregate net cash proceeds and
(ii) the Fair Market Value of (x) marketable
securities (other than marketable securities of Allis-Chalmers),
(y) Capital Stock of a Person (other than Allis-Chalmers or
an Affiliate of Allis-Chalmers) engaged in a Permitted Business
and (z) other assets used in any Permitted Business, in the
case of clauses (i) and (ii), received by Allis-Chalmers
since the Issue Date as a contribution to its common equity
capital or from the issue or sale of Equity Interests of
Allis-Chalmers (other than Disqualified Stock) or from the issue
or sale of convertible or exchangeable Disqualified Stock or
convertible or exchangeable debt securities of Allis-Chalmers
that have been converted into or exchanged for such Equity
Interests (other than Equity Interests (or Disqualified Stock or
debt securities) sold to a Subsidiary of Allis-Chalmers),
(B) the amount by which Indebtedness of Allis-Chalmers or
any Restricted Subsidiary is reduced on
Allis-Chalmers
consolidated balance sheet upon the conversion or exchange after
the Issue Date of any such Indebtedness into or for Equity
Interests (other than Disqualified Stock) of
Allis-Chalmers, and
(C) the aggregate net cash proceeds, if any, received by
Allis-Chalmers or any of its Restricted Subsidiaries upon any
conversion or exchange described in clause (A) or
(B) above, plus |
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(c) |
with respect to Restricted Investments made by Allis-Chalmers
and its Restricted Subsidiaries after the Issue Date, an amount
equal to the sum of (A) the net reduction in such
Restricted Investments in any Person resulting from
(i) repayments of loans or advances, or other transfers of
assets, in each case to Allis-Chalmers or any Restricted
Subsidiary, (ii) other repurchases, repayments or
redemptions of such Restricted Investments, (iii) the sale
of any such Restricted Investment or (iv) the release of
any Guarantee (except to the extent any amounts are paid under
such Guarantee) plus (B) all amounts representing
the return of capital (excluding dividends and distributions) to
Allis-Chalmers or any Restricted Subsidiary in respect of such
Restricted Investment plus (C) with respect to any
Unrestricted Subsidiary that the Board of Directors of
Allis-Chalmers redesignates as a Restricted Subsidiary, the Fair
Market Value of the Investment in such Subsidiary held by
Allis-Chalmers or any of its Restricted Subsidiaries at the time
of such redesignation. |
(B) The preceding provisions will not prohibit, so long as,
in the case of clauses (7) and (8) below, no Default
has occurred and is continuing or would be caused thereby:
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(1) |
the payment of any dividend within 60 days after the date
of declaration thereof, if at said date of declaration such
payment would have complied with the provisions of the indenture; |
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(2) |
the payment of any dividend or similar distribution by a
Restricted Subsidiary of
Allis-Chalmers to the
holders of its Equity Interests on a pro rata basis; |
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(3) |
the making of any Restricted Payment in exchange for, or out of
the net cash proceeds of the substantially concurrent sale
(other than to a Subsidiary of Allis-Chalmers) of, Equity
Interests of Allis-Chalmers (other than Disqualified Stock) or
from the substantially concurrent contribution (other than by a
Subsidiary of Allis-Chalmers) of capital to Allis-Chalmers in
respect of its Equity Interests (other than Disqualified Stock);
provided that the amount of any such net cash proceeds
that are utilized for any such Restricted Payment will be
excluded from clause (3)(b) of the preceding
paragraph (A); |
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(4) |
the defeasance, redemption, repurchase, retirement or other
acquisition of Subordinated Indebtedness with the net cash
proceeds from a substantially concurrent incurrence of Permitted
Refinancing Indebtedness; provided that the amount of any
such net cash proceeds that are utilized for any such
defeasance, redemption, repurchase, retirement or other
acquisition of Indebtedness will be excluded from
clause (3)(b) of the preceding paragraph (A); |
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(5) |
Investments acquired as a capital contribution to, or in
exchange for, or out of the net cash proceeds of a substantially
concurrent sale (other than to a Subsidiary of Allis-Chalmers)
of, Equity Interests (other than Disqualified Stock) of
Allis-Chalmers; provided that the amount of any such net
cash proceeds that are utilized for any such acquisition or
exchange will be excluded from clause (3)(b) of the
preceding paragraph (A); |
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(6) |
the repurchase, redemption or other acquisition or retirement of
Equity Interests deemed to occur upon the exercise or exchange
of stock options, warrants or other similar rights to the extent
such Equity Interests represent a portion of the exercise or
exchange price of those stock options, and the repurchase,
redemption or other acquisition or retirement of Equity
Interests made in lieu of withholding taxes resulting from the
exercise or exchange of stock options, warrants or other similar
rights; |
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(7) |
the repurchase, redemption or other acquisition or retirement
for value of any Equity Interests of Parent, Allis-Chalmers or
any Restricted Subsidiary of Allis-Chalmers held by any current
or former officer, director or employee (or any of their
respective heirs or estates or permitted transferees) of Parent,
Allis-Chalmers or any Restricted Subsidiary of Allis-Chalmers
pursuant to any equity subscription agreement, stock option
agreement, stockholders agreement or similar agreement;
provided that the aggregate price paid for all such
repurchased, redeemed, acquired or retired Equity Interests in
any calendar year will not exceed $2.0 million (with unused
amounts in any calendar year being carried over to succeeding
calendar years subject to a maximum (without giving effect to
the following proviso) of $6.0 million in any calendar
year); provided further that such amount in any calendar
year may be increased by an amount not to exceed (A) the
cash proceeds received by Allis-Chalmers from the sale of Equity
Interests of
Allis-Chalmers to
members of management or directors of Allis-Chalmers and its
Restricted Subsidiaries that occurs after the Issue Date (to the
extent the cash proceeds from the sale of such Equity Interests
have not otherwise been applied to the payment of Restricted
Payments by virtue of clause 3(b) of the preceding
paragraph (A)), plus (B) the cash proceeds of
key man life insurance policies received by Allis-Chalmers and |
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its Restricted Subsidiaries
after the Issue Date, less (C) the amount of any
Restricted Payments made pursuant to clauses (A) and
(B) of this clause (7);
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(8) |
dividends on Preferred Stock or
Disqualified Stock issued in compliance with the covenant
Incurrence of Indebtedness to the extent
such dividends are included in the definition of Fixed Charges;
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(9) |
the payment of cash in lieu of
fractional Equity Interests;
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(10) |
Permitted Payments to Parent; |
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(11) |
payments or distributions to dissenting stockholders pursuant to
applicable law in connection with a merger, consolidation or
transfer of assets that complies with the provisions described
under the caption Covenants
Merger, Consolidation or Sales of Assets; and |
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(12) |
other Restricted Payments in an aggregate amount at any one time
outstanding not to exceed $15.0 million. |
In determining whether any Restricted Payment is permitted by
the foregoing covenant,
Allis-Chalmers may
allocate or reallocate all or any portion of such Restricted
Payment among the clauses of the preceding
paragraph (B) or among such clauses and the provisions
of paragraph (A) of this covenant, provided
that at the time of such allocation or reallocation, all
such Restricted Payments, or allocated portions thereof, would
be permitted under the various provisions of the foregoing
covenant.
The amount of all Restricted Payments will be the Fair Market
Value on the date of the Restricted Payment of the asset(s) or
securities proposed to be transferred or issued by
Allis-Chalmers or such Restricted Subsidiary, as the case may
be, pursuant to the Restricted Payment. The Fair Market Value of
any assets or securities (other than cash or Cash Equivalents)
that are required to be valued by this covenant will be
determined by the Board of Directors of Allis-Chalmers whose
resolution with respect thereto will be delivered to the
trustee. The Board of Directors determination must be
based upon an opinion or appraisal issued by an Independent
Financial Advisor if such Fair Market Value exceeds
$15.0 million.
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Incurrence of
Indebtedness |
Allis-Chalmers will not, and will not permit any of its
Restricted Subsidiaries to, directly or indirectly, Incur any
Indebtedness (including Acquired Debt); provided,
however, that Allis-Chalmers or any Guarantor may Incur
Indebtedness (including Acquired Debt), if the Fixed Charge
Coverage Ratio for Allis-Chalmers most recently ended four
full fiscal quarters for which internal financial statements are
available immediately preceding the date on which such
additional Indebtedness is Incurred would have been at least 2.0
to 1, determined on a pro forma basis (including a pro
forma application of the net proceeds therefrom), as if the
additional Indebtedness had been Incurred at the beginning of
such four-quarter period.
The first paragraph of this covenant will not prohibit the
Incurrence of any of the following items of Indebtedness
(collectively, Permitted Debt):
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(1) |
the Incurrence by Allis-Chalmers or any Guarantor of additional
Indebtedness under Credit Facilities (including, without
limitation, the Incurrence by Allis-Chalmers and the Guarantors
of Guarantees thereof) in an aggregate amount at any one time
outstanding pursuant to this clause (1) not to exceed a
maximum amount equal to the greater of
(a) $25.0 million or (b) 10.0% of the
Consolidated Tangible Assets of Allis-Chalmers; provided,
however, that the maximum amount permitted to be outstanding
under this |
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clause (1) shall not be
deemed to limit additional Indebtedness under the Credit
Facilities to the extent the Incurrence of such additional
Indebtedness is permitted pursuant to any of the other
provisions of this covenant;
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(2) |
the Incurrence of Existing
Indebtedness;
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(3) |
the Incurrence by Allis-Chalmers
and the Guarantors of Indebtedness represented by the notes and
the related Subsidiary Guarantees to be issued on the Issue Date
and the exchange notes and the related Subsidiary Guarantees to
be issued pursuant to the Registration Rights Agreement;
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(4) |
the Incurrence by Allis-Chalmers
or any Restricted Subsidiary of Allis-Chalmers of Indebtedness
represented by Capital Lease Obligations, mortgage financings or
purchase money obligations, in each case, Incurred for the
purpose of financing all or any part of the purchase price or
cost of construction, installation, improvement, deployment,
refurbishment, modification or lease of property, plant or
equipment or furniture, fixtures and equipment, in each case
used in the business of Allis-Chalmers or such Restricted
Subsidiary, in an aggregate amount, including all Permitted
Refinancing Indebtedness Incurred to refund, refinance or
replace any Indebtedness Incurred pursuant to this
clause (4), not to exceed the greater of
(a) $10.0 million at any time outstanding or
(b) 5.0% of Consolidated Tangible Assets of Allis-Chalmers;
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(5) |
the Incurrence by Allis-Chalmers
or any Restricted Subsidiary of Allis-Chalmers of Permitted
Refinancing Indebtedness in exchange for, or the net proceeds of
which are used to refund, refinance, replace, defease or
discharge Indebtedness (other than intercompany Indebtedness)
that was permitted by the indenture to be Incurred under the
first paragraph of this covenant or clauses (2), (3), (4),
(5), (9) or (13) of this paragraph;
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(6) |
the Incurrence by Allis-Chalmers
or any of its Restricted Subsidiaries of intercompany
Indebtedness owing to and held by Allis-Chalmers or any of its
Restricted Subsidiaries; provided, however, that
(i) any subsequent issuance or transfer of Equity Interests
that results in any such Indebtedness being held by a Person
other than Allis-Chalmers or a Restricted Subsidiary thereof and
(ii) any sale or other transfer of any such Indebtedness to
a Person that is not either
Allis-Chalmers or a
Restricted Subsidiary thereof, will be deemed, in each case, to
constitute an Incurrence of such Indebtedness by Allis-Chalmers
or such Restricted Subsidiary, as the case may be, that was not
permitted by this clause (6); |
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(7) |
the Guarantee by Allis-Chalmers
or any of the Guarantors of Indebtedness of
Allis-Chalmers or a
Restricted Subsidiary of Allis-Chalmers that was permitted to be
Incurred by another provision of this covenant; |
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(8) |
the Incurrence by Allis-Chalmers
or any of its Restricted Subsidiaries of Hedging Obligations
that are Incurred for the purpose of fixing, hedging or swapping
interest rate, commodity price or foreign currency exchange rate
risk (or to reverse or amend any such agreements previously made
for such purposes), and not for speculative purposes, and that
do not increase the Indebtedness of the obligor outstanding at
any time other than as a result of fluctuations in interest
rates, commodity prices or foreign currency exchange rates or by
reason of fees, indemnities and compensation payable thereunder;
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(9) |
the Incurrence by Allis-Chalmers
or any of its Restricted Subsidiaries of Indebtedness in respect
of workers compensation claims, self-insurance
obligations, bankers acceptances, performance bonds,
completion bonds, bid bonds, appeal bonds and surety bonds or
other
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similar bonds or obligations,
and any Guarantees or letters of credit functioning as or
supporting any of the foregoing;
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(10) |
the Incurrence by Allis-Chalmers or any of its Restricted
Subsidiaries of Indebtedness constituting reimbursement
obligations with respect to letters of credit issued in the
ordinary course of business; provided that, upon the
drawing of such letters of credit or the Incurrence of such
Indebtedness, such obligations are reimbursed within one year
following such drawing or Incurrence; |
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(11) |
the Incurrence by Allis-Chalmers of Indebtedness to the extent
that the net proceeds thereof are promptly deposited to defease
or to satisfy and discharge the notes; |
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(12) |
the Incurrence by Foreign Subsidiaries of Indebtedness in an
aggregate amount outstanding at any one time not to exceed 15%
of such Foreign Subsidiaries Consolidated Tangible
Assets; or |
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(13) |
the Incurrence by Allis-Chalmers or any of its Restricted
Subsidiaries of additional Indebtedness in an aggregate amount
at any time outstanding, including all Permitted Refinancing
Indebtedness Incurred to refund, refinance, defease, discharge
or replace any Indebtedness Incurred pursuant to this
clause (13), not to exceed $10.0 million. |
For purposes of determining compliance with this covenant, in
the event that any proposed Indebtedness meets the criteria of
more than one of the categories of Permitted Debt described in
clauses (1) through (13) above, or is entitled to be
Incurred pursuant to the first paragraph of this covenant,
Allis-Chalmers will be permitted to divide and classify such
item of Indebtedness at the time of its Incurrence in any manner
that complies with this covenant. In addition, any Indebtedness
originally divided or classified as Incurred pursuant to
clauses (1) through (13) above may later be
re-divided or
reclassified by Allis-Chalmers such that it will be deemed as
having been Incurred pursuant to another of such clauses
provided that such re-divided or reclassified Indebtedness could
be Incurred pursuant to such new clause at the time of such
re-division or reclassification. Notwithstanding the foregoing,
Indebtedness under the Credit Agreement outstanding on the Issue
Date will be deemed to have been Incurred on such date in
reliance on the exception provided by clause (1) of the
definition of Permitted Debt.
Notwithstanding any other provision of this covenant, the
maximum amount of Indebtedness that may be Incurred pursuant to
this covenant will not be deemed to be exceeded with respect to
any outstanding Indebtedness due solely to the result of
fluctuations in the exchange rates of currencies.
Allis-Chalmers will not Incur any Indebtedness that is
subordinate in right of payment to any other Indebtedness of
Allis-Chalmers unless it is subordinate in right of payment to
the notes to the same extent. Allis-Chalmers will not permit any
Guarantor to Incur any Indebtedness that is subordinate in right
of payment to any other Indebtedness of such Guarantor unless it
is subordinate in right of payment to such Guarantors
Subsidiary Guarantee to the same extent. For purposes of the
foregoing, solely for the avoidance of doubt and without any
other implication, no Indebtedness will be deemed to be
subordinated in right of payment to any other Indebtedness of
Allis-Chalmers or any Guarantor, as applicable, solely by reason
of any Liens or Guarantees arising or created in respect thereof
or by virtue of the fact that the holders of any secured
Indebtedness have entered into intercreditor agreements giving
one or more of such holders priority over the other holders in
the collateral held by them.
Allis-Chalmers will not, and will not permit any of its
Restricted Subsidiaries to, create, incur, assume or suffer to
exist any Lien securing Indebtedness, upon any asset now owned
or hereafter
119
acquired, except Permitted Liens, unless the notes are equally
and ratably secured (except that Liens securing Subordinated
Indebtedness shall be expressly subordinate to any Lien securing
the notes to at least the same extent such Subordinated
Indebtedness is subordinate to the notes).
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Dividend and Other Payment
Restrictions Affecting Restricted Subsidiaries |
Allis-Chalmers will not, and will not permit any of its
Restricted Subsidiaries to create or permit to exist or become
effective any consensual encumbrance or restriction on the
ability of any Restricted Subsidiary to:
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(1) |
pay dividends or make any other distributions on its Capital
Stock (or with respect to any other interest or participation
in, or measured by, its profits) to Allis-Chalmers or any of its
Restricted Subsidiaries or pay any liabilities owed to
Allis-Chalmers or any of its Restricted Subsidiaries; |
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(2) |
make loans or advances to Allis-Chalmers or any of its
Restricted Subsidiaries; or |
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(3) |
transfer any of its properties or assets to Allis-Chalmers or
any of its Restricted Subsidiaries. |
However, the preceding restrictions will not apply to
encumbrances or restrictions:
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(1) |
existing under, by reason of or with respect to any Credit
Facility, Existing Indebtedness, Capital Stock or any other
agreements or instruments in effect on the Issue Date and any
amendments, modifications, restatements, renewals, extensions,
supplements, refundings, replacements or refinancings thereof,
provided that the encumbrances and restrictions in any
such amendments, modifications, restatements, renewals,
increases, extensions, supplements, refundings, replacement or
refinancings are, in the reasonable good faith judgment of the
Chief Executive Officer and the Chief Financial Officer of
Allis-Chalmers, no more restrictive, taken as a whole, than
those contained in the Credit Agreement, Existing Indebtedness,
Capital Stock or such other agreements or instruments, as the
case may be, as in effect on the Issue Date; |
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(2) |
set forth in the indenture, the notes and the Subsidiary
Guarantees or contained in any other instrument relating to any
other Indebtedness so long as the Board of Directors determines
that such encumbrances or restrictions are no more restrictive
in the aggregate than those contained in the indenture; |
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(3) |
existing under, by reason of or with respect to applicable law,
rule, regulation or order; |
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(4) |
with respect to any Person or the property or assets of a Person
acquired by
Allis-Chalmers or any
of its Restricted Subsidiaries existing at the time of such
acquisition, which encumbrance or restriction is not applicable
to any Person or the properties or assets of any Person, other
than the Person, or the property or assets of the Person, so
acquired and any amendments, modifications, restatements,
renewals, increases, extensions, supplements, refundings,
replacements or refinancings thereof, provided that the
encumbrances and restrictions in any such amendments,
modifications, restatements, renewals, increases, extensions,
supplements, refundings, replacement or refinancings are, in the
reasonable good faith judgment of the Chief Executive Officer
and the Chief Financial Officer of Allis-Chalmers, no more
restrictive, taken as a whole, than those in effect on the date
of the acquisition; |
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(5) |
Indebtedness Incurred or Capital Stock issued by any Restricted
Subsidiary, provided that the restrictions contained in
the agreements or instruments governing such Indebtedness |
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or Capital Stock (a) either
(i) apply only in the event of a payment default or a
default with respect to a financial covenant in such agreement
or instrument or (ii) will not materially affect
Allis-Chalmers ability to pay all principal, interest and
premium and Liquidated Damages, if any, on the notes, as
determined in good faith by the Chief Executive Officer and the
Chief Financial Officer of
Allis-Chalmers, whose
determination shall be conclusive; and (b) are not
materially more disadvantageous to the Holders of the notes than
is customary in comparable financings (as determined by the
Chief Financial Officer of Allis-Chalmers, whose determination
shall be conclusive); |
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(6) |
in the case of clause (3)
of the first paragraph of this covenant:
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(A) |
that restrict in a customary manner the subletting, assignment
or transfer of any property or asset that is a lease, license,
conveyance or contract or similar property or asset; |
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(B) |
existing by virtue of any transfer of, agreement to transfer,
option or right with respect to, or Lien on, any property or
assets of Allis-Chalmers or any Restricted Subsidiary thereof
not otherwise prohibited by the indenture; |
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(C) |
purchase money obligations for property acquired in the ordinary
course of business and Capital Lease Obligations; |
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(D) |
provisions limiting the disposition or distribution of assets or
property in joint venture agreements, asset sale agreements,
sale-leaseback agreements, stock sale agreements and other
similar agreements entered into with the approval of
Allis-Chalmers Board of Directors or in the ordinary
course of business, which limitation is applicable only to the
assets that are the subject of such agreements; |
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(E) |
any instrument governing secured Indebtedness; and |
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(F) |
arising or agreed to in the ordinary course of business, not
relating to any Indebtedness, and that do not, individually or
in the aggregate, detract from the value of property or assets
of Allis-Chalmers or any Restricted Subsidiary thereof in any
manner material to Allis-Chalmers or any Restricted Subsidiary
thereof; |
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(7) |
existing under, by reason of or with respect to any agreement
for the sale or other disposition of all or substantially all of
the Capital Stock of, or property and assets of, a Restricted
Subsidiary that restrict distributions by that Restricted
Subsidiary pending such sale or other disposition; |
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(8) |
Permitted Refinancing Indebtedness; provided that the
restrictions contained in the agreements governing such
Permitted Refinancing Indebtedness are not materially more
restrictive, taken as a whole, than those contained in the
agreements governing the Indebtedness being refinanced; |
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(9) |
Liens permitted to be incurred under the provisions of the
covenant described above under the caption
Liens that limit the right of the debtor
to dispose of the assets subject to such Liens; |
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(10) |
encumbrances or restrictions contained in agreements entered
into in connection with Hedging Obligations permitted from time
to time under the indenture; and |
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(11) |
existing under restrictions on cash or other deposits or net
worth imposed by customers or required by insurance, surety or
bonding companies, in each case, under contracts entered into in
the ordinary course of business. |
121
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Merger, Consolidation or
Sale of Assets |
Allis-Chalmers will not: (1) consolidate or merge with or
into another Person (regardless of whether Allis-Chalmers is the
surviving corporation) or (2) directly or indirectly sell,
assign, transfer, convey or otherwise dispose of all or
substantially all of the properties and assets of Allis-Chalmers
and its Restricted Subsidiaries taken as a whole, in one or more
related transactions, to another Person, unless:
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(1) |
either: (a) Allis-Chalmers is the surviving corporation; or
(b) the Person formed by or surviving any such
consolidation or merger (if other than Allis-Chalmers) or to
which such sale, assignment, transfer, conveyance or other
disposition will have been made (i) is a corporation
organized or existing under the laws of the United States, any
state thereof or the District of Columbia and (ii) assumes
all the obligations of Allis-Chalmers under the notes, the
indenture and the Registration Rights Agreement pursuant to
agreements reasonably satisfactory to the trustee; |
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(2) |
immediately after giving effect to such transaction, no Default
or Event of Default exists; |
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(3) |
either (A) immediately after giving effect to such
transaction on a pro forma basis,
Allis-Chalmers or the
Person formed by or surviving any such consolidation or merger
(if other than Allis-Chalmers), or to which such sale,
assignment, transfer, conveyance or other disposition will have
been made will be permitted to Incur at least $1.00 of
additional Indebtedness pursuant to the Fixed Charge Coverage
Ratio test set forth in the first paragraph of the covenant
described above under the caption Incurrence
of Indebtedness; or (B) immediately after giving
effect to such transaction on a pro forma basis and any related
financing transactions as if the same had occurred at the
beginning of the applicable four quarter period, the Fixed
Charge Coverage Ratio of
Allis-Chalmers is equal
to or greater than its Fixed Charge Coverage Ratio immediately
before such transaction; and |
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(4) |
Allis-Chalmers delivers to the trustee an Officers
Certificate (attaching the arithmetic computation to demonstrate
compliance with clause (3) above) and Opinion of Counsel,
in each case stating that such transaction and such agreement
complies with this covenant and that all conditions precedent
provided for herein relating to such transaction have been
complied with. |
Upon any merger or consolidation, or any sale, transfer,
assignment, conveyance or other disposition of all or
substantially all of the properties or assets of Allis-Chalmers
and its Restricted Subsidiaries in accordance with this
covenant, the successor Person formed by the consolidation or
into which Allis-Chalmers is merged or to which the sale,
transfer, assignment, conveyance or other disposition is made,
will succeed to and be substituted for Allis-Chalmers, and may
exercise every right and power of Allis-Chalmers under the
indenture with the same effect as if the successor had been
named as Allis-Chalmers therein. When the successor assumes all
of Allis-Chalmers obligations under the indenture,
Allis-Chalmers will be discharged from those obligations;
provided, however, that
Allis-Chalmers shall
not be relieved from the obligation to pay the principal of and
interest on the notes except in the case of a sale of all of
Allis-Chalmers assets in a transaction that is subject to,
and that complies with the provisions of this covenant.
In addition, Allis-Chalmers and its Restricted Subsidiaries may
not, directly or indirectly, lease all or substantially all of
the properties or assets of Allis-Chalmers and its Restricted
Subsidiaries considered as one enterprise, in one or more
related transactions, to any other Person.
122
This Merger, Consolidation or Sale of Assets
covenant will not apply to:
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(1) |
a merger of Allis-Chalmers with an Affiliate solely for the
purpose of reincorporating Allis-Chalmers in another
jurisdiction; or |
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(2) |
any merger or consolidation, or any sale, transfer, assignment,
conveyance, lease or other disposition of assets between or
among Allis-Chalmers and its Restricted Subsidiaries that are
Guarantors. |
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Transactions with
Affiliates |
Allis-Chalmers will not, and will not permit any of its
Restricted Subsidiaries to, make any payment to, or sell, lease,
transfer or otherwise dispose of any of its properties or assets
to, or purchase any property or assets from, or enter into,
make, amend, renew or extend any transaction, contract,
agreement, understanding, loan, advance or Guarantee with, or
for the benefit of, any Affiliate of
Allis-Chalmers (each,
an Affiliate Transaction), unless:
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(1) |
such Affiliate Transaction is on terms that are no less
favorable to Allis-Chalmers or the relevant Restricted
Subsidiary than those that would have been obtained in a
comparable
arms-length
transaction by Allis-Chalmers or such Restricted Subsidiary with
a Person that is not an Affiliate of Allis-Chalmers; and |
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(2) |
Allis-Chalmers delivers to the trustee: |
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(a) |
with respect to any Affiliate Transaction or series of related
Affiliate Transactions involving aggregate consideration in
excess of $5.0 million, a Board Resolution set forth in an
Officers Certificate certifying that such Affiliate
Transaction or series of related Affiliate Transactions complies
with this covenant and that such Affiliate Transaction or series
of related Affiliate Transactions has been approved by a
majority of the disinterested members of the Board of Directors
of Allis-Chalmers; and |
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(b) |
with respect to any Affiliate Transaction or series of related
Affiliate Transactions involving aggregate consideration in
excess of $15.0 million, an opinion as to the fairness to
Allis-Chalmers or such Restricted Subsidiary of such Affiliate
Transaction or series of related Affiliate Transactions from a
financial point of view issued by an Independent Financial
Advisor. |
The following items will not be deemed to be Affiliate
Transactions and, therefore, will not be subject to the
provisions of the prior paragraph:
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(1) |
transactions between or among Allis-Chalmers and/or its
Restricted Subsidiaries; |
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(2) |
payment of reasonable and customary fees to, and reasonable and
customary indemnification and similar payments on behalf of,
directors of Allis-Chalmers and its Subsidiaries; |
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(3) |
any Permitted Investments or Restricted Payments that are
permitted by the provisions of the indenture described above
under the caption Restricted Payments; |
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(4) |
any issuance of Equity Interests (other than Disqualified Stock)
of Allis-Chalmers, or receipt of any capital contribution from
any Affiliate of Allis-Chalmers; |
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(5) |
transactions with a Person that is an Affiliate of
Allis-Chalmers solely because
Allis-Chalmers owns,
directly or through a Restricted Subsidiary, an Equity Interest
in, or controls, such Person; |
123
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(6) |
transactions pursuant to agreements or arrangements in effect on
the Issue Date and described in the offering memorandum dated
January 12, 2006 relating to the initial offering of the old
notes, or any amendment, modification, or supplement thereto or
replacement thereof, as long as such agreement or arrangement,
as so amended, modified, supplemented or replaced, taken as a
whole, is not more disadvantageous to Allis-Chalmers and its
Restricted Subsidiaries than the original agreement or
arrangement in existence on the Issue Date; |
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(7) |
loans or advances to employees in the ordinary course of
business not to exceed $2.0 million in the aggregate at any
one time outstanding; and |
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(8) |
any employment, consulting, service or termination agreement,
employee benefit plan or arrangement, reasonable and customary
indemnification arrangements or any similar agreement, plan or
arrangement, entered into by Allis-Chalmers or any of its
Restricted Subsidiaries with officers, directors, consultants or
employees of Allis-Chalmers or any of its Subsidiaries and the
payment of compensation to officers, directors, consultants and
employees of Allis-Chalmers or any of its Subsidiaries
(including amounts paid pursuant to employee benefit plans,
employee stock option or similar plans), and any payments,
indemnities or other transactions permitted or required by
bylaw, statutory provisions or any of the foregoing agreements,
plans or arrangements; so long as such agreement or payment has
been approved by a majority of the disinterested members of the
Board of Directors of Allis-Chalmers. |
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Designation of Restricted
and Unrestricted Subsidiaries |
The Board of Directors of Allis-Chalmers may designate any
Restricted Subsidiary of
Allis-Chalmers to be an
Unrestricted Subsidiary; provided that:
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(1) |
any Guarantee by Allis-Chalmers or any Restricted Subsidiary
thereof of any Indebtedness of the Subsidiary being so
designated will be deemed to be an Incurrence of Indebtedness by
Allis-Chalmers or such
Restricted Subsidiary (or both, if applicable) at the time of
such designation, and such Incurrence of Indebtedness would be
permitted under the covenant described above under the caption
Incurrence of Indebtedness; |
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(2) |
the aggregate Fair Market Value of all outstanding Investments
owned by Allis-Chalmers and its Restricted Subsidiaries in the
Subsidiary being so designated (including any Guarantee by
Allis-Chalmers or any Restricted Subsidiary thereof of any
Indebtedness of such Subsidiary) will be deemed to be a
Restricted Investment made as of the time of such designation
and that such Investment would be permitted under the covenant
described above under the caption Restricted
Payments; |
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(3) |
such Subsidiary does not hold any Liens on any property of
Allis-Chalmers or any Restricted Subsidiary thereof; |
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(4) |
the Subsidiary being so designated: |
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(a) |
is a Person with respect to which neither Allis-Chalmers nor any
of its Restricted Subsidiaries has any direct or indirect
obligation (i) to subscribe for additional Equity Interests
or (ii) to maintain or preserve such Persons
financial condition or to cause such Person to achieve any
specified levels of operating results; |
124
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(b) |
has not guaranteed or otherwise directly or indirectly provided
credit support for any Indebtedness of Allis-Chalmers or any of
its Restricted Subsidiaries, except to the extent such
Guarantee or credit support would be released upon such
designation; and |
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(c) |
has at least one director on its Board of Directors that is not
a director or officer of Allis-Chalmers or any of its Restricted
Subsidiaries and has at least one executive officer that is not
a director or officer of Allis-Chalmers or any of its Restricted
Subsidiaries; and |
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(5) |
no Default or Event of Default would be in existence following
such designation. |
Any designation of a Restricted Subsidiary of Allis-Chalmers as
an Unrestricted Subsidiary will be evidenced to the trustee by
filing with the trustee the Board Resolution giving effect to
such designation and an Officers Certificate certifying
that such designation complied with the preceding conditions and
was permitted by the indenture. If, at any time, any
Unrestricted Subsidiary would fail to meet any of the preceding
requirements described in subclauses (a) or (b) of
clause (4) above, it will thereafter cease to be an
Unrestricted Subsidiary for purposes of the indenture and any
Indebtedness of such Subsidiary will be deemed to be Incurred or
made by a Restricted Subsidiary of Allis-Chalmers as of such
date and, if such Indebtedness, Investments or Liens are not
permitted to be Incurred or made as of such date under the
indenture, Allis-Chalmers will be in default under the indenture.
The Board of Directors of Allis-Chalmers may at any time
designate any Unrestricted Subsidiary to be a Restricted
Subsidiary; provided that:
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(1) |
such designation will be deemed to be an Incurrence of
Indebtedness by a Restricted Subsidiary of Allis-Chalmers of any
outstanding Indebtedness of such Unrestricted Subsidiary and
such designation will only be permitted if such Indebtedness is
permitted under the covenant described under the caption
Incurrence of Indebtedness; and |
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(2) |
no Default or Event of Default would be in existence following
such designation. |
If Allis-Chalmers or any of its Restricted Subsidiaries acquires
or creates another Domestic Subsidiary on or after the Issue
Date, then that newly acquired or created Domestic Subsidiary
must become a Guarantor and execute a supplemental indenture and
deliver an Opinion of Counsel to the trustee within 15 business
days of the date on which it was acquired or created;
provided, however, that a Domestic Subsidiary that owns
net assets that have an aggregate fair market value (as
determined in good faith by the Board of Directors of
Allis-Chalmers) of less than 5% of the Consolidated Tangible
Assets as of the end of the previous quarter, need not become a
Guarantor.
However, if, as of the end of any fiscal quarter, the Domestic
Subsidiaries that are not Guarantors collectively own net assets
that have an aggregate fair market value (as determined in good
faith by our Board of Directors) equal to or greater than 5% of
the Consolidated Tangible Assets, then we will designate one or
more of such non-Guarantor Domestic Subsidiaries to become
Guarantors such that after giving effect to such designation or
designations, as the case may be, the total net assets owned by
all such remaining non-Guarantor Domestic Subsidiaries will have
an aggregate fair market value (as determined in good faith by
our Board of Directors) of less than 5% of the Consolidated
Tangible Assets. Any such Restricted Subsidiary so designated
must become a Guarantor and execute a supplemental indenture and
deliver an Opinion of Counsel to the trustee within 15 business
days of the date on which it was designated.
125
Our current and future Foreign Subsidiaries (such as DLS and its
subsidiaries) will not be required to guarantee the notes.
A Guarantor may not sell or otherwise dispose of all or
substantially all of its assets to, or consolidate with or merge
with or into (regardless of whether such Guarantor is the
surviving Person), another Person, other than Allis-Chalmers or
another Guarantor, unless:
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(1) |
immediately after giving effect to that transaction, no Default
or Event of Default exists; and |
(2) either:
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(a) |
the Person acquiring the property in any such sale or
disposition or the Person formed by or surviving any such
consolidation or merger (if other than the Guarantor) is
organized or existing under the laws of the United States, any
state thereof or the District of Columbia and assumes all the
obligations of that Guarantor under the indenture, its
Subsidiary Guarantee and the Registration Rights Agreement
pursuant to a supplemental indenture satisfactory to the
trustee; or |
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(b) |
such sale or other disposition or consolidation or merger
complies with the covenant described above under the caption
Repurchase at the Option of
Holders Asset Sales. |
The Subsidiary Guarantee of a Guarantor will be released:
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(1) |
in connection with any sale or other disposition of all or
substantially all of the assets of that Guarantor (including by
way of merger or consolidation) to a Person that is not (either
before or after giving effect to such transaction)
Allis-Chalmers or a Restricted Subsidiary of
Allis-Chalmers, if the
sale or other disposition does not violate the Asset
Sale provisions of the indenture; |
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(2) |
in connection with any sale or other disposition of all of the
Capital Stock of a Guarantor to a Person that is not (either
before or after giving effect to such transaction) a Restricted
Subsidiary of Allis-Chalmers, if the sale of all such Capital
Stock of that Guarantor complies with the covenant described
above under the caption Repurchase at the
Option of Holders Asset Sales; |
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(3) |
if Allis-Chalmers properly designates any Restricted Subsidiary
that is a Guarantor as an Unrestricted Subsidiary under the
indenture; or |
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(4) |
upon legal defeasance or satisfaction and discharge of the
indenture as provided below under the captions
Legal Defeasance and Covenant Defeasance
and Satisfaction and Discharge. |
Allis-Chalmers will not, and will not permit any of its
Restricted Subsidiaries to, directly or indirectly, pay or cause
to be paid any consideration to or for the benefit of any Holder
of notes for or as an inducement to any consent, waiver or
amendment of any of the terms or provisions of the indenture or
the notes unless such consideration is offered to be paid and is
paid to all Holders of the notes that consent, waive or agree to
amend in the time frame set forth in the solicitation documents
relating to such consent, waiver or agreement.
126
Allis-Chalmers will furnish to the trustee and, upon request, to
beneficial owners and prospective investors a copy of all of the
information and reports referred to in clauses (1) and
(2) below within the time periods specified in the
SECs rules and regulations:
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(1) |
all quarterly and annual financial information that would be
required to be contained in a filing with the SEC on
Forms 10-Q
and 10-K if
Allis-Chalmers were required to file such Forms, including a
Managements Discussion and Analysis of Financial
Condition and Results of Operations and, with respect to
the annual information only, a report on the annual financial
statements by our certified independent accountants; and |
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(2) |
all current reports that would be required to be filed with the
SEC on Form 8-K if
we were required to file such reports. |
Regardless of whether required by the SEC, Allis-Chalmers will
comply with the periodic reporting requirements of the Exchange
Act and will file the reports specified in the preceding
paragraph with the SEC within the time periods specified above
unless the SEC will not accept such a filing.
Allis-Chalmers agrees
that we will not take any action for the purpose of causing the
SEC not to accept any such filings. If, notwithstanding the
foregoing, the SEC will not accept Allis-Chalmers filings
for any reason, Allis-Chalmers will post the reports referred to
in the preceding paragraph on its Web site within the time
periods that would apply if we were required to file those
reports with the SEC.
If Allis-Chalmers has designated any of its Subsidiaries as
Unrestricted Subsidiaries, then the quarterly and annual
financial information required by this covenant will include a
reasonably detailed presentation, either on the face of the
financial statements or in the footnotes thereto, and in
Managements Discussion and Analysis of Financial
Condition and Results of Operations, of the financial
condition and results of operations of Allis-Chalmers and its
Restricted Subsidiaries separate from the financial condition
and results of operations of the Unrestricted Subsidiaries of
Allis-Chalmers.
In addition, Allis-Chalmers and the Guarantors have agreed that,
for so long as any notes remain outstanding, they will furnish
to the Holders and to prospective investors, upon their request,
the information required to be delivered pursuant to
Rule 144A(d)(4) under the Securities Act.
Events of Default and Remedies
Each of the following is an Event of Default:
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(1) |
default for 30 days in the payment when due of interest on,
or Liquidated Damages, if any, with respect to, the notes; |
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(2) |
default in payment when due of the principal of, or premium, if
any, on the notes; |
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(3) |
failure by Allis-Chalmers to comply with its obligations
described under the caption
Covenants Merger, Consolidation or
Sale of Assets or to consummate a purchase of notes when
required pursuant to the covenants described under the captions
Repurchase at the Option of
Holders Change of Control or
Repurchase at the Option of
Holders Asset Sales; |
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(4) |
failure by Allis-Chalmers or any of its Restricted Subsidiaries
for 30 days to comply with the provisions described under
the captions Covenants Restricted
Payments or Covenants
Incurrence of Indebtedness or to comply with the
provisions described under the captions
Repurchase at the Option of
Holders Change of Control or |
127
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Repurchase at
the Option of Holders Asset Sales to the
extent not described in clause (3) above;
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(5) |
failure by Allis-Chalmers or any
of its Restricted Subsidiaries for 60 days after written
notice by the trustee or Holders representing 25% or more of the
aggregate principal amount of notes outstanding to comply with
any of the other agreements in the indenture;
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(6) |
default under any mortgage,
indenture or instrument under which there may be issued or by
which there may be secured or evidenced any Indebtedness for
money borrowed by
Allis-Chalmers or any
of its Restricted Subsidiaries (or the payment of which is
Guaranteed by
Allis-Chalmers or any
of its Restricted Subsidiaries) whether such Indebtedness or
Guarantee now exists, or is created after the Issue Date, if
that default: |
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(a) |
is caused by a failure to make any payment when due at the final
maturity of such Indebtedness (a Payment
Default); or |
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(b) |
results in the acceleration of such Indebtedness prior to its
express maturity, |
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and, in each case, the principal amount of any such
Indebtedness, together with the principal amount of any other
such Indebtedness under which there has been a Payment Default
or the maturity of which has been so accelerated, aggregates
$15.0 million or more; |
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(7) |
failure by Allis-Chalmers or any of its Restricted Subsidiaries
to pay final judgments (to the extent such judgments are not
paid or covered by insurance provided by a reputable carrier
that has the ability to perform and has acknowledged coverage in
writing) aggregating in excess of $15.0 million, which
judgments are not paid, discharged or stayed for a period of
60 days; |
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(8) |
except as permitted by the indenture, any Subsidiary Guarantee
is held in any judicial proceeding to be unenforceable or
invalid or ceases for any reason to be in full force and effect
or any Guarantor, or any Person acting on behalf of any
Guarantor, denies or disaffirms its obligations under its
Subsidiary Guarantee; and |
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(9) |
certain events of bankruptcy or insolvency with respect to
Allis-Chalmers, any Guarantor or any Significant Subsidiary of
Allis-Chalmers (or any Restricted Subsidiaries that together
would constitute a Significant Subsidiary). |
The indenture contains a provision providing that in the case of
an Event of Default arising from certain events of bankruptcy or
insolvency, with respect to Allis-Chalmers, any Restricted
Subsidiary that is a Significant Subsidiary or any group of
Restricted Subsidiaries that, taken together, would constitute a
Significant Subsidiary, all outstanding notes will become due
and payable immediately without further action or notice.
However, the effect of such provision may be limited by
applicable laws. If any other Event of Default occurs and is
continuing, the trustee or the Holders of at least 25% in
principal amount of the then outstanding notes may declare all
the notes to be due and payable immediately by notice in writing
to Allis-Chalmers specifying the Event of Default.
Holders of the notes may not enforce the indenture or the notes
except as provided in the indenture. Subject to certain
limitations, Holders of a majority in principal amount of the
then outstanding notes may direct the trustee in its exercise of
any trust or power. The trustee may withhold from Holders of the
notes notice of any Default or Event of Default (except a
Default or Event of Default relating to the payment of principal
or interest or Liquidated Damages) if it determines that
withholding notice is in their interest.
128
The Holders of a majority in aggregate principal amount of the
notes then outstanding by notice to the trustee may on behalf of
the Holders of all of the notes waive any existing Default or
Event of Default and its consequences under the indenture except
a continuing Default or Event of Default in the payment of
interest or Liquidated Damages on, or the principal of, the
notes. The Holders of a majority in principal amount of the then
outstanding notes will have the right to direct the time, method
and place of conducting any proceeding for exercising any remedy
available to the trustee. However, the trustee may refuse to
follow any direction that conflicts with law or the indenture,
that may involve the trustee in personal liability, or that the
trustee determines in good faith may be unduly prejudicial to
the rights of Holders of notes not joining in the giving of such
direction and may take any other action it deems proper that is
not inconsistent with any such direction received from Holders
of notes. A Holder may not pursue any remedy with respect to the
indenture or the notes unless:
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(1) |
the Holder gives the trustee written notice of a continuing
Event of Default; |
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(2) |
the Holder or Holders of at least 25% in aggregate principal
amount of outstanding notes make a written request to the
trustee to pursue the remedy; |
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(3) |
such Holder or Holders offer the trustee indemnity satisfactory
to the trustee against any costs, liability or expense; |
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(4) |
the trustee does not comply with the request within 60 days
after receipt of the request and the offer of indemnity; and |
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(5) |
during such 60-day
period, the Holders of a majority in aggregate principal amount
of the outstanding notes do not give the trustee a direction
that is inconsistent with the request. |
However, such limitations do not apply to the right of any
Holder of a note to receive payment of the principal of, premium
or Liquidated Damages, if any, or interest on, such note or to
bring suit for the enforcement of any such payment, on or after
the due date expressed in the notes, which right will not be
impaired or affected without the consent of the Holder.
The Holders of a majority in aggregate principal amount of the
notes then outstanding by written notice to the trustee may, on
behalf of the Holders of all of the notes, rescind an
acceleration or waive any existing Default or Event of Default
and its consequences under the indenture except a continuing
Default or Event of Default in the payment of interest or
premium or Liquidated Damages on, or the principal of, the notes.
Allis-Chalmers is required to deliver to the trustee annually
within 90 days after the end of each fiscal year a
statement regarding compliance with the indenture. Upon becoming
aware of any Default or Event of Default, Allis-Chalmers is
required to deliver to the trustee a statement specifying such
Default or Event of Default.
No Personal Liability of Directors, Officers, Employees and
Stockholders
No director, officer, employee, incorporator, stockholder,
member, manager or partner of
Allis-Chalmers or any
Guarantor, as such, will have any liability for any obligations
of Allis-Chalmers or the Guarantors under the notes, the
indenture, the Subsidiary Guarantees or for any claim based on,
in respect of, or by reason of, such obligations or their
creation. Each Holder of notes by accepting a note waives and
releases all such liability. The waiver and release are part of
the consideration for issuance of the notes. The waiver may not
be effective to waive liabilities under the federal securities
laws.
129
Legal Defeasance and Covenant Defeasance
Allis-Chalmers may, at its option and at any time, elect to have
all of its obligations discharged with respect to the
outstanding notes and all obligations of the Guarantors
discharged with respect to their Subsidiary Guarantees
(Legal Defeasance) except for:
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(1) |
the rights of Holders of outstanding notes to receive payments
in respect of the principal of, or interest or premium and
Liquidated Damages, if any, on such notes when such payments are
due from the trust referred to below; |
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(2) |
Allis-Chalmers obligations with respect to the notes
concerning issuing temporary notes, registration of notes,
mutilated, destroyed, lost or stolen notes and the maintenance
of an office or agency for payment and money for security
payments held in trust; |
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(3) |
the rights, powers, trusts, duties and immunities of the
trustee, and Allis-Chalmers and the Guarantors
obligations in connection therewith; and |
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(4) |
the Legal Defeasance provisions of the indenture. |
In addition, Allis-Chalmers may, at its option and at any time,
elect to have the obligations of
Allis-Chalmers released
with respect to the provisions of the indenture described above
under Repurchase at the Option of
Holders and under Covenants (other than
the covenant described under
Covenants Merger, Consolidation or
Sale of Assets, except to the extent described below) and
the limitation imposed by clause (3) under
Covenants Merger, Consolidation or
Sale of Assets (such release and termination being
referred to as Covenant Defeasance), and
thereafter any omission to comply with such obligations or
provisions will not constitute a Default or Event of Default. In
the event Covenant Defeasance occurs in accordance with the
indenture, the Events of Default described under
clauses (3) through (7) under the caption
Events of Default and Remedies and the
Event of Default described under clause (9) under the
caption Events of Default and Remedies
(but only with respect to Subsidiaries of Allis-Chalmers), in
each case, will no longer constitute an Event of Default.
In order to exercise either Legal Defeasance or Covenant
Defeasance:
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(1) |
Allis-Chalmers must irrevocably deposit with the trustee, in
trust, for the benefit of the Holders of the notes, cash in
U.S. dollars, non-callable Government Securities, or a
combination thereof, in such amounts as will be sufficient, in
the opinion of a nationally recognized investment bank,
appraisal firm or firm of independent public accountants, to pay
the principal of, or interest and premium and Liquidated
Damages, if any, on the outstanding notes on the Stated Maturity
or on the applicable redemption date, as the case may be, and
Allis-Chalmers must specify whether the notes are being defeased
to maturity or to a particular redemption date; |
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(2) |
in the case of Legal Defeasance, Allis-Chalmers will have
delivered to the trustee an Opinion of Counsel reasonably
acceptable to the trustee confirming that
(a) Allis-Chalmers has received from, or there has been
published by, the Internal Revenue Service a ruling or
(b) since the Issue Date, there has been a change in the
applicable federal income tax law, in either case to the effect
that, and based thereon such Opinion of Counsel will confirm
that, the Holders of the outstanding notes will not recognize
income, gain or loss for federal income tax purposes as a result
of such Legal Defeasance and will be subject to federal income
tax on the same amounts, in the same manner and at the same
times as would have been the case if such Legal Defeasance had
not occurred; |
130
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(3) |
in the case of Covenant Defeasance, Allis-Chalmers will have
delivered to the trustee an Opinion of Counsel reasonably
acceptable to the trustee confirming that the Holders of the
outstanding notes will not recognize income, gain or loss for
federal income tax purposes as a result of such Covenant
Defeasance and will be subject to federal income tax on the same
amounts, in the same manner and at the same times as would have
been the case if such Covenant Defeasance had not occurred; |
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(4) |
no Default or Event of Default will have occurred and be
continuing (other than a Default or Event of Default resulting
from the borrowing of funds to be applied to such deposit)
either: (a) on the date of such deposit; or
(b) insofar as Events of Default from bankruptcy or
insolvency events are concerned, at any time in the period
ending on the 123rd day after the date of deposit; |
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(5) |
such Legal Defeasance or Covenant Defeasance will not result in
a breach or violation of, or constitute a default under, any
material agreement or instrument (other than the indenture) to
which Allis-Chalmers or any of its Subsidiaries is a party or by
which Allis-Chalmers or any of its Subsidiaries is bound; |
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(6) |
in the case of legal defeasance, Allis-Chalmers must have
delivered to the trustee an Opinion of Counsel to the effect
that, (1) assuming no intervening bankruptcy of
Allis-Chalmers or any Guarantor between the date of deposit and
the 123rd day following the deposit and assuming that no
Holder is an insider of Allis-Chalmers under
applicable bankruptcy law, after the 123rd day following
the deposit, the trust funds will not be subject to the effect
of any applicable bankruptcy, insolvency, reorganization or
similar laws affecting creditors rights generally,
including Section 547 of the United States Bankruptcy Code
and Section 15 of the New York Debtor and Creditor Law and
(2) the creation of the defeasance trust does not violate
the Investment Company Act of 1940; |
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(7) |
Allis-Chalmers must deliver to the trustee an Officers
Certificate stating that the deposit was not made by
Allis-Chalmers with the intent of preferring the Holders over
the other creditors of Allis-Chalmers with the intent of
defeating, hindering, delaying or defrauding creditors of
Allis-Chalmers or
others; |
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(8) |
Allis-Chalmers must deliver to the trustee an Officers
Certificate, stating that all conditions precedent set forth in
clauses (1) through (7) of this paragraph have been
complied with; and |
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(9) |
Allis-Chalmers must deliver to the trustee an Opinion of Counsel
(which Opinion of Counsel may be subject to customary
assumptions, qualifications and exclusions), stating that all
conditions precedent set forth in clauses (2) and
(3) of this paragraph have been complied with. |
Amendment, Supplement and Waiver
Except as provided in the next three succeeding paragraphs, the
indenture or the notes may be amended or supplemented with the
consent of the Holders of at least a majority in principal
amount of the notes then outstanding (including, without
limitation, consents obtained in connection with a purchase of,
or tender offer or exchange offer for, notes), and any existing
Default or Event of Default or compliance with any provision of
the indenture or the notes may be waived with the consent of the
Holders of a majority in principal amount of the then
outstanding notes (including, without limitation, consents
obtained in connection with a purchase of, or tender offer or
exchange offer for, notes).
131
Without the consent of each Holder affected, an amendment or
waiver may not (with respect to any notes held by a
non-consenting Holder):
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(1) |
reduce the principal amount of notes whose Holders must consent
to an amendment, supplement or waiver; |
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(2) |
reduce the principal of or change the fixed maturity of any note
or alter the provisions, or waive any payment with respect to
the redemption of the notes; provided, however, that
solely for the avoidance of doubt, and without any other
implication, any purchase or repurchase of notes, including
pursuant to the covenants described above under the caption
Repurchase at the Option of Holders,
shall not be deemed a redemption of the notes; |
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(3) |
reduce the rate of or change the time for payment of interest on
any note; |
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(4) |
waive a Default or Event of Default in the payment of principal
of, or interest, or premium or Liquidated Damages, if any, on,
the notes (except a rescission of acceleration of the notes by
the Holders of at least a majority in aggregate principal amount
of the then outstanding notes and a waiver of the payment
default that resulted from such acceleration); |
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(5) |
make any note payable in money other than U.S. dollars; |
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(6) |
make any change in the provisions of the indenture relating to
waivers of past Defaults or the rights of Holders of notes to
receive payments of principal of, or interest or premium or
Liquidated Damages, if any, on, the notes; |
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(7) |
release any Guarantor from any of its obligations under its
Subsidiary Guarantee or the indenture, except in accordance with
the terms of the indenture; |
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(8) |
impair the right to institute suit for the enforcement of any
payment on or with respect to the notes or the Subsidiary
Guarantees; |
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(9) |
amend or modify any of the provisions of the indenture or the
related definitions affecting the ranking of the notes or any
Subsidiary Guarantee in any manner adverse to the Holders of the
notes or any Subsidiary Guarantee; or |
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(10) |
make any change in the preceding amendment and waiver provisions. |
Notwithstanding the preceding, without the consent of any Holder
of notes, Allis-Chalmers, the Guarantors and the trustee may
amend or supplement the indenture or the notes:
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(1) |
to cure any ambiguity, defect or inconsistency; |
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(2) |
to provide for uncertificated notes in addition to or in place
of certificated notes; |
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(3) |
to provide for the assumption of Allis-Chalmers or any
Guarantors obligations to Holders of notes in the case of
a merger or consolidation or sale of all or substantially all of
Allis-Chalmers or
such Guarantors assets; |
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(4) |
to make any change that would provide any additional rights or
benefits to the Holders of notes or that does not materially
adversely affect the legal rights under the indenture of any
such Holder; |
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(5) |
to comply with requirements of the SEC in order to effect or
maintain the qualification of the indenture under the Trust
Indenture Act; |
132
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(6) |
to add any Subsidiary Guarantee or to effect the release of a
Guarantor from its Subsidiary Guarantee and the termination of
such Subsidiary Guarantee, all in accordance with the provisions
of the indenture governing such release and termination or to
otherwise comply with the provisions described under
Covenants Guarantees; |
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(7) |
to secure the notes or any Subsidiary Guarantees or any other
obligation under the indenture; |
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(8) |
to evidence and provide for the acceptance of appointment by a
successor trustee; |
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(9) |
to conform the text of the indenture or the notes to any
provision of this Description of notes to the extent that such
provision in this Description of notes was intended to be a
verbatim recitation of a provision of the indenture, the
Subsidiary Guarantees or the notes; or |
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(10) |
to provide for the issuance of additional notes in accordance
with the indenture. |
The consent of the Holders of the notes is not necessary under
the indenture to approve the particular form of any proposed
amendment or waiver. It is sufficient if such consent approves
the substance of the proposed amendment or waiver.
Satisfaction and Discharge
The indenture will be discharged and will cease to be of further
effect as to all notes issued thereunder, when:
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(a) |
all notes that have been authenticated (except lost, stolen or
destroyed notes that have been replaced or paid and notes for
whose payment money has theretofore been deposited in trust and
thereafter repaid to Allis-Chalmers) have been delivered to the
trustee for cancellation; or |
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(b) |
all notes that have not been delivered to the trustee for
cancellation have become due and payable by reason of the
mailing of a notice of redemption or otherwise or will become
due and payable within one year and Allis-Chalmers or any
Guarantor has irrevocably deposited or caused to be deposited
with the trustee as trust funds in trust solely for the benefit
of the Holders, cash in U.S. dollars, non-callable
Government Securities, or a combination thereof, in such amounts
as will be sufficient without consideration of any reinvestment
of interest, to pay and discharge the entire Indebtedness on the
notes not delivered to the trustee for cancellation for
principal, premium and Liquidated Damages, if any, and accrued
interest to the date of maturity or redemption; |
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(2) |
no Default or Event of Default has occurred and is continuing on
the date of the deposit (other than a Default or Event of
Default resulting from the borrowing of funds to be applied to
such deposit); |
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(3) |
such deposit will not result in a breach or violation of, or
constitute a default under, any material agreement or instrument
(other than the indenture) to which Allis-Chalmers or any
Guarantor is a party or by which Allis-Chalmers or any Guarantor
is bound; |
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(4) |
Allis-Chalmers or any Guarantor has paid or caused to be paid
all sums payable by it under the indenture; and |
133
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(5) |
Allis-Chalmers has delivered irrevocable instructions to the
trustee under the indenture to apply the deposited money toward
the payment of the notes at maturity or the redemption date, as
the case may be. |
In addition, Allis-Chalmers must deliver to the trustee
(a) an officers certificate, stating that all
conditions precedent set forth in clauses (1) through
(5) above have been satisfied, and (b) an opinion of
counsel (which opinion of counsel may be subject to customary
assumptions and qualifications), stating that all conditions
precedent set forth in clauses (3) and (5) above have
been satisfied; provided that the opinion of counsel with
respect to clause (3) above may be to the knowledge of such
counsel.
Governing Law
The indenture, the notes and the Subsidiary Guarantees are
governed by the laws of the State of New York.
Concerning the Trustee
If the trustee becomes a creditor of Allis-Chalmers or any
Guarantor, the indenture and the Trust Indenture Act limit its
right to obtain payment of claims in certain cases, or to
realize on certain property received in respect of any such
claim as security or otherwise. The trustee will be permitted to
engage in other transactions; however, if it acquires any
conflicting interest it must eliminate such conflict within
90 days, apply to the SEC for permission to continue or
resign.
The indenture provides that in case an Event of Default will
occur and be continuing, the trustee will be required, in the
exercise of its power, to use the degree of care of a prudent
man in the conduct of his own affairs. Subject to such
provisions, the trustee will be under no obligation to exercise
any of its rights or powers under the indenture at the request
of any Holder of notes, unless such Holder will have offered to
the trustee security and indemnity satisfactory to it against
any loss, liability or expense.
Book-Entry, Delivery and Form
Except as set forth below, notes will be issued in registered,
global form in minimum denominations of $2,000 and integral
multiples of $1,000 in excess thereof (Global Notes).
The Global Notes will be deposited upon issuance with the
trustee as custodian for The Depository Trust Company
(DTC), in New York, New York, and registered
in the name of DTC or its nominee, in each case for credit to an
account of a direct or indirect participant in DTC as described
below. Global Notes may also be held through Euroclear Bank,
S.A./ N.V. as the operator of the Euroclear System
(Euroclear) and Clearstream Banking, S.A.
(Clearstream) (as indirect participants in
DTC).
Except as set forth below, the Global Notes may be transferred,
in whole and not in part, only to another nominee of DTC or to a
successor of DTC or its nominee. Beneficial interests in the
Global Notes may not be exchanged for notes in certificated form
except in the limited circumstances described below. See
Exchange of Book-Entry Notes for Certificated
Notes.
Except in the limited circumstances described below, owners of
beneficial interests in the Global Notes will not be entitled to
receive physical delivery of notes in certificated form.
Transfers of beneficial interests in the Global Notes will be
subject to the applicable rules and procedures of DTC and its
direct or indirect participants (including, if applicable, those
of Euroclear and Clearstream), which may change from time to
time.
134
Depository Procedures
The following description of the operations and procedures of
DTC, Euroclear and Clearstream are provided solely as a matter
of convenience. These operations and procedures are solely
within the control of the respective settlement systems and are
subject to changes by them. Allis-Chalmers takes no
responsibility for these operations and procedures and urges
investors to contact the system or their participants directly
to discuss these matters.
DTC has advised Allis-Chalmers that DTC is a limited-purpose
trust company created to hold securities for its participating
organizations (collectively, the
Participants) and to facilitate the clearance
and settlement of transactions in those securities between
Participants through electronic
book-entry changes in
accounts of its Participants. The Participants include
securities brokers and dealers (including the Initial
Purchasers), banks, trust companies, clearing corporations and
certain other organizations. Access to DTCs system is also
available to other entities such as banks, brokers, dealers and
trust companies that clear through or maintain a custodial
relationship with a Participant, either directly or indirectly
(collectively, the Indirect Participants).
Persons who are not Participants may beneficially own securities
held by or on behalf of DTC only through the Participants or the
Indirect Participants. The ownership interests in, and transfers
of ownership interests in, each security held by or on behalf of
DTC are recorded on the records of the Participants and Indirect
Participants.
DTC has also advised Allis-Chalmers that, pursuant to procedures
established by it:
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(1) |
upon deposit of the Global Notes, DTC will credit the accounts
of Participants designated by the Initial Purchasers with
portions of the principal amount of the Global Notes; and |
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(2) |
ownership of these interests in the Global Notes will be shown
on, and the transfer of ownership thereof will be effected only
through, records maintained by DTC (with respect to the
Participants) or by the Participants and the Indirect
Participants (with respect to other owners of beneficial
interest in the Global Notes). |
Investors in the Global Notes who are Participants in DTCs
system may hold their interests therein directly through DTC.
Investors in the Global Notes who are not Participants may hold
their interests therein indirectly through organizations
(including Euroclear and Clearstream) which are Participants in
such system. Euroclear and Clearstream will hold interests in
the Global Notes on behalf of their participants through
customers securities accounts in their respective names on
the books of their respective depositories, which are Euroclear
Bank, S.A./ N.V., as operator of Euroclear, and Citibank, N.A.,
as operator of Clearstream. All interests in a Global Note,
including those held through Euroclear or Clearstream, may be
subject to the procedures and requirements of DTC. Those
interests held through Euroclear or Clearstream may also be
subject to the procedures and requirements of such systems.
Except as described below, owners of interests in the Global
Notes will not have notes registered in their names, will not
receive physical delivery of notes in certificated form and will
not be considered the registered owners or Holders
thereof under the indenture for any purpose.
Payments in respect of the principal of, and interest and
premium and Liquidated Damages, if any, on a Global Note
registered in the name of DTC or its nominee will be payable to
DTC in its capacity as the registered Holder under the
indenture. Under the terms of the indenture, Allis-Chalmers and
the trustee will treat the Persons in whose names the notes,
including the Global Notes, are registered as the owners thereof
for the purpose of receiving payments and for all other
purposes. Consequently, neither
135
Allis-Chalmers, the trustee nor any agent of Allis-Chalmers or
the trustee has or will have any responsibility or liability for:
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(1) |
any aspect of DTCs records or any Participants or
Indirect Participants records relating to or payments made
on account of beneficial ownership interest in the Global Notes
or for maintaining, supervising or reviewing any of DTCs
records or any Participants or Indirect Participants
records relating to the beneficial ownership interests in the
Global Notes; or |
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(2) |
any other matter relating to the actions and practices of DTC or
any of its Participants or Indirect Participants. |
DTC has advised Allis-Chalmers that its current practice, upon
receipt of any payment in respect of securities such as the
notes (including principal and interest), is to credit the
accounts of the relevant Participants with the payment on the
payment date unless DTC has reason to believe it will not
receive payment on such payment date. Each relevant Participant
is credited with an amount proportionate to its beneficial
ownership of an interest in the principal amount of the relevant
security as shown on the records of DTC. Payments by the
Participants and the Indirect Participants to the beneficial
owners of notes will be governed by standing instructions and
customary practices and will be the responsibility of the
Participants or the Indirect Participants and will not be the
responsibility of DTC, the trustee or Allis-Chalmers. Neither
Allis-Chalmers nor the trustee will be liable for any delay by
DTC or any of its Participants or the Indirect Participants in
identifying the beneficial owners of the notes, and
Allis-Chalmers and the trustee may conclusively rely on and will
be protected in relying on instructions from DTC or its nominee
for all purposes.
Transfers between Participants in DTC will be effected in
accordance with DTCs procedures, and will be settled in
same-day funds, and
transfers between participants in Euroclear and Clearstream will
be effected in accordance with their respective rules and
operating procedures.
Cross-market transfers
between the Participants in DTC, on the one hand, and Euroclear
or Clearstream participants, on the other hand, will be effected
through DTC in accordance with DTCs rules on behalf of
Euroclear or Clearstream, as the case may be, by their
respective depositaries; however, such
cross-market
transactions will require delivery of instructions to Euroclear
or Clearstream, as the case may be, by the counterparty in such
system in accordance with the rules and procedures and within
the established deadlines (Brussels time) of such system.
Euroclear or Clearstream, as the case may be, will, if the
transaction meets its settlement requirements, deliver
instructions to its respective depositary to take action to
effect final settlement on its behalf by delivering or receiving
interests in the relevant Global Note in DTC, and making or
receiving payment in accordance with normal procedures for
same-day funds
settlement applicable to DTC. Euroclear participants and
Clearstream participants may not deliver instructions directly
to the depositories for Euroclear or Clearstream.
DTC has advised Allis-Chalmers that it will take any action
permitted to be taken by a Holder of notes only at the direction
of one or more Participants to whose account DTC has
credited the interests in the Global Notes and only in respect
of such portion of the aggregate principal amount of the notes
as to which such Participant or Participants has or have given
such direction. However, if there is an Event of Default under
the notes, DTC reserves the right to exchange the Global Notes
for legended notes in certificated form, and to distribute such
notes to its Participants.
Although DTC, Euroclear and Clearstream have agreed to the
foregoing procedures to facilitate transfers of interests in the
Global Notes among participants in DTC, Euroclear and
Clearstream, they are under no obligation to perform or to
continue to perform such procedures, and may discontinue such
procedures at any time. Neither Allis-Chalmers nor the trustee
nor any of their respective agents will
136
have any responsibility for the performance by DTC, Euroclear or
Clearstream or their respective participants or indirect
participants of their respective obligations under the rules and
procedures governing their operations.
Exchange of Global Notes for Certificated Notes
A Global Note is exchangeable for definitive notes in registered
certificated form (Certificated notes) if:
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(1) |
DTC (a) notifies Allis-Chalmers that it is unwilling or
unable to continue as depositary for the Global Notes or
(b) has ceased to be a clearing agency registered under the
Exchange Act, and in each case Allis-Chalmers fails to appoint a
successor depositary; |
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(2) |
Allis-Chalmers, at its option, notifies the trustee in writing
that it elects to cause the issuance of Certificated notes (DTC
has advised Allis-Chalmers that, in such event, under its
current practices, DTC would notify its participants of
Allis-Chalmers request, but will only withdraw beneficial
interests from a Global Note at the request of each DTC
participant); or |
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(3) |
there will have occurred and be continuing a Default or Event of
Default with respect to the notes. |
In addition, beneficial interests in a Global Note may be
exchanged for Certificated notes upon prior written notice given
to the trustee by or on behalf of DTC in accordance with the
indenture. In all cases, Certificated notes delivered in
exchange for any Global Note or beneficial interests in Global
Notes will be registered in the names, and issued in any
approved denominations, requested by or on behalf of the
depositary (in accordance with its customary procedures).
Same Day Settlement and Payment
Allis-Chalmers will make payments in respect of the notes
represented by the Global Notes (including principal, premium,
if any, interest and Liquidated Damages, if any) by wire
transfer of immediately available funds to the accounts
specified by DTC or its nominee. Allis-Chalmers will make all
payments of principal, interest and premium and Liquidated
Damages, if any, with respect to Certificated notes by wire
transfer of immediately available funds to the accounts
specified by the Holders thereof or, if no such account is
specified, by mailing a check to each such Holders
registered address. The notes represented by the Global Notes
are expected to trade in DTCs Same-Day Funds Settlement
System, and any permitted secondary market trading activity in
such notes will, therefore, be required by DTC to be settled in
immediately available funds. Allis-Chalmers expects that
secondary trading in any Certificated notes will also be settled
in immediately available funds.
Because of time zone differences, the securities account of a
Euroclear or Clearstream participant purchasing an interest in a
Global Note from a Participant in DTC will be credited, and any
such crediting will be reported to the relevant Euroclear or
Clearstream participant, during the securities settlement
processing day (which must be a business day for Euroclear and
Clearstream) immediately following the settlement date of DTC.
DTC has advised Allis-Chalmers that cash received in Euroclear
or Clearstream as a result of sales of interests in a Global
Note by or through a Euroclear or Clearstream participant to a
Participant in DTC will be received with value on the settlement
date of DTC but will be available in the relevant Euroclear or
Clearstream cash account only as of the business day for
Euroclear or Clearstream following DTCs settlement date.
137
Definitions
Set forth below are certain defined terms used in the indenture.
Reference is made to the indenture for a full disclosure of all
such terms, as well as any other capitalized terms used herein
for which no definition is provided.
Acquired Debt means, with respect to any
specified Person, Indebtedness of any other Person existing at
the time such other Person is merged with or into or became a
Subsidiary of such specified Person, regardless of whether such
Indebtedness is incurred in connection with, or in contemplation
of, such other Person merging with or into, or becoming a
Restricted Subsidiary of, such specified Person.
Affiliate of any specified Person means any
other Person directly or indirectly controlling or controlled by
or under direct or indirect common control with such specified
Person. For purposes of this definition, control, as
used with respect to any Person, will mean the possession,
directly or indirectly, of the power to direct or cause the
direction of the management or policies of such Person, whether
through the ownership of voting securities, by agreement or
otherwise; provided that beneficial ownership of 10% or
more of the Voting Stock of a Person will be deemed to be
control. For purposes of this definition, the terms
controlling, controlled by and
under common control with will have correlative
meanings.
Asset Sale means:
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(1) |
the sale, lease, conveyance or other disposition of any assets,
other than a transaction governed by the provisions of the
indenture described above under the caption
Repurchase at the Option of
Holders Change of Control and/or the
provisions described above under the caption
Covenants Merger, Consolidation or
Sale of Assets; and |
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(2) |
the issuance of Equity Interests by any of Allis-Chalmers
Restricted Subsidiaries or the sale by Allis-Chalmers or any
Restricted Subsidiary thereof of Equity Interests in any of its
Subsidiaries (other than directors qualifying shares and
shares issued to foreign nationals to the extent required by
applicable law). |
Notwithstanding the preceding, the following items, which may
constitute all or a portion of any transaction, will be deemed
not to be Asset Sales:
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(1) |
any single transaction or series of related transactions that
involves assets or other Equity Interests having a Fair Market
Value of less than $3.0 million or for Net Proceeds of less
than such amount; |
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(2) |
any issuance or transfer of assets or Equity Interests between
or among two or more of the Persons that are among
Allis-Chalmers and its Restricted Subsidiaries; |
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(3) |
the sale, lease or other disposition of products, services,
equipment, inventory, accounts receivable or other assets in the
ordinary course of business; |
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(4) |
the sale or other disposition of cash or Cash Equivalents; |
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(5) |
dispositions (including without limitation surrenders and
waivers) of accounts receivable or other contract rights in
connection with the compromise, settlement or collection thereof; |
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(6) |
the issuance or sale of Equity Interests or the sale, lease or
other disposition of products, services, equipment, inventory,
accounts receivable or other assets pursuant to any |
138
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Restricted Payment that is
permitted by the covenant described above under the caption
Covenants Restricted
Payments or any Permitted Investment;
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(7) |
the trade or exchange by
Allis-Chalmers or any Restricted Subsidiary of any asset for any
other asset or assets, including any cash or Cash Equivalents
necessary in order to achieve an exchange of equivalent value;
provided, however, that the Fair Market Value of the
asset or assets received by Allis-Chalmers or any Restricted
Subsidiary in such trade or exchange (including any such cash or
Cash Equivalents) is at least equal to the Fair Market Value (as
determined in good faith by the Board of Directors or an
executive officer of Allis-Chalmers or of such Restricted
Subsidiary with responsibility for such transaction, which
determination shall be conclusive evidence of compliance with
this provision) of the asset or assets disposed of by
Allis-Chalmers or any Restricted Subsidiary pursuant to such
trade or exchange;
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(8) |
any sale, lease, conveyance or
other disposition of any assets or any sale or issuance of
Equity Interests in each case, made pursuant to a Permitted
Joint Venture Investment or a Joint Marketing Arrangement;
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(9) |
any sale or disposition of any
property or equipment that has become damaged, worn out or
obsolete or pursuant to a program for the maintenance or
upgrading of such property or equipment; and
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(10) |
the creation of a Lien not prohibited by the indenture and any
disposition of assets resulting from the enforcement or
foreclosure of any such Lien. |
Beneficial Owner has the meaning assigned to
such term in
Rule 13d-3 and
Rule 13d-5 under
the Exchange Act, except that in calculating the beneficial
ownership of any particular person (as that term is
used in Section 13(d)(3) of the Exchange Act), such
person will be deemed to have beneficial ownership
of all securities that such person has the right to
acquire by conversion or exercise of other securities, whether
such right is currently exercisable or is exercisable only upon
the occurrence of a subsequent condition. The terms
Beneficially Owns, Beneficially Owned
and Beneficially Owning will have a corresponding
meaning.
Board of Directors means:
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(1) |
with respect to a corporation, the board of directors of the
corporation or, except in the context of the definitions of
Change of Control and Continuing
Directors, a duly authorized committee thereof; |
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(2) |
with respect to a partnership, the Board of Directors of the
general partner of the partnership; and |
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(3) |
with respect to any other Person, the board or committee of such
Person serving a similar function. |
Board Resolution means a resolution certified
by the Secretary or an Assistant Secretary of Allis-Chalmers to
have been duly adopted by the Board of Directors of
Allis-Chalmers and to be in full force and effect on the date of
such certification.
business day means any day other than a Legal
Holiday.
Capital Lease Obligation means, at the time
any determination thereof is to be made, the amount of the
liability in respect of a capital lease that would at that time
be required to be capitalized on a balance sheet in accordance
with GAAP, and the Stated Maturity thereof shall be the date of
the
139
last payment of rent or any other amount due under such lease
prior to the first date upon which such lease may be prepaid by
the lessee without payment of a penalty.
Capital Stock means:
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(1) |
in the case of a corporation, corporate stock; |
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(2) |
in the case of an association or business entity, any and all
shares, interests, participations, rights or other equivalents
(however designated) of corporate stock; |
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(3) |
in the case of a partnership or limited liability company,
partnership or membership interests (whether general or
limited); and |
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(4) |
any other interest or participation that confers on a Person the
right to receive a share of the profits and losses of, or
distributions of assets of, the issuing Person, but excluding
from all of the foregoing any debt securities convertible into
Capital Stock, regardless of whether such debt securities
include any right of participation with Capital Stock. |
Cash Equivalents means:
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(1) |
United States dollars; |
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(2) |
securities issued or directly and fully guaranteed or insured by
the United States government or any agency or instrumentality
thereof (provided that the full faith and credit of the
United States is pledged in support of such securities),
maturing, unless such securities are deposited to defease any
Indebtedness, not more than one year from the date of
acquisition; |
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(3) |
certificates of deposit and eurodollar time deposits with
maturities of one year or less from the date of acquisition,
bankers acceptances with maturities not exceeding one year
and overnight bank deposits, in each case, with any domestic
commercial bank having capital and surplus in excess of
$500.0 million and a rating at the time of acquisition
thereof and a Thomson Bank Watch Rating of B or
higher; |
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(4) |
repurchase obligations with a term of not more than seven days
for underlying securities of the types described in
clauses (2) and (3) above entered into with any
financial institution meeting the qualifications specified in
clause (3) above; |
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(5) |
commercial paper having the highest rating obtainable from
either (i) Moodys Investors Service, Inc. or
(ii) Standard & Poors Rating Services and in
each case maturing within one year after the date of
acquisition; and |
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(6) |
securities issued and fully guaranteed by any state,
commonwealth or territory of the United States of America, or by
any political subdivision or taxing authority thereof, rated at
least A by Moodys Investors Service, Inc. or
Standard & Poors Rating Services and having
maturities of not more than one year from the date of
acquisition; and |
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(7) |
money market funds at least 95% of the assets of which
constitute Cash Equivalents of the kinds described in
clauses (1) through (6) of this definition. |
Change of Control means the occurrence of any
of the following:
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(1) |
the direct or indirect sale, transfer, conveyance or other
disposition (other than by way of merger or consolidation), in
one or a series of related transactions, of all or substantially
all of the properties or assets of Allis-Chalmers and its
Restricted Subsidiaries, taken as a |
140
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whole, to any person
(as that term is used in Section 13(d)(3) of the Exchange
Act) other than a Permitted Holder;
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(2) |
the adoption of a plan relating
to the liquidation or dissolution of Allis-Chalmers;
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(3) |
any person or
group (as such terms are used in Sections 13(d) and
14(d) of the Exchange Act) other than Parent or a Permitted
Holder becomes the Beneficial Owner, directly or indirectly, of
more than 50% of the voting power of the Voting Stock of
Allis-Chalmers; or
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(4) |
the first day on which a
majority of the members of the Board of Directors of
Allis-Chalmers are not
Continuing Directors. |
Consolidated Cash Flow means, with respect to
any specified Person for any period, the Consolidated Net Income
of such Person for such period plus:
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(1) |
any net loss realized by such Person or any of its Restricted
Subsidiaries in connection with an Asset Sale, to the extent
such losses were deducted in computing such Consolidated Net
Income; plus |
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(2) |
all extraordinary, unusual or non-recurring items of loss or
expense to the extent deducted in computing such Consolidated
Net Income; plus |
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(3) |
provision for taxes based on income or profits of such Person
and its Restricted Subsidiaries for such period, to the extent
that such provision for taxes was deducted in computing such
Consolidated Net Income; plus |
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(4) |
Fixed Charges of such Person and its Restricted Subsidiaries for
such period, to the extent that any such Fixed Charges were
deducted in computing such Consolidated Net Income; plus |
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(5) |
depreciation, amortization (including amortization of
intangibles but excluding amortization of prepaid cash expenses
that were paid in a prior period) and other non-cash expenses
(excluding any such non-cash expense to the extent that it
represents an accrual of or reserve for cash expenses in any
future period or amortization of a prepaid cash expense that was
paid in a prior period) of such Person and its Restricted
Subsidiaries for such period to the extent that such
depreciation, amortization and other non-cash expenses were
deducted in computing such Consolidated Net Income; plus |
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(6) |
all expenses related to restricted stock and redeemable stock
interests granted to officers, directors and employees, to the
extent such expenses were deducted in computing such
Consolidated Net Income; minus |
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(7) |
non-cash items increasing such Consolidated Net Income for such
period, other than the accrual of revenue in the ordinary course
of business; |
in each case, on a consolidated basis and determined in
accordance with GAAP.
Notwithstanding the preceding, the provision for taxes based on
the income or profits of, the Fixed Charges of and the
depreciation and amortization and other non-cash expenses of, a
Restricted Subsidiary of Allis-Chalmers will be added to
Consolidated Net Income to compute Consolidated Cash Flow of
Allis-Chalmers (A) in the same proportion that the Net
Income of such Restricted Subsidiary was added to compute such
Consolidated Net Income of Allis-Chalmers and (B) only to
the extent that a corresponding amount would be permitted at the
date of determination to be dividended or distributed directly
or indirectly to Allis-Chalmers by such Restricted Subsidiary
without prior governmental
141
approval (that has not been obtained), and without restriction
pursuant to the terms of its charter and all agreements,
instruments, judgments, decrees, orders, statutes, rules and
governmental regulations applicable to that Subsidiary or its
stockholders (without regard to any restrictions existing by
reason of, or any governmental approvals necessary pursuant to,
any law, rule, regulation, order or decree that is generally
applicable to all Persons operating in any jurisdiction in which
Allis-Chalmers or any of its Restricted Subsidiaries are
conducting business so long as there is in effect no specific
order, decree or other prohibition pursuant to any such law,
rule or regulation in such jurisdiction limiting the payment of
a dividend or similar distribution by such Restricted
Subsidiary).
Consolidated Net Income means, with respect
to any specified Person for any period, the aggregate of the Net
Income of such Person and its Subsidiaries for such period, on a
consolidated basis, determined in accordance with GAAP;
provided that:
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(1) |
the Net Income or loss of any Person that is not a Restricted
Subsidiary or that is accounted for by the equity method of
accounting will be included only to the extent of the amount of
dividends or similar distributions paid in cash to the specified
Person or a Restricted Subsidiary thereof; |
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(2) |
the Net Income of any Restricted Subsidiary will be excluded to
the extent that the declaration or payment of dividends or
similar distributions by that Restricted Subsidiary of that Net
Income is not at the date of determination permitted without any
prior governmental approval (that has not been obtained) or,
directly or indirectly, by operation of the terms of its charter
or any judgment, decree, order, statute, rule or governmental
regulation applicable to that Restricted Subsidiary or its
equityholders (without regard to any restrictions existing by
reason of, or any governmental approvals necessary pursuant to,
any law, rule, regulation, order or decree that is generally
applicable to all Persons operating in any jurisdiction in which
Allis-Chalmers or any of its Restricted Subsidiaries are
conducting business so long as there is in effect no specific
order, decree or other prohibition pursuant to any such law,
rule or regulation in such jurisdiction limiting the payment of
a dividend or similar distribution by such Restricted
Subsidiary); |
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(3) |
the cumulative effect of a change in accounting principles will
be excluded; and |
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(4) |
to the extent deducted in the calculation of Net Income, any
non-recurring charges associated with any premium or penalty
paid, write-offs of deferred financing costs or other financial
recapitalization charges in connection with redeeming or
retiring any Indebtedness prior to its Stated Maturity will be
added back to arrive at Consolidated Net income. |
Consolidated Tangible Assets means, with
respect to any Person as of any date, the amount which, in
accordance with GAAP, would be set forth under the caption
Total Assets (or any like caption) on a consolidated
balance sheet of such Person and its Restricted Subsidiaries,
less all goodwill, patents, tradenames, trademarks, copyrights,
franchises, experimental expenses, organization expenses and any
other amounts classified as intangible assets in accordance with
GAAP.
Continuing Directors means, as of any date of
determination, any member of the Board of Directors of
Allis-Chalmers who:
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(1) |
was a member of such Board of Directors on the Issue
Date; or |
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(2) |
was nominated for election or elected to such Board of Directors
with the approval of a majority of the Continuing Directors who
were members of such Board of Directors at the time of such
nomination or election. |
142
Credit Agreement means the Amended and
Restated Credit Agreement, dated as of January 18, 2006 by
and among Allis-Chalmers, Royal Bank of Canada, as
Administrative Agent, and the other lenders named therein
providing for up to $25.0 million of revolving credit
borrowings, including any standby letters of credit, related
notes, Guarantees, collateral documents, instruments and
agreements executed in connection therewith, and in each case as
amended, restated, modified, renewed, refunded, replaced or
refinanced from time to time, regardless of whether such
amendment, restatement, modification, renewal, refunding,
replacement or refinancing is with the same financial
institutions or otherwise.
Credit Facilities means one or more debt
facilities (including, without limitation, the Credit
Agreement), commercial paper facilities, in each case with banks
or other institutional lenders, providing for revolving credit
loans, term loans, receivables financing (including through the
sale of receivables to such lenders or to special purpose
entities formed to borrow from such lenders against such
receivables), one or more letters of credit, or one or more
indentures or similar agreements, including any related bond,
note, debentures, Guarantees, collateral documents, instruments
and agreements executed in connection therewith, in each case,
as amended, restated, modified, renewed, refunded, replaced or
refinanced (including by means of sales of debt securities to
institutional investors) in whole or in part from time to time.
Default means any event that is, or with the
passage of time or the giving of notice or both would be, an
Event of Default.
Disqualified Stock means any Capital Stock
that, by its terms (or by the terms of any security into which
it is convertible, or for which it is exchangeable, in each case
at the option of the holder thereof), or upon the happening of
any event, matures or is mandatorily redeemable, pursuant to a
sinking fund obligation or otherwise, or redeemable at the
option of the holder thereof, in whole or in part, on or prior
to the date that is 91 days after the date on which the
notes mature. Notwithstanding the preceding sentence, any
Capital Stock that would constitute Disqualified Stock solely
because the holders thereof have the right to require
Allis-Chalmers to repurchase such Capital Stock upon the
occurrence of a change of control or an asset sale will not
constitute Disqualified Stock if the terms of such Capital Stock
provide that Allis-Chalmers may not repurchase or redeem any
such Capital Stock pursuant to such provisions unless such
repurchase or redemption complies with the covenant described
above under the caption Covenants
Restricted Payments. The amount of Disqualified Stock
deemed to be outstanding at any time for purposes of the
indenture will be the maximum amount that Allis-Chalmers and its
Restricted Subsidiaries may become obligated to pay upon the
maturity of, or pursuant to any mandatory redemption provisions
of, such Disqualified Stock, exclusive of accrued dividends.
Domestic Subsidiary means each Restricted
Subsidiary of Allis-Chalmers organized or existing under the
laws of the United States, any state thereof or the District of
Columbia.
Equity Interests means Capital Stock and all
warrants, options or other rights to acquire Capital Stock (but
excluding any debt security that is convertible into, or
exchangeable for, Capital Stock).
Equity Offering means any issuance or sale of
Equity Interests (other than Disqualified Stock), or a
contribution to the equity capital, of Allis-Chalmers to any
Person (other than a Restricted Subsidiary of Allis-Chalmers).
Existing Indebtedness means the aggregate
amount of Indebtedness of Allis-Chalmers and its Restricted
Subsidiaries (other than Indebtedness under the Credit Agreement
or under the notes and the related Subsidiary Guarantees) in
existence on the Issue Date after giving effect to the
application of the
143
proceeds of (1) the notes and (2) any borrowings made
under the Credit Agreement on the Issue Date, until such amounts
are repaid.
Fair Market Value means the value that would
be paid by a willing buyer to an unaffiliated willing seller in
a transaction not involving distress or necessity of either
party, determined in good faith by the Board of Directors of
Allis-Chalmers (unless otherwise provided in the indenture).
Fixed Charges means, with respect to any
specified Person for any period, the sum, without duplication,
of:
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(1) |
the consolidated interest expense of such Person and its
Restricted Subsidiaries for such period, whether paid or
accrued, including, without limitation, amortization of debt
issuance costs and original issue discount, non-cash interest
payments, the interest component of any deferred payment
obligations, the interest component of all payments associated
with Capital Lease Obligations, commissions, discounts and other
fees and charges incurred in respect of letter of credit or
bankers acceptance financings, and net of the effect of
all payments made or received pursuant to Hedging Obligations;
plus |
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(2) |
the consolidated interest of such Person and its Restricted
Subsidiaries that was capitalized during such period; plus |
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(3) |
any interest expense on Indebtedness of another Person that is
Guaranteed by such Person or one of its Restricted Subsidiaries
or secured by a Lien on assets of such Person or one of its
Restricted Subsidiaries, whether or not such Guarantee or Lien
is called upon; plus |
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(4) |
all dividends, whether paid or accrued and whether or not in
cash, on any series of Disqualified Stock of such Person or any
of its Restricted Subsidiaries or Preferred Stock of such
Persons Restricted Subsidiaries, other than dividends on
Equity Interests payable solely in Equity Interests (other than
Disqualified Stock) of Allis-Chalmers or to Allis-Chalmers or a
Restricted Subsidiary of Allis-Chalmers, |
in each case, on a consolidated basis and in accordance with
GAAP.
Fixed Charge Coverage Ratio means, with
respect to any specified Person for any period, the ratio of the
Consolidated Cash Flow of such Person for such period to the
Fixed Charges of such Person for such period. In the event that
the specified Person or any of its Restricted Subsidiaries
Incurs, repays, repurchases or redeems any Indebtedness (other
than the incurrence or repayment of revolving credit borrowings,
except to the extent that a repayment is accompanied by a
permanent reduction in revolving credit commitments) or issues,
repurchases or redeems Disqualified Stock subsequent to the
commencement of the period for which the Fixed Charge Coverage
Ratio is being calculated and on or prior to the date on which
the event for which the calculation of the Fixed Charge Coverage
Ratio is made (the Calculation Date), then
the Fixed Charge Coverage Ratio will be calculated giving pro
forma effect to such Incurrence, repayment, repurchase or
redemption of Indebtedness, or such issuance, repurchase or
redemption of Disqualified Stock, and the use of the proceeds
therefrom as if the same had occurred at the beginning of such
period.
In addition, for purposes of calculating the Fixed Charge
Coverage Ratio:
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(1) |
acquisitions and dispositions of business entities or property
and assets constituting a division or line of business of any
Person that have been made by the specified Person or any of its
Restricted Subsidiaries, including through mergers or
consolidations, during the four-quarter reference period or
subsequent to such reference period and on or prior to the
Calculation Date will be given pro forma effect as if they had
occurred on the first day of the four-quarter reference period,
and Consolidated Cash Flow for such reference period |
144
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will be calculated on a pro
forma basis in good faith on a reasonable basis by a responsible
financial or accounting Officer of
Allis-Chalmers;
provided, that such Officer may in his discretion include
any pro forma changes to Consolidated Cash Flow, including any
pro forma reductions of expenses and costs, that have occurred
or are reasonably expected by such Officer to occur (regardless
of whether such expense or cost savings or any other operating
improvements could then be reflected properly in pro forma
financial statements prepared in accordance with
Regulation S-X
under the Securities Act or any other regulation or policy of
the SEC); |
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(2) |
the Consolidated Cash Flow
attributable to discontinued operations, as determined in
accordance with GAAP, will be excluded;
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(3) |
the Fixed Charges attributable
to discontinued operations, as determined in accordance with
GAAP, will be excluded, but only to the extent that the
obligations giving rise to such Fixed Charges will not be
obligations of the specified Person or any of its Restricted
Subsidiaries following the Calculation Date; and
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(4) |
Fixed Charges attributable to
interest on any Indebtedness (whether existing or being
Incurred) computed on a pro forma basis and bearing a
floating interest rate will be computed as if the rate in effect
on the Calculation Date (taking into account any interest rate
option, swap, cap or similar agreement applicable to such
Indebtedness if such agreement has a remaining term in excess of
12 months or, if shorter, at least equal to the remaining
term of such Indebtedness) had been the applicable rate for the
entire period.
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Foreign Subsidiary means any Restricted
Subsidiary of Allis-Chalmers other than a Domestic Subsidiary.
GAAP means generally accepted accounting
principles set forth in the opinions and pronouncements of the
Accounting Principles Board of the American Institute of
Certified Public Accountants, the opinions and pronouncements of
the Public Company Accounting Oversight Board and in the
statements and pronouncements of the Financial Accounting
Standards Board or in such other statements by such other entity
as have been approved by a significant segment of the accounting
profession, which are in effect from time to time.
Government Securities means securities that
are direct obligations of, or obligations guaranteed by, the
United States of America for the timely payment of which its
full faith and credit is pledged.
Guarantee means, as to any Person, a
guarantee other than by endorsement of negotiable instruments
for collection in the ordinary course of business, direct or
indirect, in any manner including, without limitation, by way of
a pledge of assets or through letters of credit or reimbursement
agreements in respect thereof, of all or any part of any
Indebtedness of another Person.
Guarantors means:
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(1) |
the Initial Guarantors; and |
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(2) |
any other subsidiary that executes a Subsidiary Guarantee in
accordance with the provisions of the indenture; |
and their respective successors and assigns until released from
their obligations under their Subsidiary Guarantees and the
indenture in accordance with the terms of the indenture.
145
Hedging Obligations means, with respect to
any specified Person, the obligations of such Person under:
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(1) |
interest rate swap agreements, interest rate cap agreements,
interest rate collar agreements and other agreements or
arrangements with respect to interest rates; |
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(2) |
commodity swap agreements, commodity option agreements, forward
contracts and other agreements or arrangements with respect to
commodity prices; |
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(3) |
foreign exchange contracts, currency swap agreements and other
agreements or arrangements with respect to foreign currency
exchange rates; |
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(4) |
other agreements or arrangements designed to protect such Person
or any Restricted Subsidiaries against fluctuations in interest
rates, commodity prices or currency exchange rates; and |
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(5) |
letters of credit and reimbursement obligations with respect to
letters of credit, in each case supporting obligations of the
types described in the preceding clauses of this definition. |
Holder means a Person in whose name a note is
registered.
Incur means, with respect to any
Indebtedness, to incur, create, issue, assume, Guarantee or
otherwise become directly or indirectly liable for or with
respect to, or become responsible for, the payment of,
contingently or otherwise, such Indebtedness (and
Incurrence and Incurred
will have meanings correlative to the foregoing); provided
that (1) any Indebtedness of a Person existing at the
time such Person becomes a Restricted Subsidiary of
Allis-Chalmers will be deemed to be Incurred by such Restricted
Subsidiary at the time it becomes a Restricted Subsidiary of
Allis-Chalmers and (2) neither the accrual of interest nor
the accretion of original issue discount nor the payment of
interest in the form of additional Indebtedness with the same
terms and the payment of dividends on Disqualified Stock in the
form of additional shares of the same class of Disqualified
Stock (to the extent provided for when the Indebtedness or
Disqualified Stock on which such interest or dividend is paid
was originally issued) will be considered an Incurrence of
Indebtedness; provided that in each case the amount
thereof is for all other purposes included in the Fixed Charges
and Indebtedness of
Allis-Chalmers or its
Restricted Subsidiary as accrued.
Indebtedness means, with respect to any
specified Person, any indebtedness of such Person, whether or
not contingent:
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(1) |
in respect of borrowed money; |
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(2) |
evidenced by bonds, notes, debentures or similar instruments or
letters of credit (or reimbursement agreements in respect
thereof); |
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(3) |
in respect of bankers acceptances; |
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(4) |
in respect of Capital Lease Obligations; |
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(5) |
in respect of the balance deferred and unpaid of the purchase
price of any property or services due more than six months after
such property is acquired or such services are completed, except
any such balance that constitutes an accrued expense or a trade
payable; |
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(6) |
representing Hedging Obligations; or |
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(7) |
representing Disqualified Stock valued at the greater of its
voluntary or involuntary maximum fixed repurchase price plus
accrued dividends, |
146
if and to the extent any of the preceding items (other than
letters of credit and Hedging Obligations) would appear as a
liability upon a balance sheet of the specified Person prepared
in accordance with GAAP. In addition, the term
Indebtedness includes (x) all Indebtedness of
others secured by a Lien on any asset of the specified Person
(whether or not such Indebtedness is assumed by the specified
Person), provided that the amount of such Indebtedness
will be the lesser of (A) the Fair Market Value of such
asset at such date of determination and (B) the amount of
such Indebtedness, and (y) to the extent not otherwise
included, the Guarantee by the specified Person of any
Indebtedness of any other Person. For purposes hereof, the
maximum fixed repurchase price of any Disqualified
Stock which does not have a fixed repurchase price will be
calculated in accordance with the terms of such Disqualified
Stock, as applicable, as if such Disqualified Stock were
repurchased on any date on which Indebtedness will be required
to be determined pursuant to the indenture.
Notwithstanding the foregoing, the following shall not
constitute Indebtedness:
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(1) |
accrued expenses and trade accounts payable arising in the
ordinary course of business; |
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(2) |
any indebtedness that has been defeased in accordance with GAAP
or defeased pursuant to the deposit of cash or Cash Equivalents
(in an amount sufficient to satisfy all obligations relating
thereto at maturity or redemption, as applicable, including all
payments of interest and premium, if any) in a trust or account
created or pledged for the sole benefit of the holders of such
indebtedness, and subject to no other Liens, and in accordance
with the other applicable terms of the instrument governing such
indebtedness; |
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(3) |
any obligation arising from the honoring by a bank or other
financial institution of a check, draft or similar instrument
drawn against insufficient funds in the ordinary course of
business; provided, however, that such obligation is
extinguished within five business days of its
incurrence; and |
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(4) |
any obligation arising from any agreement providing for
indemnities, Guarantees, purchase price adjustments, holdbacks,
contingency payment obligations based on the performance of the
acquired or disposed assets or similar obligations (other than
Guarantees of Indebtedness) incurred by any Person in connection
with the acquisition or disposition of any assets, including
Capital Stock. |
The amount of any Indebtedness outstanding as of any date will
be the outstanding balance at such date of all unconditional
obligations as described above and, with respect to contingent
obligations, the maximum liability upon the occurrence of the
contingency giving rise to the obligation, and will be:
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(1) |
the accreted value thereof, in the case of any Indebtedness
issued with original issue discount; and |
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(2) |
the principal amount thereof, together with any interest thereon
that is more than 30 days past due, in the case of any
other Indebtedness. |
Independent Financial Advisor means a
nationally recognized accounting, appraisal or investment
banking firm that is, in the reasonable judgment of the Board of
Directors, qualified to perform the task for which such firm has
been engaged hereunder and disinterested and independent with
respect to Allis-Chalmers and its Affiliates; provided that
providing accounting, appraisal or investment banking services
to Allis-Chalmers or any of its Affiliates or having an
employee, officer or other representative serving as a member of
the Board of Directors of Allis-Chalmers or any of its
Affiliates will not disqualify any firm from being an
Independent Financial Advisor.
Initial Guarantors means all of the Domestic
Subsidiaries of Allis-Chalmers.
147
Investments means, with respect to any
Person, all direct or indirect investments by such Person in
other Persons (including Affiliates) in the form of loans or
other extensions of credit (including Guarantees), advances,
capital contributions (by means of any transfer of cash or other
property to others or any payment for property or services for
the account or use of others, excluding commission, travel and
similar advances to officers and employees made in the ordinary
course of business and excluding accounts receivables created or
acquired in the ordinary course of business), purchases or other
acquisitions for consideration of Indebtedness, Equity Interests
or other securities, together with all items that are or would
be classified as investments on a balance sheet prepared in
accordance with GAAP.
If Allis-Chalmers or any Restricted Subsidiary of Allis-Chalmers
sells or otherwise disposes of any Equity Interests of any
direct or indirect Restricted Subsidiary of Allis-Chalmers such
that, after giving effect to any such sale or disposition, such
Person is no longer a Restricted Subsidiary of
Allis-Chalmers,
Allis-Chalmers will be deemed to have made an Investment on the
date of any such sale or disposition equal to the Fair Market
Value of the Investment in such Subsidiary not sold or disposed
of. The acquisition by Allis-Chalmers or any Restricted
Subsidiary of Allis-Chalmers of a Person that holds an
Investment in a third Person will be deemed to be an Investment
by Allis-Chalmers or such Restricted Subsidiary in such third
Person in an amount equal to the Fair Market Value of the
Investment held by the acquired Person in such third Person.
Issue Date means January 18, 2006 (the
first date of original issuance of the old notes under the
indenture).
Joint Marketing Arrangement means any joint
venture, partnership, lease, joint marketing agreement,
operating agreement, or other arrangement (which may or may not
include joint ownership of any Person) pursuant to which
Allis-Chalmers or any of its Restricted Subsidiaries arrange for
the marketing, lease or sale of products and services and share
in the profits therefrom.
Legal Holiday means a Saturday, a Sunday or a
day on which banking institutions in The City of New York or
Houston, Texas or at a place of payment are authorized or
required by law, regulation or executive order to remain closed.
Lien means, with respect to any asset, any
mortgage, lien, pledge, charge, security interest or encumbrance
of any kind in respect of such asset, whether or not filed,
recorded or otherwise perfected under applicable law, including
any conditional sale or other title retention agreement, any
lease in the nature thereof, any option or other agreement to
sell or give a security interest in and any filing of or
agreement to give any financing statement under the Uniform
Commercial Code (or equivalent statutes) of any jurisdiction.
Liquidated Damages means all Liquidated
Damages then owing pursuant to the Registration Rights Agreement.
Net Income means, with respect to any
specified Person, the net income (loss) of such Person,
determined in accordance with GAAP and before any reduction in
respect of Preferred Stock dividends, excluding, however:
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(1) |
any gain or loss, together with any related provision for taxes
on such gain or loss, realized in connection with: (a) any
Asset Sale; or (b) the disposition of any securities by
such Person or any of its Restricted Subsidiaries or the
extinguishment of any Indebtedness of such Person or any of its
Restricted Subsidiaries; and |
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any extraordinary gain or loss, together with any related
provision for taxes on such extraordinary gain or loss. |
148
Net Proceeds means the aggregate cash
proceeds, including payments in respect of deferred payment
obligations (to the extent corresponding to the principal, but
not the interest component, thereof) received by Allis-Chalmers
or any of its Restricted Subsidiaries in respect of any Asset
Sale (including, without limitation, any cash received upon the
sale or other disposition of any non-cash consideration received
in any Asset Sale), net of (1) the direct costs relating to
such Asset Sale, including, without limitation, legal,
accounting, investment banking and brokerage fees, and sales
commissions, and any relocation expenses incurred as a result
thereof, (2) taxes paid or payable as a result thereof, in
each case, after taking into account any available tax credits
or deductions and any tax sharing arrangements, (3) amounts
required to be applied to the repayment of Indebtedness or other
liabilities secured by a Lien on the asset or assets that were
the subject of such Asset Sale or required to be paid as a
result of such sale, (4) any reserve for adjustment in
respect of the sale price of such asset or assets established in
accordance with GAAP, (5) in the case of any Asset Sale by
a Restricted Subsidiary of Allis-Chalmers, payments to holders
of Equity Interests in such Restricted Subsidiary in such
capacity (other than such Equity Interests held by
Allis-Chalmers or any Restricted Subsidiary thereof) to the
extent that such payment is required to permit the distribution
of such proceeds in respect of the Equity Interests in such
Restricted Subsidiary held by Allis-Chalmers or any Restricted
Subsidiary thereof, and (6) appropriate amounts to be
provided by Allis-Chalmers or its Restricted Subsidiaries as a
reserve against liabilities associated with such Asset Sale,
including, without limitation, pension and other post-employment
benefit liabilities, liabilities related to environmental
matters and liabilities under any indemnification obligations
associated with such Asset Sale, all as determined in accordance
with GAAP; provided that (a) excess amounts set
aside for payment of taxes pursuant to clause (2) above
remaining after such taxes have been paid in full or the statute
of limitations therefor has expired and (b) amounts
initially held in reserve pursuant to clause (6) no longer
so held, will, in the case of each of subclause (a) and
(b), at that time become Net Proceeds.
Obligations means any principal, interest,
penalties, fees, indemnifications, reimbursements, damages and
other liabilities payable under the documentation governing any
Indebtedness.
Officer means, with respect to any Person,
the Chairman of the Board, the Chief Executive Officer, the
President, the Chief Operating Officer, the Chief Financial
Officer, the Treasurer, any Assistant Treasurer, the Controller,
the Secretary, any Assistant Secretary or any Vice-President of
such Person.
Officers Certificate means a
certificate signed on behalf of Allis-Chalmers by at least two
Officers of Allis-Chalmers, one of whom must be the principal
executive officer, the principal financial officer, the
treasurer or the principal accounting officer of Allis-Chalmers,
that meets the requirements of the indenture.
Opinion of Counsel means an opinion from
legal counsel who is reasonably acceptable to the trustee (who
may be counsel to or an employee of Allis-Chalmers) that meets
the requirements of the indenture.
Parent means any entity that becomes the
holder of 100% of the outstanding Equity Interests of
Allis-Chalmers in a transaction in which the Beneficial Owners
of Allis-Chalmers immediately prior to such transaction are
Beneficial Owners in the same proportion of Allis-Chalmers
immediately after such transaction.
Permitted Business means any business
conducted or proposed to be conducted (as described in the
offering memorandum dated January 12, 2006 relating to the
initial offering of the old notes) by Allis-Chalmers and its
Restricted Subsidiaries on the Issue Date and other businesses
reasonably related or ancillary thereto.
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Permitted Holder means:
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(1) |
any Officer or member of the Board of Directors of
Allis-Chalmers or any Beneficial Owner of at least 5% of
Allis-Chalmers Equity Interests as of the Issue Date; |
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(2) |
any controlling stockholder, 80% (or more) owned Subsidiary or
immediate family member (in the case of an individual) of any
Person referred to in clause (1); or |
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(3) |
any trust, corporation, partnership or other entity, the
beneficiaries, stockholders, partners, owners or Persons
Beneficially Owning an 80% or more controlling interest of which
consist of any one or more Persons referred to in
clause (1) or (2). |
Permitted Investments means:
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(1) |
any Investment in Allis-Chalmers or in a Restricted Subsidiary
of Allis-Chalmers; |
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(2) |
any Investment in cash or Cash Equivalents; |
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(3) |
any Investment by Allis-Chalmers or any Restricted Subsidiary of
Allis-Chalmers in a Person, if as a result of such Investment: |
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(a) |
such Person becomes a Restricted Subsidiary of
Allis-Chalmers; or |
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(b) |
such Person is merged, consolidated or amalgamated with or into,
or transfers or conveys substantially all of its assets to, or
is liquidated into, Allis-Chalmers or a Restricted Subsidiary of
Allis-Chalmers; |
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(4) |
any Investment made as a result of the receipt of non-cash
consideration from an Asset Sale that was made pursuant to and
in compliance with the covenant described above under the
caption Repurchase at the Option of
Holders Asset Sales; |
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(5) |
Hedging Obligations that are Incurred for the purpose of fixing,
hedging or swapping interest rate, commodity price or foreign
currency exchange rate risk (or to reverse or amend any such
agreements previously made for such purposes), and not for
speculative purposes, and that do not increase the Indebtedness
of the obligor outstanding at any time other than as a result of
fluctuations in interest rates, commodity prices or foreign
currency exchange rates or by reason of fees, indemnities and
compensation payable thereunder; |
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(6) |
stock, obligations or securities received in satisfaction of
judgments; |
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(7) |
advances to customers or suppliers in the ordinary course of
business that are, in conformity with GAAP, recorded as accounts
receivable, prepaid expenses or deposits on the balance sheet of
Allis-Chalmers or its Restricted Subsidiaries and endorsements
for collection or deposit arising in the ordinary course of
business; |
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(8) |
any Investment in any Person solely in exchange for the issuance
of Equity Interests (other than Disqualified Stock) of
Allis-Chalmers or any of its Subsidiaries; |
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(9) |
any Investments received in compromise or resolution of (A)
obligations of trade creditors or customers that were incurred
in the ordinary course of business of Allis-Chalmers or any of
its Restricted Subsidiaries, including pursuant to any plan of
reorganization or similar arrangement upon the bankruptcy or
insolvency of any trade creditor or customer; or
(B) litigation, arbitration or other disputes with Persons
who are not Affiliates; |
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(10) |
loans to officers and employees of Allis-Chalmers or any of its
Subsidiaries made in the ordinary course of business; |
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(11) |
commission, payroll, travel, entertainment and similar advances
to officers and employees of Allis-Chalmers or any of its
Restricted Subsidiaries that are expected at the time of such
advance ultimately to be recorded as an expense in conformity
with GAAP; |
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(12) |
Permitted Joint Venture Investments made by Allis-Chalmers or
any of its Restricted Subsidiaries and Investments made pursuant
to any Joint Marketing Arrangement, in an aggregate amount
(measured on the date each such Investment was made and without
giving effect to subsequent changes in value), when taken
together with all other Investments made pursuant to this
clause (12), that does not exceed $10.0 million; |
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(13) |
Investments existing on the Issue Date; |
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(14) |
repurchases of, or other Investments in, the notes; |
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(15) |
advances, deposits and prepayments for purchases of any assets,
including any Equity Interests; and |
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(16) |
other Investments in any Person having an aggregate Fair Market
Value (measured on the date each such Investment was made and
without giving effect to subsequent changes in value), when
taken together with all other Investments made pursuant to this
clause (16) since the Issue Date, not to exceed the
greater of (a) $15.0 million or (b) 5.0% of
Consolidated Tangible Assets. |
In determining whether any Investment is a Permitted Investment,
Allis-Chalmers may allocate or reallocate all or any portion of
an Investment among the clauses of this definition and any of
the provisions of the covenant described under the caption
Covenants Restricted
Payments.
Permitted Joint Venture Investment means,
with respect to an Investment by any specified Person, an
Investment by such specified Person in any other Person engaged
in a Permitted Business (a) over which the specified Person
is responsible (either directly or through a services agreement)
for day-to-day
operations or otherwise has operational and managerial control
of such other Person, or veto power over significant management
decisions affecting such other Person and (b) of which at
least 30% of the outstanding Equity Interests of such other
Person is at the time owned directly or indirectly by the
specified Person.
Permitted Liens means:
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(1) |
Liens on the assets of Allis-Chalmers and any Restricted
Subsidiary securing Indebtedness Incurred under clause (1)
of the second paragraph of the covenant described under the
caption Covenants Incurrence of
Indebtedness; |
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(2) |
Liens in favor of Allis-Chalmers or any Restricted Subsidiary; |
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(3) |
Liens on property of a Person (i) existing at the time of
acquisition thereof or (ii) existing at the time such
Person is merged with or into or consolidated with
Allis-Chalmers or any Restricted Subsidiary of Allis-Chalmers;
provided that such Liens were in existence prior to the
contemplation of such merger or consolidation and do not extend
to any assets other than those of the Person acquired or merged
into or consolidated with Allis-Chalmers or the Restricted
Subsidiary; |
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(4) |
Liens on property existing at the time of acquisition thereof by
Allis-Chalmers or any Restricted Subsidiary of Allis-Chalmers,
provided that such Liens were in existence prior to, and
not in contemplation of, such acquisition and do not extend to
any property other than the property so acquired by
Allis-Chalmers or the Restricted Subsidiary; |
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(5) |
Liens securing the notes and the Subsidiary Guarantees; |
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(6) |
Liens existing on the Issue Date (other than any Liens securing
Indebtedness Incurred under clause (1) of the covenant
described under the caption Covenants
Incurrence of Indebtedness); |
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(7) |
Liens securing Permitted Refinancing Indebtedness;
provided that such Liens do not extend to any property or
assets other than the property or assets that secure the
Indebtedness being refinanced; |
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(8) |
Liens on property or assets used to defease or to satisfy and
discharge Indebtedness; provided that (a) the
Incurrence of such Indebtedness was not prohibited by the
indenture and (b) such defeasance or satisfaction and
discharge is not prohibited by the indenture; |
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(9) |
Liens securing obligations that do not exceed $10.0 million
at any one time outstanding; |
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(10) |
Liens to secure Indebtedness (including Capital Lease
Obligations) permitted by clause (4) of the second
paragraph of the covenant described under the caption
Covenants Incurrence of
Indebtedness; provided that any such Lien
(i) covers only the assets acquired, constructed,
refurbished, installed, improved, deployed, refurbished,
modified or leased with such Indebtedness and (ii) is
created within 180 days of such acquisition, construction,
refurbishment, installation, improvement, deployment,
refurbishment, modification or lease; |
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(11) |
Liens to secure Indebtedness incurred for the purpose of
financing all or any part of the purchase price or the cost of
construction, development, expansion or improvement of the
equipment or other property subject to such Liens; provided,
however, that (a) the principal amount of any
Indebtedness secured by such a Lien does not exceed 100% of such
purchase price or cost, (b) such Lien does not extend to or
cover any property other than such item of property or any
improvements on such item of property and (c) the
incurrence of such Indebtedness is otherwise not prohibited by
the indenture; |
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(12) |
Liens securing Indebtedness of any Foreign Subsidiary which
Indebtedness is permitted by the indenture; |
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(13) |
Liens securing Hedging Obligations of Allis-Chalmers or any of
its Restricted Subsidiaries; |
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(14) |
Liens incurred or deposits made in the ordinary course of
business in connection with workers compensation,
unemployment insurance or other social security obligations; |
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(15) |
Liens, deposits or pledges to secure the performance of bids,
tenders, contracts (other than contracts for the payment of
Indebtedness), leases, or other similar obligations arising in
the ordinary course of business; |
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(16) |
survey exceptions, encumbrances, easements or reservations of,
or rights of others for, rights of way, electric lines,
telegraph and telephone lines and other similar purposes, or
zoning or other restrictions as to the use of properties, and
defects in title which, in the case of any of the foregoing,
were not incurred or created to secure the payment of
Indebtedness, and which in the aggregate do not materially
adversely affect the value of such properties or materially
impair the use for the purposes of which such properties are
held by Allis-Chalmers or any of its Restricted Subsidiaries; |
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(17) |
judgment and attachment Liens not giving rise to an Event of
Default, notices of lis pendens and associated
rights related to litigation being contested in good faith by
appropriate proceedings and for which adequate reserves have
been made and any Liens that are required to protect or enforce
any rights in any administrative, arbitration, litigation or
other court proceeding in the ordinary course of business; |
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(18) |
Liens, deposits or pledges to secure public or statutory
obligations, surety, stay, appeal, indemnity, performance or
other similar bonds or obligations; and Liens, deposits or
pledges in lieu of such bonds or obligations, or to secure such
bonds or obligations, or to secure letters of credit in lieu of
or supporting the payment of such bonds or obligations; |
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(19) |
Liens in favor of collecting or payor banks having a right of
setoff, revocation, refund or chargeback with respect to money
or instruments of Allis-Chalmers or any Subsidiary thereof on
deposit with or in possession of such bank; |
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(20) |
any interest or title of a lessor, licensor or sublicensor in
the property subject to any lease, license or sublicense; |
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(21) |
Liens for taxes, assessments and governmental charges not yet
delinquent or being contested in good faith and for which
adequate reserves have been established to the extent required
by GAAP; |
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(22) |
Liens arising from precautionary UCC financing statements
regarding operating leases or consignments; |
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(23) |
Liens of franchisors in the ordinary course of business not
securing Indebtedness; |
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(24) |
Liens imposed by law, such as carriers,
warehousemens, repairmens, landlords and
mechanics Liens or other similar Liens, in each case,
incurred in the ordinary course of business; |
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(25) |
Liens contained in purchase and sale agreements limiting the
transfer of assets pending the closing of the transactions
contemplated thereby; |
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(26) |
Liens that may be deemed to exist by virtue of contractual
provisions that restrict the ability of Allis-Chalmers or any of
its Subsidiaries from granting or permitting to exist Liens on
their respective assets; and |
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(27) |
Liens in favor of the trustee as provided for in the indenture
on money or property held or collected by the trustee in its
capacity as trustee. |
Permitted Payments to Parent means, for so
long as Allis-Chalmers is a member of a group filing a
consolidated or combined tax return with the Parent, payments to
the Parent in respect of an allocable portion of the tax
liabilities of such group that is attributable to Allis-Chalmers
and its Subsidiaries (Tax Payments). The Tax
Payments shall not exceed the lesser of (a) the amount of
the relevant tax (including any penalties and interest) that
Allis-Chalmers would owe if Allis-Chalmers were filing a
separate tax return (or a separate consolidated or combined
return with its Subsidiaries that are members of the
consolidated or combined group), taking into account any
carryovers and carrybacks of tax attributes (such as net
operating losses) of Allis-Chalmers and such Subsidiaries from
other taxable years and (b) the net amount of the relevant
tax that the Parent actually owes to the appropriate taxing
authority. Any Tax Payments received from Allis-Chalmers shall
be paid over to the appropriate taxing authority within
30 days of the Parents receipt of such Tax Payments
or refunded to Allis-Chalmers.
153
Permitted Refinancing Indebtedness means any
Indebtedness of Allis-Chalmers or any of its Restricted
Subsidiaries issued (a) in exchange for, or the net
proceeds of which are used to extend, refinance, renew, replace,
defease, discharge, refund or otherwise retire for value, in
whole or in part, or (b) constituting an amendment,
modification or supplement to or a deferral or renewal of ((a)
and (b) above collectively, a
Refinancing) any other Indebtedness of
Allis-Chalmers or any of its Restricted Subsidiaries (other than
intercompany Indebtedness); provided that:
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(1) |
the amount of such Permitted Refinancing Indebtedness does not
exceed the amount of the Indebtedness so Refinanced (plus all
accrued and unpaid interest thereon and the amount of any
reasonably determined premium necessary to accomplish such
refinancing and such reasonable expenses incurred in connection
therewith); |
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(2) |
such Permitted Refinancing Indebtedness has a final maturity
date later than the final maturity date of, and has a Weighted
Average Life to Maturity equal to or greater than the Weighted
Average Life to Maturity of, the Indebtedness being Refinanced; |
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(3) |
if the Indebtedness being Refinanced is subordinated in right of
payment to the notes or the Subsidiary Guarantees, such
Permitted Refinancing Indebtedness has a final maturity date
later than the final maturity date of the notes and is
subordinated in right of payment to the notes or the Subsidiary
Guarantees, as applicable, on terms at least as favorable, taken
as a whole, to the Holders of notes as those contained in the
documentation governing the Indebtedness being
Refinanced; and |
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(4) |
such Indebtedness is Incurred by either (a) the Restricted
Subsidiary that is the obligor on the Indebtedness being
Refinanced or (b) Allis-Chalmers. |
Person means any individual, corporation,
partnership, joint venture, association, joint-stock company,
trust, unincorporated organization, limited liability company or
government or other entity.
Preferred Stock means, with respect to any
Person, any Capital Stock of such Person that has preferential
rights to any other Capital Stock of such Person with respect to
dividends or redemptions upon liquidation.
Registration Rights Agreement means
(1) with respect to the notes issued on the Issue Date, the
Registration Rights Agreement, to be dated the Issue Date, among
Allis-Chalmers, the Initial Guarantors, RBC Capital Markets
Corporation and Morgan Keegan & Company, Inc. and
(2) with respect to any additional notes, any registration
rights agreement between Allis-Chalmers and the other parties
thereto relating to the registration by Allis-Chalmers of such
additional notes under the Securities Act.
Replacement Assets means (1) non-current
assets that will be used or useful in a Permitted Business or
(2) substantially all the assets of a Permitted Business or
a majority of the Voting Stock of any Person engaged in a
Permitted Business that will become on the date of acquisition
thereof a Restricted Subsidiary.
Restricted Investment means an Investment
other than a Permitted Investment.
Restricted Subsidiary of a Person means any
Subsidiary of such Person that is not an Unrestricted Subsidiary.
SEC means the United States Securities and
Exchange Commission.
154
Significant Subsidiary means any Subsidiary
that would be a significant subsidiary as defined in
Article 1, Rule 1-02 of
Regulation S-X,
promulgated pursuant to the Securities Act, as such Regulation
is in effect on the Issue Date.
Stated Maturity means, with respect to any
installment of interest or principal on any series of
Indebtedness, the date on which such payment of interest or
principal was scheduled to be paid in the original documentation
governing such Indebtedness, and will not include any contingent
obligations to repay, redeem or repurchase any such interest or
principal prior to the date originally scheduled for the payment
thereof.
Subordinated Indebtedness means Indebtedness
of Allis-Chalmers or a Guarantor that is contractually
subordinated in right of payment, in any respect (by its terms
or the terms of any document or instrument relating thereto), to
the notes or the Subsidiary Guarantee of such Guarantor, as
applicable.
Subsidiary means, with respect to any
specified Person:
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(1) |
any corporation, association or other business entity of which
more than 50% of the total voting power of shares of Capital
Stock entitled (without regard to the occurrence of any
contingency) to vote in the election of directors, managers or
trustees thereof is at the time owned or controlled, directly or
indirectly, by such Person or one or more of the other
Subsidiaries of that Person (or a combination thereof); and |
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(2) |
any partnership (a) the sole general partner or the
managing general partner of which is such Person or a Subsidiary
of such Person or (b) the only general partners of which
are such Person or one or more Subsidiaries of such Person (or
any combination thereof). |
Subsidiary Guarantee means a Guarantee of the
notes by a Subsidiary of Allis-Chalmers in accordance with the
provisions of the indenture.
Unrestricted Subsidiary means any Subsidiary
of Allis-Chalmers that is designated by the Board of Directors
of Allis-Chalmers as an Unrestricted Subsidiary pursuant to a
Board Resolution in compliance with the covenant described under
the caption Covenants Designation
of Restricted and Unrestricted Subsidiaries, and any
Subsidiary of such Subsidiary.
Voting Stock of any Person as of any date
means the Capital Stock of such Person that is ordinarily
entitled to vote in the election of the Board of Directors of
such Person.
Weighted Average Life to Maturity means, when
applied to any Indebtedness at any date, the number of years
obtained by dividing:
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(1) |
the sum of the products obtained by multiplying (a) the
amount of each then remaining installment, sinking fund, serial
maturity or other required payments of principal, including
payment at final maturity, in respect thereof, by (b) the
number of years (calculated to the nearest
one-twelfth) that will
elapse between such date and the making of such payment; by |
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(2) |
the then outstanding principal amount of such Indebtedness. |
155
MATERIAL U.S. FEDERAL INCOME TAX CONSIDERATIONS
The following is a discussion of the material United States
federal income tax considerations applicable to the exchange of
old notes for new notes in the exchange offer and of owning and
disposing of the notes. This discussion applies only to holders
of the notes who hold the notes as capital assets within the
meaning of Section 1221 of the Internal Revenue Code of
1986, as amended, which we refer to as the Code.
In this discussion, we do not purport to address all tax
considerations that may be important to a particular holder in
light of the holders circumstances, or to certain
categories of investors that may be subject to special rules,
such as:
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dealers in securities or currencies; |
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traders in securities; |
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U.S. holders whose functional currency is not the
U.S. dollar; |
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persons holding notes as part of a hedge, straddle, conversion
or other synthetic security or integrated
transaction; |
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certain U.S. expatriates; financial institutions; insurance
companies; |
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entities that are tax-exempt for U.S. federal income tax
purposes; and |
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partnerships and other pass-through entities. |
This discussion does not address all of the aspects of
U.S. federal income taxation that may be relevant to you in
light of your particular investment or other circumstances. If a
partnership or other entity treated as a partnership for
U.S. federal income tax purposes holds notes, the tax
treatment of a partner will generally depend on the status of
the partner and on the activities of the partnership. We
encourage partners of partnerships holding notes to consult
their tax advisors. In addition, this discussion does not
address any state, local or foreign income or other tax
consequences.
This discussion is based on U.S. federal income tax law,
including the provisions of the Code, Treasury regulations,
administrative rulings and judicial authority, all as in effect
as of the date of this document. Subsequent developments in
U.S. federal income tax law, including changes in law or
differing interpretations, which may be applied retroactively,
could have a material effect on the U.S. federal income tax
consequences of owning and disposing of notes as described in
this discussion.
We encourage you to consult your own tax advisor regarding the
particular U.S. federal, state, local and foreign income
and other tax consequences of the exchange offer and of owning
and disposing of the notes that may be applicable to you.
The Exchange Offer
An exchange of old notes for new notes pursuant to the exchange
offer will not be a taxable transaction for U.S. federal
income tax purposes. Holders will not recognize any taxable gain
or loss as a result of the exchange offer and will have the same
tax basis and holding period in the new notes as they had in the
old notes immediately before the exchange.
156
U.S. Holders
You are a U.S. holder for purposes of this
discussion if you are a beneficial owner of notes that is for
U.S. federal income tax purposes:
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a citizen or resident of the United States, |
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a corporation created or organized in or under the laws of the
United States, any state thereof or the District of Columbia, |
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an estate, the income of which is subject to U.S. federal
income taxation regardless of the source of that income, or |
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a trust, if, in general, a U.S. court is able to exercise
primary supervision over the trusts administration and one
or more U.S. persons are authorized to control all
substantial decisions of the trust. |
Generally, interest on the notes will be taxable as ordinary
interest income at the time it is paid or accrues in accordance
with your method of accounting for U.S. federal income tax
purposes. Special rules governing the treatment of discount and
premium are described below.
If you acquired a note at a discount, you may be subject to the
market discount rules of the Code. These rules
provide, in part, that gain on the sale or other disposition of
a note and partial principal payments on a note are treated as
ordinary income to the extent of accrued market discount. The
market discount rules also provide for deferral of interest
deductions with respect to debt incurred to purchase or carry a
note that has market discount.
If you acquired a note at a premium over the sum of all amounts
payable thereafter on the note that are treated as stated
redemption price at maturity, within the meaning of the
Code, you may elect to offset the premium against interest
income over the remaining term of the note in accordance with
the premium amortization provisions of the Code.
The rules concerning discounts and premiums are complex, and we
encourage you to consult your own tax advisor to determine how,
and to what extent, any discount or premium will be included in
your income or amortized, and as to the desirability, mechanics
and consequences of making any elections in connection therewith
in connection with your particular circumstances.
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Sale or Other Disposition
of Notes |
When you sell or otherwise dispose of a note in a taxable
transaction, you generally will recognize taxable gain or loss
equal to the difference, if any, between your adjusted tax basis
in the note and the amount realized on the sale or other
disposition (which does not include for this purpose any amount
attributable to accrued interest, which will be taxable in the
manner described under
U.S. Holders Payments of
Interest).
Gain or loss realized on the sale or other disposition of a note
will generally be capital gain or loss and will be long-term
capital gain or loss if the note has been held for more than one
year. You are encouraged to consult your own tax advisors
regarding the treatment of capital gains, which may be
157
taxed at lower rates than ordinary income for taxpayers who are
individuals, and losses, the deductibility of which is subject
to limitations.
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Information Reporting and
Backup Withholding |
Information reporting requirements apply to interest and
principal payments and to the proceeds of sales before maturity.
These amounts generally must be reported to the Internal Revenue
Service, or IRS. In general, backup withholding
(currently at a rate of 28%) may apply to any payments made to
you of interest on your notes, and to payment of the proceeds of
a sale or other disposition of your notes before maturity, if
you are a non-corporate U.S. holder and fail to provide a
correct taxpayer identification number, certified under
penalties of perjury, or otherwise fail to comply with
applicable requirements of the backup withholding rules. The
backup withholding tax is not an additional tax and may be
credited against your U.S. federal income tax liability if
the required information is timely provided to the IRS.
Non-U.S. Holders
The following summary applies to you if you are a
non-U.S. holder.
You generally are a
non-U.S. holder
for purposes of this discussion if you are a beneficial owner
(other than a partnership) of notes that is not a
U.S. holder, as described above.
Under current U.S. federal income tax laws, and subject to
the discussion below, U.S. federal withholding tax will not
apply to payments of interest on the notes under the
portfolio interest exemption of the Code, provided
that:
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|
you do not, directly or indirectly, actually or constructively,
own 10% or more of the total combined voting power of all
classes of our shares; |
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you are not a controlled foreign corporation that is related to
us within the meaning of the Code; and |
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the U.S. payor does not have actual knowledge or reason to
know that you are a U.S. person and either (1) you
certify to the applicable payor or its agent, under penalties of
perjury, that you are not a U.S. holder and provide your
name and address on IRS Form W-8BEN (or a suitable
substitute form) or (2) a securities clearing organization,
bank or other financial institution, that holds customers
securities in the ordinary course of its trade or business (a
financial institution) and holds the note, certifies
under penalties of perjury that a IRS Form W-8BEN (or a
suitable substitute form) has been received from you by it or by
a financial institution between it and you and furnishes the
payor with a copy of the form or the U.S. payor otherwise
possesses documentation upon which it may rely to treat the
payment as made to a non-U.S. person in accordance with
applicable U.S. Treasury regulations. |
If you cannot satisfy the requirements described above, payments
of interest made to you will be subject to the 30%
U.S. federal withholding tax, unless you provide a properly
executed IRS
Form W-8BEN or
successor form claiming an exemption from or a reduction of
withholding under the benefit of a U.S. income tax treaty,
or you provide a properly executed IRS Form W-8ECI claiming
that the payments of interest are effectively connected with
your conduct of a trade or business in the United States.
158
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Gain on Disposition of
Notes |
You generally will not be subject to U.S. federal income
and withholding tax on gain realized on the sale, exchange,
redemption or other taxable disposition of a note unless:
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you are an individual present in the United States for
183 days or more in the year of such sale, exchange,
redemption or other taxable disposition and specific other
conditions are present, or |
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the gain is effectively connected with your conduct of a
U.S. trade or business, or, if a U.S. income tax
treaty applies, is generally attributable to a
U.S. permanent establishment you maintain.
Please read Non-U.S. Holders
Income Effectively Connected with a U.S. Trade or
Business. |
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Income Effectively
Connected with a U.S. Trade or Business |
If you are engaged in a trade or business in the United States
and interest, gain or any other income in respect of your notes
is effectively connected with the conduct of your trade or
business, or, if a U.S. income tax treaty applies, you
maintain a U.S. permanent establishment to
which the interest, gain or other income is generally
attributable, you may be subject to U.S. income tax on a
net income basis on such interest, gain or income. In this
instance, however, the interest on your notes will be exempt
from the 30% U.S. withholding tax discussed under the
caption
Non-U.S. Holders
Taxation of Interest, if you provide a properly executed
IRS Form W-8ECI or appropriate substitute form to the payor
on or before any payment date to claim the exemption.
In addition, if you are a foreign corporation, you may be
subject to a U.S. branch profits tax equal to 30% of your
effectively connected earnings and profits for the taxable year,
as adjusted for certain items, unless a lower rate applies to
you under a U.S. income tax treaty with your country of
residence. For this purpose, you must include interest, gain and
income on your notes in the earnings and profits subject to the
U.S. branch profits tax if these amounts are effectively
connected with the conduct of your U.S. trade or business.
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Information Reporting and
Backup Withholding |
Payments made to you of interest on the notes and amounts, if
any, withheld from such payments will be reported to the IRS and
to you. U.S. backup withholding tax generally will not
apply to payments of interest and principal on the notes if you
have provided the required certification that you are a
non-U.S. holder as
described in
Non-U.S. Holders
Taxation of Interest above or otherwise established an
exemption, provided that the payor does not have actual
knowledge or reason to know that you are a U.S. holder or
that the conditions of any other exemptions are not in fact
satisfied.
The gross proceeds from the disposition of your notes may be
subject to information reporting and backup withholding tax.
Payments of the proceeds of a sale of your notes effected
through a U.S. office of a broker will be subject to both
U.S. backup withholding and information reporting unless
you provide an IRS Form W-8BEN certifying that you are a
non-U.S. person
and specific other conditions are met or you otherwise establish
an exemption. If you sell your notes outside the United States
through a
non-U.S. office of
a non-U.S. broker
and the sales proceeds are paid to you outside the United
States, then the U.S. backup withholding and information
reporting requirements generally will not apply to that payment.
However, U.S. information reporting, but not backup
withholding, will apply to a
159
payment of sales proceeds, even if that payment is made outside
the United States, if you sell your notes through a
non-U.S. office of
a broker that:
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is a United States person as defined in the Code; |
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derives 50% or more of its gross income in specific periods from
the conduct of a trade or business in the United States; |
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is a controlled foreign corporation for
U.S. federal income tax purposes; or |
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|
is a foreign partnership that, at any time during its taxable
year, has more than 50% of its income or capital interests owned
by U.S. persons or is engaged in the conduct of a
U.S. trade or business, unless the broker has documentary
evidence in its files that you are a
non-U.S. person
and specific other conditions are met or you otherwise establish
an exemption. |
We encourage you to consult your own tax advisor regarding
application of backup withholding in your particular
circumstances and the availability of and procedure for
obtaining an exemption from backup withholding under current
Treasury regulations. Any amounts withheld under the backup
withholding rules from a payment to you will be allowed as a
refund or credit against your U.S. federal income tax
liability, provided that the required information is furnished
to the IRS.
160
PLAN OF DISTRIBUTION
Based on interpretations by the staff of the SEC set forth in no
action letters issued to third parties, we believe that you may
transfer new notes issued under the exchange offer in exchange
for old notes unless you are:
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our affiliate within the meaning of Rule 405
under the Securities Act; |
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a broker-dealer that acquired old notes directly from us; or |
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a broker-dealer that acquired old notes as a result of
market-making or other trading activities without compliance
with the registration and prospectus delivery provisions of the
Securities Act; |
provided that you acquire the new notes in the ordinary course
of your business and you are not engaged in, and do not intend
to engage in, and have no arrangement or understanding with any
person to participate in, a distribution of the new notes.
Broker-dealers receiving new notes in the exchange offer will be
subject to a prospectus delivery requirement with respect to
resales of the new notes.
To date, the staff of the SEC has taken the position that
participating broker-dealers may fulfill their prospectus
delivery requirements with respect to transactions involving an
exchange of securities such as this exchange offer, other than a
resale of an unsold allotment from the original sale of the old
notes, with the prospectus contained in the exchange offer
registration statement.
Each broker-dealer that receives new notes for its own account
pursuant to the exchange offer must acknowledge that it will
deliver a prospectus in connection with any resale of such new
notes. This prospectus, as it may be amended or supplemented
from time to time, may be used by a broker-dealer in connection
with resales of new notes received in exchange for old notes
where such old notes were acquired as a result of market-making
activities or other trading activities. In addition,
until ,
2006, all dealers effecting transactions in the new notes may be
required to deliver a prospectus.
We will not receive any proceeds from any sale of new notes by
brokers-dealers or any other persons. New notes received by
broker-dealers for their own account pursuant to the exchange
offer may be sold from time to time in one or more transactions
in the over-the-counter
market, in negotiated transactions, through the writing of
options on the new notes or a combination of such methods of
resale, at market prices prevailing at the time of resale, at
prices related to such prevailing market prices or negotiated
prices. Any such resale may be made directly to purchasers or to
or through brokers or dealers who may receive compensation in
the form of commissions or concessions from any such
broker-dealer and/or the purchasers of any such new notes. Any
broker-dealer that resells new notes that were received by it
for its own account pursuant to the exchange offer and any
broker or dealer that participates in a distribution of such new
notes may be deemed to be an underwriter within the
meaning of the Securities Act and any profit of any such resale
of new notes and any commissions or concessions received by any
such persons may be deemed to be underwriting compensation under
the Securities Act. The letter of transmittal states that by
acknowledging that it will deliver and by delivering a
prospectus, a broker-dealer will not be deemed to admit that it
is an underwriter within the meaning of the
Securities Act.
We have agreed to pay all expenses incident to this exchange
offer other than commissions or concessions of any brokers or
dealers and will indemnify the holders of the old notes
(including any broker-dealers) against certain liabilities,
including liabilities under the Securities Act.
Each broker-dealer must acknowledge and agree that, upon receipt
of notice from us of the happening of any event which makes any
statement in the prospectus untrue in any material respect or
161
which requires the making of any changes in the prospectus to
make the statements in the prospectus not misleading, which
notice we agree to deliver promptly to the broker-dealer, the
broker-dealer will suspend use of the prospectus until we have
notified the broker-dealer that delivery of the prospectus may
resume and have furnished copies of any amendment or supplement
to the prospectus to the broker-dealer.
LEGAL MATTERS
The validity of the notes offered in the exchange offer will be
passed upon for us by Andrews Kurth LLP, Houston, Texas.
EXPERTS
The consolidated financial statements of Allis-Chalmers Energy
Inc. as of and for the years ended December 31, 2005 and
2004 included in this prospectus have been audited by UHY Mann
Frankfort Stein & Lipp CPAs, LLP, independent
registered public accounting firm, as set forth in their report
thereon appearing elsewhere herein, and are included herein in
reliance upon such report given upon the authority of said firm
as experts in auditing and accounting.
The consolidated financial statements of Allis-Chalmers Energy
Inc. as of and for the year ended December 31, 2003
included in this prospectus have been audited by Gordon, Hughes
and Banks, LLP, independent registered public accounting firm,
as set forth in their report thereon appearing elsewhere herein,
and are included in reliance upon such report given upon the
authority of said firm as experts in auditing and accounting.
The financial statements of Delta Rental Service, Inc. and
schedules and notes thereto included in this prospectus have
been audited by Wright, Moore, Dehart, Dupuis &
Hutchinson, LLC, independent certified public accountants, to
the extent and for the periods set forth in their report thereon
appearing elsewhere herein, and are included herein in reliance
upon such report given upon the authority of said firm as
experts in auditing and accounting.
The financial statements of Capcoil Tubing Services, Inc. and
schedules and notes thereto included in this prospectus have
been audited by Curtis Blakely & Co., PC, independent
certified public accountants, to the extent and for the periods
set forth in their report thereon appearing elsewhere herein,
and are included herein in reliance upon such report given upon
the authority of said firm as experts in auditing and accounting.
The financial statements of W.T. Enterprises, Inc. and schedules
and notes thereto included in this prospectus have been audited
by Accounting & Consulting Group, LLP, independent
certified public accountants, to the extent and for the periods
set forth in their report thereon appearing elsewhere herein,
and are included herein in reliance upon such report given upon
the authority of said firm as experts in auditing and accounting.
162
The financial statements of Specialty Rental Tools Inc. included
in this prospectus have been audited by UHY Mann Frankfort
Stein & Lipp CPAs, LLP, independent auditors, to the
extent and for the periods set forth in their report thereon
appearing elsewhere herein, and are included herein in reliance
upon such report given upon the authority of said firm as
experts in auditing and accounting.
The consolidated financial statements of DLS Drilling, Logistics
and Services Corporation as of December 31, 2005 and 2004
and for each of the years in the three-year period ended
December 31, 2005, have been included herein in reliance
upon the report of Sibille (formerly Finsterbusch Pickenhayn
Sibille), independent registered public accounting firm,
appearing elsewhere herein, and upon the authority of said firm
as experts in accounting and auditing.
163
INDEX TO FINANCIAL STATEMENTS
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|
|
ALLIS-CHALMERS ENERGY INC.
|
|
|
|
|
F-4 |
|
|
F-6 |
|
|
F-7 |
|
|
F-8 |
|
|
F-9 |
|
|
F-10 |
|
|
F-50 |
|
|
F-51 |
|
|
F-52 |
|
|
F-53 |
|
DELTA RENTAL SERVICE, INC.
|
|
|
|
|
F-67 |
|
|
F-68 |
|
|
F-70 |
|
|
F-71 |
|
|
F-72 |
|
|
F-73 |
|
|
F-77 |
|
|
F-78 |
|
|
F-79 |
|
|
F-80 |
|
CAPCOIL TUBING SERVICES, INC.
|
|
|
|
|
F-81 |
|
|
F-82 |
|
|
F-84 |
|
|
F-85 |
|
|
F-86 |
|
|
F-93 |
|
|
F-94 |
F-1
|
|
|
|
|
F-96 |
|
|
F-97 |
|
|
F-98 |
|
W. T. ENTERPRISES, INC.
|
|
|
|
|
F-99 |
|
|
F-100 |
|
|
F-101 |
|
|
F-102 |
|
|
F-103 |
|
|
F-104 |
|
|
F-109 |
|
|
F-110 |
|
|
F-111 |
|
|
F-112 |
|
SPECIALTY RENTAL TOOLS, INC.
|
|
|
|
|
F-113 |
|
|
F-114 |
|
|
F-115 |
|
|
F-116 |
|
|
F-117 |
|
|
F-118 |
Supplemental Information
|
|
|
|
|
F-126 |
|
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
|
|
|
|
|
F-127 |
|
|
F-128 |
|
|
F-129 |
|
|
F-130 |
|
|
F-131 |
|
|
F-132 |
F-2
|
|
|
|
|
F-148 |
|
|
F-149 |
|
|
F-150 |
|
|
F-151 |
|
|
F-152 |
|
PRO FORMA FINANCIAL INFORMATION
|
|
F-169 |
|
|
F-173 |
|
|
F-174 |
|
|
F-175 |
|
|
F-177 |
F-3
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders
Allis-Chalmers Energy Inc.
Houston, Texas
We have audited the accompanying consolidated balance sheets of
Allis-Chalmers Energy Inc. and subsidiaries as of
December 31, 2005 and 2004, and the related consolidated
statements of operations, stockholders equity and cash
flows for the years then ended. These consolidated financial
statements are the responsibility of the Companys
management. Our responsibility is to express an opinion on these
consolidated financial statements based on our audits.
We conducted our audits in accordance with the standards of the
Public Company Accounting Oversight Board (United States). Those
standards require that we plan and perform the audits to obtain
reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in
the financial statements. An audit also includes assessing the
accounting principles used and significant estimates made by
management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a
reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred
to above present fairly, in all material respects, the
consolidated financial position of Allis-Chalmers Energy Inc.
and subsidiaries as of December 31, 2005 and 2004, and the
consolidated results of their operations and their cash flows
for the years then ended, in conformity with accounting
principles generally accepted in the United States of America.
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|
|
/s/ UHY Mann Frankfort Stein & Lipp CPAs, LLP |
Houston, Texas
March 21, 2006
F-4
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors
Allis-Chalmers Energy Inc.
Houston, Texas
We have audited the accompanying consolidated statements of
operations, stockholders equity and cash flows for the
year ended December 31, 2003 of Allis-Chalmers Energy Inc.
These consolidated financial statements are the responsibility
of the Companys management. Our responsibility is to
express an opinion on these consolidated financial statements
based on our audit.
We conducted our audit in accordance with the Standards of the
Public Company Accounting Oversight Board (United States). Those
standards require that we plan and perform the audits to obtain
reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in
the financial statements. An audit also includes assessing the
accounting principles used and significant estimates made by
management, as well as evaluating the overall financial
statement presentation. We believe that our audit provides a
reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred
to above present fairly, in all material respects, the results
of its consolidated operations and cash flows for the year ended
December 31, 2003 of Allis-Chalmers Energy Inc., in
conformity with accounting principles generally accepted in the
United States of America.
As discussed in Note 2 to the consolidated financial
statements, the Company restated the consolidated financial
statements as of and for the year ended December 31, 2003.
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/s/ GORDON, HUGHES & BANKS, LLP |
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|
Greenwood Village, Colorado
March 3, 2004, except as to Note 11 which date is
June 10, 2004 and Notes 2 and 17 which date is
February 10, 2005 and
Note 2 which date is August 5, 2005.
F-5
ALLIS-CHALMERS ENERGY INC.
CONSOLIDATED BALANCE SHEETS
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|
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|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
|
(In thousands, except | |
|
|
for share amounts) | |
ASSETS
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
1,920 |
|
|
$ |
7,344 |
|
Trade receivables, net of allowance for doubtful accounts of
$383 and $265 at December 31, 2005 and 2004, respectively
|
|
|
26,964 |
|
|
|
12,986 |
|
Inventory
|
|
|
5,945 |
|
|
|
2,373 |
|
Lease receivable, current
|
|
|
|
|
|
|
180 |
|
Prepaid expenses and other
|
|
|
823 |
|
|
|
1,495 |
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
35,652 |
|
|
|
24,378 |
|
Property and equipment, at costs net of accumulated depreciation
of $9,996 and $5,251 at December 31, 2005 and 2004,
respectively
|
|
|
80,574 |
|
|
|
37,679 |
|
Goodwill
|
|
|
12,417 |
|
|
|
11,776 |
|
Other intangible assets, net of accumulated amortization of
$3,163 and $2,036 at December 31, 2005 and 2004,
respectively
|
|
|
6,783 |
|
|
|
5,057 |
|
Debt issuance costs, net of accumulated amortization of $299 and
$828 at December 31, 2005 and 2004, respectively
|
|
|
1,298 |
|
|
|
685 |
|
Lease receivable, less current portion
|
|
|
|
|
|
|
558 |
|
Other assets
|
|
|
631 |
|
|
|
59 |
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
137,355 |
|
|
$ |
80,192 |
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
Current maturities of long-term debt
|
|
$ |
5,632 |
|
|
$ |
5,541 |
|
Trade accounts payable
|
|
|
9,018 |
|
|
|
5,694 |
|
Accrued salaries, benefits and payroll taxes
|
|
|
1,271 |
|
|
|
615 |
|
Accrued interest
|
|
|
289 |
|
|
|
470 |
|
Accrued expenses
|
|
|
4,350 |
|
|
|
1,852 |
|
Accounts payable, related parties
|
|
|
60 |
|
|
|
740 |
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
20,620 |
|
|
|
14,912 |
|
Accrued postretirement benefit obligations
|
|
|
335 |
|
|
|
687 |
|
Long-term debt, net of current maturities
|
|
|
54,937 |
|
|
|
24,932 |
|
Other long-term liabilities
|
|
|
588 |
|
|
|
129 |
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
76,480 |
|
|
|
40,660 |
|
Commitments and Contingencies Minority interest
|
|
|
|
|
|
|
4,423 |
|
Stockholders Equity
|
|
|
|
|
|
|
|
|
Preferred stock, $0.01 par value (25,000,000 shares authorized,
none issued)
|
|
|
|
|
|
|
|
|
Common stock, $0.01 par value (100,000,000 shares
authorized;16,859,988 issued and outstanding at
December 31, 2005 and 20,000,000 shares authorized and
13,611,525 issued and outstanding at December 31, 2004)
|
|
|
169 |
|
|
|
136 |
|
Capital in excess of par value
|
|
|
58,889 |
|
|
|
40,331 |
|
Retained earnings (deficit)
|
|
|
1,817 |
|
|
|
(5,358 |
) |
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
60,875 |
|
|
|
35,109 |
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity
|
|
$ |
137,355 |
|
|
$ |
80,192 |
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of the Consolidated
Financial Statements.
F-6
ALLIS-CHALMERS ENERGY INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
|
|
(Restated) | |
|
(Restated) | |
|
|
(In thousands, except | |
|
|
per share amounts) | |
Revenues
|
|
$ |
105,344 |
|
|
$ |
47,726 |
|
|
$ |
32,724 |
|
Cost of revenues
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Direct costs
|
|
|
69,889 |
|
|
|
32,598 |
|
|
|
21,977 |
|
|
Depreciation
|
|
|
4,874 |
|
|
|
2,702 |
|
|
|
2,052 |
|
|
|
|
|
|
|
|
|
|
|
Gross margin
|
|
|
30,581 |
|
|
|
12,426 |
|
|
|
8,695 |
|
General and administrative expense
|
|
|
15,928 |
|
|
|
7,135 |
|
|
|
5,285 |
|
Amortization
|
|
|
1,787 |
|
|
|
876 |
|
|
|
884 |
|
Post-retirement medical costs
|
|
|
(352 |
) |
|
|
188 |
|
|
|
(99 |
) |
|
|
|
|
|
|
|
|
|
|
Income from operations
|
|
|
13,218 |
|
|
|
4,227 |
|
|
|
2,625 |
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(4,397 |
) |
|
|
(2,808 |
) |
|
|
(2,467 |
) |
Settlement on lawsuit
|
|
|
|
|
|
|
|
|
|
|
1,034 |
|
Gain on sale of interest in AirComp
|
|
|
|
|
|
|
|
|
|
|
2,433 |
|
Other
|
|
|
186 |
|
|
|
304 |
|
|
|
15 |
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense)
|
|
|
(4,211 |
) |
|
|
(2,504 |
) |
|
|
1,015 |
|
|
|
|
|
|
|
|
|
|
|
Income before minority interest and income taxes
|
|
|
9,007 |
|
|
|
1,723 |
|
|
|
3,640 |
|
Minority interest in income of subsidiaries
|
|
|
(488 |
) |
|
|
(321 |
) |
|
|
(343 |
) |
Provision for income taxes
|
|
|
(1,344 |
) |
|
|
(514 |
) |
|
|
(370 |
) |
|
|
|
|
|
|
|
|
|
|
Net income
|
|
|
7,175 |
|
|
|
888 |
|
|
|
2,927 |
|
Preferred stock dividend
|
|
|
|
|
|
|
(124 |
) |
|
|
(656 |
) |
|
|
|
|
|
|
|
|
|
|
Net income attributed to common stockholders
|
|
$ |
7,175 |
|
|
$ |
764 |
|
|
$ |
2,271 |
|
|
|
|
|
|
|
|
|
|
|
Income per common share basic
|
|
$ |
0.48 |
|
|
$ |
0.10 |
|
|
$ |
0.58 |
|
|
|
|
|
|
|
|
|
|
|
Income per common share diluted
|
|
$ |
0.44 |
|
|
$ |
0.09 |
|
|
$ |
0.50 |
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
14,832 |
|
|
|
7,930 |
|
|
|
3,927 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
16,238 |
|
|
|
9,510 |
|
|
|
5,850 |
|
|
|
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of the Consolidated
Financial Statements.
F-7
ALLIS-CHALMERS ENERGY INC.
CONSOLIDATED STATEMENT OF STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common Stock | |
|
Capital in | |
|
Retained | |
|
|
|
|
| |
|
Excess of | |
|
Earnings | |
|
|
|
|
Shares | |
|
Amount | |
|
Par Value | |
|
(Deficit) | |
|
Total | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
|
(In thousands, except share amounts) | |
|
|
Balances, December 31, 2002
|
|
|
3,926,668 |
|
|
$ |
39 |
|
|
$ |
10,143 |
|
|
$ |
(9,173 |
) |
|
$ |
1,009 |
|
Net income (restated)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,927 |
|
|
|
2,927 |
|
Effect of consolidation of AirComp
|
|
|
|
|
|
|
|
|
|
|
955 |
|
|
|
|
|
|
|
955 |
|
Accrual of preferred dividends
|
|
|
|
|
|
|
|
|
|
|
(350 |
) |
|
|
|
|
|
|
(350 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2003, as restated
|
|
|
3,926,668 |
|
|
|
39 |
|
|
|
10,748 |
|
|
|
(6,246 |
) |
|
|
4,541 |
|
Net income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
888 |
|
|
|
888 |
|
Issuance of common stock:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Acquisitions
|
|
|
1,868,466 |
|
|
|
19 |
|
|
|
8,592 |
|
|
|
|
|
|
|
8,611 |
|
|
Private placement
|
|
|
6,081,301 |
|
|
|
61 |
|
|
|
15,600 |
|
|
|
|
|
|
|
15,661 |
|
|
Services
|
|
|
17,000 |
|
|
|
|
|
|
|
99 |
|
|
|
|
|
|
|
99 |
|
Conversion of preferred stock
|
|
|
1,718,090 |
|
|
|
17 |
|
|
|
4,278 |
|
|
|
|
|
|
|
4,295 |
|
Issuance of stock purchase warrants
|
|
|
|
|
|
|
|
|
|
|
1,138 |
|
|
|
|
|
|
|
1,138 |
|
Accrual of preferred dividends
|
|
|
|
|
|
|
|
|
|
|
(124 |
) |
|
|
|
|
|
|
(124 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2004
|
|
|
13,611,525 |
|
|
|
136 |
|
|
|
40,331 |
|
|
|
(5,358 |
) |
|
|
35,109 |
|
Net income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,175 |
|
|
|
7,175 |
|
Issuance of common stock:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Acquisitions
|
|
|
411,275 |
|
|
|
4 |
|
|
|
1,746 |
|
|
|
|
|
|
|
1,750 |
|
|
Secondary public offering
|
|
|
1,761,034 |
|
|
|
18 |
|
|
|
15,441 |
|
|
|
|
|
|
|
15,459 |
|
|
Stock options and warrants exercised
|
|
|
1,076,154 |
|
|
|
11 |
|
|
|
1,371 |
|
|
|
|
|
|
|
1,382 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balances, December 31, 2005
|
|
|
16,859,988 |
|
|
$ |
169 |
|
|
$ |
58,889 |
|
|
$ |
1,817 |
|
|
$ |
60,875 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of the Consolidated
Financial Statements.
F-8
ALLIS-CHALMERS ENERGY INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
|
|
|
|
(Restated) | |
|
|
(In thousands) | |
Cash Flows from Operating Activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
7,175 |
|
|
$ |
888 |
|
|
$ |
2,927 |
|
Adjustments to reconcile net income to net cash provided by
operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation
|
|
|
4,874 |
|
|
|
2,702 |
|
|
|
2,052 |
|
|
Amortization
|
|
|
1,787 |
|
|
|
876 |
|
|
|
884 |
|
|
Write-off of deferred financing fees due to refinancing
|
|
|
653 |
|
|
|
|
|
|
|
|
|
|
Issuance of stock options for services
|
|
|
|
|
|
|
14 |
|
|
|
|
|
|
Amortization of discount on debt
|
|
|
9 |
|
|
|
350 |
|
|
|
516 |
|
|
(Gain) on change in PBO liability
|
|
|
(352 |
) |
|
|
|
|
|
|
(125 |
) |
|
(Gain) on settlement of lawsuit
|
|
|
|
|
|
|
|
|
|
|
(1,034 |
) |
|
(Gain) on sale of interest in AirComp
|
|
|
|
|
|
|
|
|
|
|
(2,433 |
) |
|
Minority interest in income of subsidiaries
|
|
|
488 |
|
|
|
321 |
|
|
|
343 |
|
|
(Gain) loss on sale of property
|
|
|
(669 |
) |
|
|
|
|
|
|
82 |
|
Changes in working capital:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Increase) in accounts receivable
|
|
|
(10,437 |
) |
|
|
(2,292 |
) |
|
|
(4,414 |
) |
|
(Increase) in due from related party
|
|
|
|
|
|
|
(7 |
) |
|
|
|
|
|
(Increase) in other current assets
|
|
|
(2,143 |
) |
|
|
(612 |
) |
|
|
(1,260 |
) |
|
Decrease (increase) in other assets
|
|
|
(936 |
) |
|
|
(19 |
) |
|
|
1 |
|
|
Decrease in lease deposit
|
|
|
|
|
|
|
|
|
|
|
525 |
|
|
Increase in accounts payable
|
|
|
2,373 |
|
|
|
1,140 |
|
|
|
2,251 |
|
|
(Decrease) increase in accrued interest
|
|
|
324 |
|
|
|
299 |
|
|
|
(126 |
) |
|
(Decrease) increase in accrued expenses
|
|
|
(97 |
) |
|
|
(276 |
) |
|
|
397 |
|
|
(Decrease) increase in other long-term liabilities
|
|
|
86 |
|
|
|
(141 |
) |
|
|
|
|
|
Increase in accrued salaries,benefits and payroll taxes
|
|
|
443 |
|
|
|
19 |
|
|
|
1,293 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
3,578 |
|
|
|
3,262 |
|
|
|
1,879 |
|
Cash Flows from Investing Activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Acquisitions, net of cash acquired
|
|
|
(36,888 |
) |
|
|
(4,459 |
) |
|
|
|
|
Purchase of property and equipment
|
|
|
(17,767 |
) |
|
|
(4,603 |
) |
|
|
(5,354 |
) |
Proceeds from sale of property and equipment
|
|
|
1,579 |
|
|
|
|
|
|
|
843 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investing activities
|
|
|
(53,076 |
) |
|
|
(9,062 |
) |
|
|
(4,511 |
) |
Cash Flows from Financing Activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Proceeds from issuance of long-term debt
|
|
|
56,251 |
|
|
|
8,169 |
|
|
|
14,127 |
|
Payments on long-term debt
|
|
|
(28,202 |
) |
|
|
(13,259 |
) |
|
|
(10,826 |
) |
Payments on related party debt
|
|
|
(1,522 |
) |
|
|
(246 |
) |
|
|
(246 |
) |
Net borrowings on lines of credit
|
|
|
2,527 |
|
|
|
689 |
|
|
|
1,138 |
|
Proceeds from issuance of common stock
|
|
|
15,459 |
|
|
|
16,883 |
|
|
|
|
|
Proceeds from exercise of options and warrants
|
|
|
1,382 |
|
|
|
|
|
|
|
|
|
Debt issuance costs
|
|
|
(1,821 |
) |
|
|
(391 |
) |
|
|
(408 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
44,074 |
|
|
|
11,845 |
|
|
|
3,785 |
|
|
|
|
|
|
|
|
|
|
|
Net increase (decrease) in cash and cash equivalents
|
|
|
(5,424 |
) |
|
|
6,045 |
|
|
|
1,153 |
|
Cash and cash equivalents at beginning of year
|
|
|
7,344 |
|
|
|
1,299 |
|
|
|
146 |
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of year
|
|
$ |
1,920 |
|
|
$ |
7,344 |
|
|
$ |
1,299 |
|
|
|
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of the Consolidated
Financial Statements.
F-9
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 Nature of Business and Summary of
Significant Accounting Policies
Allis-Chalmers Energy Inc. (Allis-Chalmers or
We) was incorporated in Delaware in 1913. OilQuip
Rentals, Inc. (OilQuip), an oil and gas rental
company, was incorporated on February 4, 2000 to find and
acquire acquisition targets to operate as subsidiaries.
On February 6, 2001, OilQuip, through its subsidiary,
Mountain Compressed Air Inc. (Mountain Air), a Texas
corporation, acquired certain assets of Mountain Air Drilling
Service Co., Inc, whose business consisted of providing
equipment and trained personnel in the Four Corners area of the
southwestern United States. Mountain Air primarily provided
compressed air equipment and related products and services and
trained operators to companies in the business of drilling for
natural gas. On May 9, 2001, OilQuip merged into a
subsidiary of Allis-Chalmers Energy Inc. In the merger, all of
OilQuips outstanding common stock was converted into
2.0 million shares of Allis-Chalmers common stock.
For legal purposes, Allis-Chalmers acquired OilQuip, the parent
company of Mountain Air. However, for accounting purposes,
OilQuip was treated as the acquiring company in a reverse
acquisition of Allis-Chalmers.
On February 6, 2002, we acquired 81% of the outstanding
stock of Allis-Chalmers Tubular Services Inc.
(Tubular), formerly known as Jens Oilfield
Service, Inc., which supplies highly specialized equipment and
operations to install casing and production tubing required to
drill and complete oil and gas wells. On February 2, 2002,
we also purchased substantially all of the outstanding common
stock and preferred stock of Strata Directional Technology, Inc.
(Strata), which provides high-end directional and
horizontal drilling services for specific targeted reservoirs
that cannot be reached vertically.
In July 2003, through its subsidiary Mountain Air, we entered
into a limited liability company operating agreement with a
division of M-I L.L.C. (M-I), a joint venture
between Smith International and Schlumberger N.V. (Schlumberger
Limited), to form a Texas limited liability company named
AirComp LLC (AirComp). The assets contributed by
Mountain Air were recorded at Mountain Airs historical
cost of $6.3 million, and the assets contributed by M-I
were recorded at fair market value of $10.3 million. We
originally owned 55% and M-I originally owned 45% of AirComp. As
a result of our controlling interest and operating control, we
consolidated AirComp in our financial statements. AirComp is in
the compressed air drilling services segment.
On September 23, 2004, we acquired 100% of the outstanding
stock of Safco-Oil Field Products, Inc. (Safco) for
$1.0 million. Safco leases spiral drill pipe and provides
related oilfield services to the oil drilling industry.
On September 30, 2004, we acquired the remaining 19% of
Tubular in exchange for 1.3 million shares of our
common stock. The total value of the consideration paid to the
seller, Jens Mortensen, was $6.4 million which was equal to
the number of shares of common stock issued to Mr. Mortensen
multiplied by the last sale price ($4.95) of the common stock as
reported on the American Stock Exchange on the date of issuance.
On November 10, 2004, AirComp acquired substantially all
the assets of Diamond Air Drilling Services, Inc. and Marquis
Bit Co., L.L.C. collectively (Diamond Air) for
$4.6 million in cash and
F-10
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
the assumption of approximately $450,000 of accrued liabilities.
We contributed $2.5 million and M-I L.L.C. contributed
$2.1 million to AirComp LLC in order to fund the purchase.
Diamond Air provides air drilling technology and products to the
oil and gas industry in West Texas, New Mexico and Oklahoma.
Diamond Air is a leading provider of air hammers and hammer bit
products.
On December 10, 2004, we acquired Downhole Injection
Services, LLC (Downhole) for approximately
$1.1 million in cash, 568,466 shares of common stock and
payment or assumption of $950,000 of debt. Downhole is
headquartered in Midland, Texas, and provides chemical
treatments to wells by inserting small diameter, stainless steel
coiled tubing into producing oil and gas wells.
On April 1, 2005, we acquired 100% of the outstanding stock
of Delta Rental Service, Inc. (Delta) for
$4.6 million in cash, 223,114 shares of our common stock
and two promissory notes totaling $350,000. Delta, located in
Lafayette, Louisiana, is a rental tool company providing
specialty rental items to the oil and gas industry such as
spiral heavy weight drill pipe, test plugs used to test blow-out
preventors, well head retrieval tools, spacer spools and
assorted handling tools.
On May 1, 2005, we acquired 100% of the outstanding capital
stock of Capcoil Tubing Services, Inc. (Capcoil) for
$2.7 million in cash, 168,161 shares of our common stock
and the payment or assumption of approximately $1.3 million
of debt. Capcoil, located in Kilgore, Texas, is engaged in
downhole well servicing by providing coil tubing services to
enhance production from existing wells.
On July 11, 2005, we acquired the compressed air drilling
assets of W.T. Enterprises, Inc. (W.T.), based in
South Texas, for $6.0 million in cash. The equipment
includes compressors, boosters, mist pumps and vehicles.
On July 11, 2005, we acquired from M-I its 45% interest in
AirComp and subordinated note in the principal amount of
$4.8 million issued by AirComp, for which we paid M-I
$7.1 million in cash and issued to M-I a $4.0 million
subordinated note bearing interest at 5% per annum. As a result,
we now own 100% of AirComp.
Effective August 1, 2005, we acquired 100% of the
outstanding capital stock of Target Energy Inc.
(Target) for $1.3 million in cash and
forgiveness of a lease receivable of approximately
$0.6 million. The results of Target are included in our
directional and horizontal drilling segment as their Measure
While Drilling equipment is utilized in that segment.
On September 1, 2005, we acquired the casing and tubing
service assets of Patterson Services, Inc. for approximately
$15.6 million. These assets are located in Corpus Christi,
Texas; Kilgore, Texas; Lafayette, Louisiana and Houma, Louisiana.
|
|
|
Vulnerabilities and
Concentrations |
We provide oilfield services in several regions, including the
states of Texas, Utah, Louisiana, Colorado, Oklahoma, and New
Mexico, the Gulf of Mexico and southern portions of Mexico. The
nature of our operations and the many regions in which we
operate subject us to changing economic, regulatory and
political conditions. We are vulnerable to near-term and
long-term changes in the demand for and prices of oil and
natural gas and the related demand for oilfield service
operations.
F-11
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
The preparation of financial statements in conformity with
accounting principles generally accepted in the United States of
America requires management to make estimates and assumptions
that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of
the financial statements, and the reported amounts of revenues
and expenses during the reporting period. Future events and
their effects cannot be perceived with certainty. Accordingly,
our accounting estimates require the exercise of judgment. While
management believes that the estimates and assumptions used in
the preparation of the consolidated financial statements are
appropriate, actual results could differ from those estimates.
Estimates are used for, but are not limited to, determining the
following: allowance for doubtful accounts, recoverability of
long-lived assets and intangibles, useful lives used in
depreciation and amortization, income taxes and valuation
allowances. The accounting estimates used in the preparation of
the consolidated financial statements may change as new events
occur, as more experience is acquired, as additional information
is obtained and as our operating environment changes.
|
|
|
Principles of
Consolidation |
The consolidated financial statements include the accounts of
Allis-Chalmers and its subsidiaries. Our subsidiaries at
December 31, 2005 are Oil Quip, Mountain Air, Tubular,
Strata, AirComp, Safco, Downhole, Delta, Capcoil and Target. All
significant inter-company transactions have been eliminated.
We provide rental equipment and drilling services to our
customers at per day and per job contractual rates and recognize
the drilling related revenue as the work progresses and when
collectibility is reasonably assured. Proceeds from customers
for the cost of oilfield rental equipment that is involuntarily
damaged or lost in-hole are reflected as revenues. We recognized
revenue from damaged or lost in-hole of $970,000, $41,000 and
$252,000 for the years ended December 31, 2005, 2004 and
2003, respectively. The Securities and Exchange
Commissions (SEC) Staff Accounting Bulletin
(SAB) No. 104, Revenue Recognition In Financial
Statements (SAB No. 104), provides
guidance on the SEC staffs views on the application of
generally accepted accounting principles to selected revenue
recognition issues. Our revenue recognition policy is in
accordance with generally accepted accounting principles and
SAB No. 104.
|
|
|
Allowance for Doubtful
Accounts |
Accounts receivable are customer obligations due under normal
trade terms. We sell our services to oil and natural gas
exploration and production companies. We perform continuing
credit evaluations of its customers financial condition
and although we generally does not require collateral, letters
of credit may be required from customers in certain
circumstances.
We record an allowance for doubtful accounts based on
specifically identified amounts that are determined
uncollectible. We have a limited number of customers with
individually large amounts due at any given date. Any
unanticipated change in any one of these customers credit
worthiness or other matters affecting the collectibility of
amounts due from such customers could have a material effect on
the results of operations in the period in which such changes or
events occur. After all attempts to
F-12
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
collect a receivable have failed, the receivable is written off
against the allowance. As of December 31, 2005 and 2004, we
had recorded an allowance for doubtful accounts of $383,000 and
$265,000 respectively. Bad debt expense was $219,000, $104,000
and $136,000 for the years ended December 31, 2005, 2004
and 2003, respectively.
We consider all highly liquid investments with an original
maturity of three months or less at the time of purchase to be
cash equivalents.
Inventories are stated at the lower of cost or market. Cost is
determined using the first in, first out
(FIFO) method or the average cost method, which
approximates FIFO, and includes the cost of materials, labor and
manufacturing overhead.
Property and equipment is recorded at cost less accumulated
depreciation. Certain equipment held under capital leases are
classified as equipment and the related obligations are recorded
as liabilities.
Maintenance and repairs, which do not improve or extend the life
of the related assets, are charged to operations when incurred.
Refurbishments and renewals are capitalized when the value of
the equipment is enhanced for an extended period. When property
and equipment are sold or otherwise disposed of, the asset
account and related accumulated depreciation account are
relieved, and any gain or loss is included in operations.
The cost of property and equipment currently in service is
depreciated over the estimated useful lives of the related
assets, which range from three to twenty years. Depreciation is
computed on the straight-line method for financial reporting
purposes. Capital leases are amortized using the straight-line
method over the estimated useful lives of the assets and lease
amortization is included in depreciation expense. Depreciation
expense charged to operations was $4.9 million,
$2.7 million and $2.1 million for the years ended
December 31, 2005, 2004 and 2003, respectively.
|
|
|
Goodwill, Intangible
Assets and Amortization |
Goodwill, including goodwill associated with equity method
investments, and other intangible assets with infinite lives are
not amortized, but tested for impairment annually or more
frequently if circumstances indicate that impairment may exist.
Intangible assets with finite useful lives are amortized either
on a straight-line basis over the assets estimated useful
life or on a basis that reflects the pattern in which the
economic benefits of the intangible assets are realized.
We perform impairment tests on the carrying value of our
goodwill on an annual basis as of December 31st for each of
our reportable segments. As of December 31, 2005 and 2004,
no evidence of impairment exists.
F-13
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
|
Impairment of Long-Lived
Assets |
Long-lived assets, which include property, plant and equipment
and other intangible assets, and certain other assets are
reviewed for impairment whenever events or changes in
circumstances indicate that the carrying amount may not be
recoverable. An impairment loss is recorded in the period in
which it is determined that the carrying amount is not
recoverable. The determination of recoverability is made based
upon the estimated undiscounted future net cash flows, excluding
interest expense. The impairment loss is determined by comparing
the fair value, as determined by a discounted cash flow
analysis, with the carrying value of the related assets.
Financial instruments consist of cash and cash equivalents,
accounts receivable and payable, and debt. The carrying value of
cash and cash equivalents and accounts receivable and payable
approximate fair value due to their short-term nature. We
believe the fair values and the carrying value of our debt would
not be materially different due to the instruments
interest rates approximating market rates for similar borrowings
at December 31, 2005 and 2004.
|
|
|
Concentration of Credit
and Customer Risk |
Financial instruments that potentially subject us to
concentrations of credit risk consist principally of cash and
cash equivalents and trade accounts receivable. We transact our
business with several financial institutions. However, the
amount on deposit in two financial institutions exceeded the
$100,000 federally insured limit at December 31, 2005 by a total
of $2.0 million. Management believes that the financial
institutions are financially sound and the risk of loss is
minimal.
We sell our services to major and independent domestic and
international oil and gas companies. We perform ongoing credit
valuations of our customers and provide allowances for probable
credit losses where appropriate. In 2005, none of our customers
accounted for more than 10% of our consolidated revenues. In the
year ended December 31, 2004, Matyep in Mexico represented
10.8%, and Burlington Resources represented 10.1% of our
consolidated revenues, respectively. In the year ended December
31, 2003, Matyep, Burlington Resources, Inc., and El Paso Energy
Corporation represented 10.2%, 11.1% and 14.1%, respectively, of
our consolidated revenues. Revenues from Matyep represented
94.5%, 98.0% and 100% of our international revenues in 2005,
2004 and 2003, respectively.
The costs related to the issuance of debt are capitalized and
amortized to interest expense using the straight-line method,
which approximates the interest method, over the maturity
periods of the related debt.
We use the liability method for determining our income taxes,
under which current and deferred tax liabilities and assets are
recorded in accordance with enacted tax laws and rates. Under
this method, the amounts of deferred tax liabilities and assets
at the end of each period are determined using the tax rate
F-14
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
expected to be in effect when taxes are actually paid or
recovered. Future tax benefits are recognized to the extent that
realization of such benefits is more likely than not.
Deferred income taxes are provided for the estimated income tax
effect of temporary differences between financial and tax bases
in assets and liabilities. Deferred tax assets are also provided
for certain tax credit carryforwards. A valuation allowance to
reduce deferred tax assets is established when it is more likely
than not that some portion or all of the deferred tax assets
will not be realized.
We account for our stock-based compensation using Accounting
Principle Board Opinion No. 25 (APB
No. 25). Under APB No. 25, compensation expense
is recognized for stock options with an exercise price that is
less than the market price on the grant date of the option. For
stock options with exercise prices at or above the market value
of the stock on the grant date, we adopted the disclosure-only
provisions of Statement of Financial Accounting Standards
(SFAS) No. 123, Accounting For Stock-Based
Compensation (SFAS 123). We also adopted
the disclosure-only provisions of SFAS No. 123 for the
stock options granted to our employees and directors.
Accordingly, no compensation cost has been recognized under APB
No. 25. Had compensation expense for the options granted
been recorded based on the fair value at the grant date for the
options, consistent with the provisions of SFAS 123, our
net income/(loss) and net income/(loss) per share for the years
ended December 31, 2005, 2004, and 2003 would have been
decreased to the pro forma amounts indicated below (in
thousands, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For0the Years2Ended December031, | |
|
|
|
|
| |
|
|
|
|
| |
|
|
|
|
|
|
(Restated) | |
|
(Restated) | |
Net income attributed to common stockholders as reported:
|
|
|
|
$ |
7,175 |
|
|
$ |
764 |
|
|
$ |
2,271 |
|
Less total stock based employee compensation expense determined
under fair value based method for all awards net of tax related
effects
|
|
|
|
|
(4,284 |
) |
|
|
(1,072 |
) |
|
|
(2,314 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Pro-forma net income (loss) attributed to common
stockholders
|
|
|
|
$ |
2,891 |
|
|
$ |
(308 |
) |
|
$ |
(43 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Net income/(loss) per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
As reported |
|
$ |
0.48 |
|
|
$ |
0.10 |
|
|
$ |
0.58 |
|
|
|
Pro forma |
|
$ |
0.19 |
|
|
$ |
(0.04 |
) |
|
$ |
(0.01 |
) |
|
Diluted
|
|
As reported |
|
$ |
0.44 |
|
|
$ |
0.09 |
|
|
$ |
0.50 |
|
|
|
Pro forma |
|
$ |
0.18 |
|
|
$ |
(0.04 |
) |
|
$ |
(0.01 |
) |
F-15
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Options were granted in 2005, 2004 and 2003. See Note 12
for further disclosures regarding stock options. The following
assumptions were applied in determining the pro forma
compensation costs:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Expected dividend yield
|
|
|
|
|
|
|
|
|
|
|
|
|
Expected price volatility
|
|
|
84.28 |
% |
|
|
89.76 |
% |
|
|
265.08 |
% |
Risk-free interest rate
|
|
|
5.6 |
% |
|
|
7.00 |
% |
|
|
6.25 |
% |
Expected life of options
|
|
|
7 years |
|
|
|
7 years |
|
|
|
7 years |
|
Weighted average fair value of options granted at market value
|
|
$ |
5.02 |
|
|
$ |
3.19 |
|
|
$ |
2.78 |
|
|
|
|
Segments of an Enterprise
and Related Information |
We disclose the results of our segments in accordance with
SFAS No. 131, Disclosures About Segments Of An
Enterprise And Related
Information(SFAS No. 131). We
designate the internal organization that is used by management
for allocating resources and assessing performance as the source
of our reportable segments. SFAS No. 131 also requires
disclosures about products and services, geographic areas and
major customers Please see Note 18 for further disclosure
of segment information in accordance with SFAS No. 131.
|
|
|
Pension and Other Post
Retirement Benefits |
SFAS No. 132, Employers Disclosures About
Pension And Other Post Retirement Benefits
(SFAS No. 132), requires certain
disclosures about employers pension and other post
retirement benefit plans and specifies the accounting and
measurement or recognition of those plans. SFAS No. 132
requires disclosure of information on changes in the benefit
obligations and fair values of the plan assets that facilitates
financial analysis. Please see Note 3 for further
disclosure in accordance with SFAS No. 132.
We compute income per common share in accordance with the
provisions of SFAS No. 128, Earnings Per Share
(SFAS No. 128). SFAS No. 128
requires companies with complex capital structures to present
basic and diluted earnings per share. Basic earnings per share
are computed on the basis of the weighted average number of
shares of common stock outstanding during the period. For
periods through April 12, 2004, preferred dividends are
deducted from net income and have been considered in the
calculation of income available to common stockholders in
computing basic earnings per share. Diluted earnings per share
is similar to basic earnings per share, but presents the
dilutive effect on a per share basis of potential common shares
(e.g., convertible preferred stock, stock options, etc.) as if
they had been converted. Potential dilutive common shares that
have an anti-dilutive effect (e.g., those that increase income
per share) are excluded from diluted earnings per share.
F-16
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
The components of basic and diluted earnings per share are as
follows (in thousands, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
|
|
(Restated) | |
|
(Restated) | |
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income available for common stockholders
|
|
$ |
7,175 |
|
|
$ |
764 |
|
|
$ |
2,271 |
|
Plus income impact of assumed conversions:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred stock dividends/interest
|
|
|
|
|
|
|
124 |
|
|
|
656 |
|
|
|
|
|
|
|
|
|
|
|
Net income applicable to common stockholders plus assumed
conversions
|
|
$ |
7,175 |
|
|
$ |
888 |
|
|
$ |
2,927 |
|
|
|
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
Denominator for basic earnings per share weighted
average shares outstanding
|
|
|
14,832 |
|
|
|
7,930 |
|
|
|
3,927 |
|
Effect of potentially dilutive common shares:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Convertible preferred stock and employee and director stock
options
|
|
|
1,406 |
|
|
|
1,580 |
|
|
|
1,923 |
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares outstanding and assumed conversions
|
|
|
16,238 |
|
|
|
9,510 |
|
|
|
5,850 |
|
|
|
|
|
|
|
|
|
|
|
Basic earnings per share
|
|
$ |
0.48 |
|
|
$ |
0.10 |
|
|
$ |
0.58 |
|
|
|
|
|
|
|
|
|
|
|
Diluted earnings per share
|
|
$ |
0.44 |
|
|
$ |
0.09 |
|
|
$ |
0.50 |
|
|
|
|
|
|
|
|
|
|
|
Certain prior period balances have been reclassified to conform
to current year presentation.
|
|
|
New Accounting
Pronouncements |
In May 2005, the FASB issued SFAS No. 154,
Accounting Changes and Error Corrections.
SFAS No. 154 requires retroactive application of a
voluntary change in accounting principle to prior period
financial statements unless it is impracticable.
SFAS No. 154 also requires that a change in the method
of depreciation, amortization or depletion for long-lived,
non-financial assets be accounted for as a change in accounting
estimate that is affected by a change in accounting principle.
SFAS No. 154 replaces APB Opinion No. 20,
Accounting Changes and SFAS No. 3,
Reporting Accounting Changes in Interim Financial
Statements. SFAS No. 154 is effective for fiscal
years beginning after December 15, 2005. We will adopt the
provisions of SFAS No. 154 as of January 1, 2006
and do not expect that its adoption will have a material impact
on our results of operations or financial condition.
In December 2004, the FASB issued SFAS No. 123R,
Share-Based Payment. SFAS No. 123R revises
SFAS No. 123, Accounting for Stock-Based
Compensation, and focuses on accounting for share-based
payments for services by employer to employee. The statement
requires all share-based payments to employees, including grants
of employee stock options, to be recognized in the financial
statements based on their fair values. We will adopt
SFAS No. 123R as of January 1, 2006 and will use
the
F-17
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
modified prospective transition method, utilizing the
Black-Scholes option pricing model for the calculation of the
fair value of our employee stock options. Under the modified
prospective method, stock option awards that are granted,
modified or settled after January 1, 2006 will be measured
and accounted for in accordance with SFAS No. 123R.
Compensation cost for awards granted prior to, but not vested,
as of January 1, 2006 would be based on the grant date
attributes originally used to value those awards for pro forma
purposes under SFAS No. 123. We believe that the
adoption of this standard will result in an expense of
approximately $3.2 million, or a reduction in diluted
earnings per share of approximately $0.18 per share. This
estimate assumes no additional grants of stock options beyond
those outstanding as of December 31, 2005. This estimate is
based on many assumptions including the level of stock option
grants expected in 2006, our stock price, and significant
assumptions in the option valuation model including volatility
and the expected life of options. Actual expenses could differ
from the estimate.
In November 2004, the FASB issued SFAS No. 151,
Inventory Costs an Amendment of ARB
No. 43, Chapter 4, which amends the guidance in ARB
No. 43 to clarify the accounting for abnormal amounts of idle
facility expense, freight, handling costs and wasted material.
SFAS No. 151 requires that these items be recognized
as current period charges. In addition, SFAS No. 151
requires the allocation of fixed production overheads to
inventory based on the normal capacity of the production
facilities. We are required to adopt provisions of
SFAS 151, on a prospective basis, as of January 1,
2006. We do not believe the adoption of SFAS 151 will have
a material impact on our future results of operations.
Note 2 Restatement
We understated diluted earnings per share due to an incorrect
calculation of our weighted shares outstanding for the third
quarter of 2003, for each of the first three quarters of 2004,
for the years ended December 31, 2003 and 2004 and for the
quarter ended March 31, 2005. In addition, we understated
basic earnings per share due to an incorrect calculation of our
weighted average basic shares outstanding for the quarter ended
September 30, 2004. Consequently, we have restated our
financial statements for each of those periods. The incorrect
calculation resulted from a mathematical error and an improper
application of SFAS No. 128. The effect of the restatement
is to reduce weighted average basic and diluted shares
outstanding for the three and nine months ended
September 30, 2004. Consequently, weighted average basic
and diluted earnings per share for the three and nine months
ended September 30, 2004 were increased.
F-18
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
A restated earnings per share calculation for all affected
periods reflecting the above adjustments to our results as
previously restated (see following section), is presented below
(amounts in thousands, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended March 31, 2005 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
|
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Income per common share diluted
|
|
$ |
0.09 |
|
|
$ |
0.02 |
|
|
$ |
0.11 |
|
Weighted average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
17,789 |
|
|
|
(3,094 |
) |
|
|
14,695 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2004 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
|
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Income per common share diluted
|
|
$ |
0.07 |
|
|
$ |
0.02 |
|
|
$ |
0.09 |
|
Weighted average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
11,959 |
|
|
|
(2,449 |
) |
|
|
9,510 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30, | |
|
|
2004 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
|
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Income per common share basic
|
|
$ |
0.04 |
|
|
$ |
0.02 |
|
|
$ |
0.06 |
|
Income per common share diluted
|
|
$ |
0.04 |
|
|
$ |
0.01 |
|
|
$ |
0.05 |
|
Weighted average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
11,599 |
|
|
|
(3,301 |
) |
|
|
8,298 |
|
|
Diluted
|
|
|
14,407 |
|
|
|
(4,579 |
) |
|
|
9,828 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended June 30, 2004 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
|
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Income per common share diluted
|
|
$ |
0.04 |
|
|
$ |
0.01 |
|
|
$ |
0.05 |
|
Weighted average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
10,237 |
|
|
|
(2,618 |
) |
|
|
7,619 |
|
F-19
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended March 31, 2004 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
|
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Income per common share diluted
|
|
$ |
0.05 |
|
|
$ |
0.03 |
|
|
$ |
0.08 |
|
Weighted average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
5,762 |
|
|
|
478 |
|
|
|
6,240 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2003 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
|
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Income per common share diluted
|
|
$ |
0.39 |
|
|
$ |
0.11 |
|
|
$ |
0.50 |
|
Weighted average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
5,761 |
|
|
|
89 |
|
|
|
5,850 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended September 30, | |
|
|
2003 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
|
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Income per common share diluted
|
|
$ |
0.60 |
|
|
$ |
(0.01 |
) |
|
$ |
0.59 |
|
Weighted average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
5,761 |
|
|
|
208 |
|
|
|
5,969 |
|
In connection with the formation of AirComp LLC in 2003, we,
along with M-I L.L.C. contributed assets to AirComp in exchange
for a 55% interest and 45% interest, respectively, in AirComp.
We originally accounted for the formation of AirComp as a joint
venture. However in February 2005, we determined that the
transaction should have been accounted for using purchase
accounting pursuant to SFAS No. 141, Business
Combinations and recorded the sale of an interest in a
subsidiary, in accordance with SEC Staff Accounting
Bulletin No. 51, Accounting for Sales of Stock by a
Subsidiary. Consequently, we restated our financial
statements for the quarter ended September 30, 2003, for
the year ended December 31, 2003 and for the three quarters
ended September 30, 2004, to reflect the following
adjustments:
|
|
|
Increase in Book Value of
Fixed Assets. |
Under joint venture accounting, we originally recorded the value
of the assets contributed by M-I to AirComp at M-Is
historical cost of $6.9 million. Under purchase accounting,
we increased the recorded value of the assets contributed by M-I
by approximately $3.3 million to $10.3 million to
reflect their fair market value as determined by a third party
appraisal. In addition, under joint venture accounting, we
established negative goodwill which reduced fixed assets in the
amount of $1.6 million. The negative goodwill was amortized
by us over the lives of the related fixed assets. Under purchase
accounting, we increased fixed assets by $1.6 million to
reverse the negative goodwill previously recorded and reversed
F-20
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
amortization expenses recorded in 2004. Therefore, the cost of
fixed assets was increased by a total of $4.9 million at
the time of acquisition. As a result of the increase in fixed
assets and the reversal of amortization of negative goodwill,
depreciation expense increased by $98,000 for the year ended
December 31, 2003.
|
|
|
Increase in Minority Interest
and Capital in Excess of Par Value. |
Under purchase accounting, minority interest was increased by
$1.5 million, which was partially offset by minority
interest expense of $44,000 for the year ended December 31,
2003. Under purchase accounting, the capital in excess of par
was increased by $955,000.
A restated consolidated balance sheet, reflecting the above
adjustments follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
At December 31, 2003 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
Restatement | |
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
1,299 |
|
|
$ |
|
|
|
$ |
1,299 |
|
Trade receivables, net
|
|
|
8,823 |
|
|
|
|
|
|
|
8,823 |
|
Lease receivable, current
|
|
|
180 |
|
|
|
|
|
|
|
180 |
|
Prepaid expenses and other
|
|
|
887 |
|
|
|
|
|
|
|
887 |
|
|
|
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
11,189 |
|
|
|
|
|
|
|
11,189 |
|
Property and equipment, net
|
|
|
26,339 |
|
|
|
4,789 |
|
|
|
31,128 |
|
Goodwill
|
|
|
7,661 |
|
|
|
|
|
|
|
7,661 |
|
Other intangible assets, net
|
|
|
2,290 |
|
|
|
|
|
|
|
2,290 |
|
Debt issuance costs, net
|
|
|
567 |
|
|
|
|
|
|
|
567 |
|
Lease receivable, less current portion
|
|
|
787 |
|
|
|
|
|
|
|
787 |
|
Other
|
|
|
40 |
|
|
|
|
|
|
|
40 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets
|
|
$ |
48,873 |
|
|
$ |
4,789 |
|
|
$ |
53,662 |
|
|
|
|
|
|
|
|
|
|
|
Liabilities and Stockholders Equity
|
|
|
|
|
|
|
|
|
|
|
|
|
Current maturities of long-term debt
|
|
$ |
3,992 |
|
|
$ |
|
|
|
$ |
3,992 |
|
Trade accounts payable
|
|
|
3,133 |
|
|
|
|
|
|
|
3,133 |
|
Accrued salaries, benefits and payroll taxes
|
|
|
591 |
|
|
|
|
|
|
|
591 |
|
Accrued interest
|
|
|
152 |
|
|
|
|
|
|
|
152 |
|
Accrued expenses
|
|
|
1,761 |
|
|
|
|
|
|
|
1,761 |
|
Accounts payable, related parties
|
|
|
787 |
|
|
|
|
|
|
|
787 |
|
|
|
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
10,416 |
|
|
|
|
|
|
|
10,416 |
|
Accrued postretirement benefit obligations
|
|
|
545 |
|
|
|
|
|
|
|
545 |
|
Long-term debt, net of current maturities
|
|
|
28,241 |
|
|
|
|
|
|
|
28,241 |
|
Other long-term liabilities
|
|
|
270 |
|
|
|
|
|
|
|
270 |
|
Redeemable warrants
|
|
|
1,500 |
|
|
|
|
|
|
|
1,500 |
|
Redeemable convertible preferred stock and dividends
|
|
|
4,171 |
|
|
|
|
|
|
|
4,171 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities
|
|
|
45,143 |
|
|
|
|
|
|
|
45,143 |
|
Commitments and contingencies Minority interests
|
|
|
2,523 |
|
|
|
1,455 |
|
|
|
3,978 |
|
F-21
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
At December 31, 2003 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
Restatement | |
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Stockholders Equity
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock
|
|
|
39 |
|
|
|
|
|
|
|
39 |
|
Capital in excess of par value
|
|
|
9,793 |
|
|
|
955 |
|
|
|
10,748 |
|
Accumulated (deficit)
|
|
|
(8,625 |
) |
|
|
2,379 |
|
|
|
(6,246 |
) |
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders Equity
|
|
|
1,207 |
|
|
|
3,334 |
|
|
|
4,541 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities and Stockholders Equity
|
|
$ |
48,873 |
|
|
$ |
4,789 |
|
|
$ |
53,662 |
|
|
|
|
|
|
|
|
|
|
|
Under joint venture accounting, no gain or loss was recognized
in connection with the formation of AirComp. Under purchase
accounting, we recorded a $2.4 million non-operating gain
in the third quarter of 2003.
As a result of the increase in fixed assets, depreciation
expense was increased for the year ended December 31, 2003
by $98,000 and minority interest expense decreased by $44,000,
resulting in a reduction in net income attributable to common
stockholders of $54,000. However, as a result of recording the
non-operating gain, net income attributed to common stockholders
increased by $2.4 million for the year ended December 31,
2003.
F-22
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
A restated consolidated income statement reflecting the above
adjustments follows (in thousands, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2003 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
Restatement | |
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Revenue
|
|
$ |
32,724 |
|
|
$ |
|
|
|
$ |
32,724 |
|
Cost of revenues
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Direct costs
|
|
|
21,977 |
|
|
|
|
|
|
|
21,977 |
|
|
Depreciation
|
|
|
1,954 |
|
|
|
98 |
|
|
|
2,052 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross margin
|
|
|
8,793 |
|
|
|
(98 |
) |
|
|
8,695 |
|
General and administrative expense
|
|
|
5,285 |
|
|
|
|
|
|
|
5,285 |
|
Amortization
|
|
|
884 |
|
|
|
|
|
|
|
884 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
2,624 |
|
|
|
(98 |
) |
|
|
2,526 |
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest, net
|
|
|
(2,464 |
) |
|
|
|
|
|
|
(2,464 |
) |
|
Settlement on lawsuit
|
|
|
1,034 |
|
|
|
|
|
|
|
1,034 |
|
|
Gain on sale of stock in a subsidiary
|
|
|
|
|
|
|
2,433 |
|
|
|
2,433 |
|
|
Other
|
|
|
111 |
|
|
|
|
|
|
|
111 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense)
|
|
|
(1,319 |
) |
|
|
2,433 |
|
|
|
1,114 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income before minority interest and income taxes
|
|
|
1,305 |
|
|
|
2,335 |
|
|
|
3,640 |
|
Minority interest in income of subsidiaries
|
|
|
(387 |
) |
|
|
44 |
|
|
|
(343 |
) |
Provision for foreign income tax
|
|
|
(370 |
) |
|
|
|
|
|
|
(370 |
) |
|
|
Net income
|
|
|
548 |
|
|
|
2,379 |
|
|
|
2,927 |
|
Preferred stock dividend
|
|
|
(656 |
) |
|
|
|
|
|
|
(656 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributed to common stockholders
|
|
$ |
(108 |
) |
|
$ |
2,379 |
|
|
$ |
2,271 |
|
|
|
|
|
|
|
|
|
|
|
Net income per common share basic
|
|
$ |
(0.03 |
) |
|
|
|
|
|
$ |
0.58 |
|
|
|
|
|
|
|
|
|
|
|
Net income per common share diluted
|
|
$ |
(0.03 |
) |
|
|
|
|
|
$ |
0.39 |
|
|
|
|
|
|
|
|
|
|
|
Weighted average number of common shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
3,927 |
|
|
|
|
|
|
|
3,927 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
5,761 |
|
|
|
|
|
|
|
5,761 |
|
|
|
|
|
|
|
|
|
|
|
F-23
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
A restated consolidated statement of cash flows reflecting the
adjustments follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2003 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
Restatement | |
|
As | |
|
|
Reported | |
|
Adjustments | |
|
Restated | |
|
|
| |
|
| |
|
| |
Cash Flows From Operating Activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
548 |
|
|
$ |
2,379 |
|
|
$ |
2,927 |
|
Adjustments to reconcile net income to net cash provided by
operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and amortization expense
|
|
|
2,838 |
|
|
|
98 |
|
|
|
2,936 |
|
|
Amortization of discount on debt
|
|
|
516 |
|
|
|
|
|
|
|
516 |
|
|
(Gain) on change PBO liability
|
|
|
(125 |
) |
|
|
|
|
|
|
(125 |
) |
|
(Gain) on settlement of lawsuit
|
|
|
(1,034 |
) |
|
|
|
|
|
|
(1,034 |
) |
|
(Gain) on sale of interest in AirComp
|
|
|
|
|
|
|
(2,433 |
) |
|
|
(2,433 |
) |
|
Minority interest in income of subsidiaries
|
|
|
387 |
|
|
|
(44 |
) |
|
|
343 |
|
|
Loss on sale of property
|
|
|
82 |
|
|
|
|
|
|
|
82 |
|
|
Changes in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Increase) in accounts receivable
|
|
|
(4,414 |
) |
|
|
|
|
|
|
(4,414 |
) |
|
|
(Increase) in other current assets
|
|
|
(1,260 |
) |
|
|
|
|
|
|
(1,260 |
) |
|
|
Decrease in other assets
|
|
|
1 |
|
|
|
|
|
|
|
1 |
|
|
|
Decrease in lease deposit
|
|
|
525 |
|
|
|
|
|
|
|
525 |
|
|
|
Increase in accounts payable
|
|
|
2,251 |
|
|
|
|
|
|
|
2,251 |
|
|
|
(Decrease) in accrued interest
|
|
|
(126 |
) |
|
|
|
|
|
|
(126 |
) |
|
|
Increase in accrued expenses
|
|
|
397 |
|
|
|
|
|
|
|
397 |
|
|
|
Increase in accrued employee benefits and payroll taxes
|
|
|
1,293 |
|
|
|
|
|
|
|
1,293 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
1,879 |
|
|
|
|
|
|
|
1,879 |
|
Cash Flows From Investing Activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchase of equipment
|
|
|
(5,354 |
) |
|
|
|
|
|
|
(5,354 |
) |
Proceeds from sale of equipment
|
|
|
843 |
|
|
|
|
|
|
|
843 |
|
|
|
|
Net cash used by investing activities
|
|
|
(4,511 |
) |
|
|
|
|
|
|
(4,511 |
) |
F-24
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2003 | |
|
|
| |
|
|
As | |
|
|
|
|
Previously | |
|
Restatement |
|
As | |
|
|
Reported | |
|
Adjustments |
|
Restated | |
|
|
| |
|
|
|
| |
Cash Flows From Financing Activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Proceeds from issuance of long-term debt
|
|
|
14,127 |
|
|
|
|
|
|
|
14,127 |
|
Repayments of long-term debt
|
|
|
(10,826 |
) |
|
|
|
|
|
|
(10,826 |
) |
Repayments on related party debt
|
|
|
(246 |
) |
|
|
|
|
|
|
(246 |
) |
Borrowing on lines of credit
|
|
|
30,537 |
|
|
|
|
|
|
|
30,537 |
|
Repayments on lines of credit
|
|
|
(29,399 |
) |
|
|
|
|
|
|
(29,399 |
) |
Debt issuance costs
|
|
|
(408 |
) |
|
|
|
|
|
|
(408 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
3,785 |
|
|
|
|
|
|
|
3,785 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net decrease in cash and cash equivalents
|
|
|
1,153 |
|
|
|
|
|
|
|
1,153 |
|
Cash and cash equivalents at beginning of the year
|
|
|
146 |
|
|
|
|
|
|
|
146 |
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of the period
|
|
$ |
1,299 |
|
|
$ |
|
|
|
$ |
1,299 |
|
|
|
|
|
|
|
|
|
|
|
Supplemental information:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest paid
|
|
$ |
2,341 |
|
|
$ |
|
|
|
$ |
2,341 |
|
In addition, the 2004 financial statements have been restated
from the previously filed interim financial statements included
in Form 10-Q for the first, second and third quarters of
2004. The effect of the restatement on the individual quarterly
financial statements is as follows (in thousands, except per
share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months | |
|
Three Months | |
|
Three Months | |
|
|
Ended | |
|
Ended | |
|
Ended | |
|
|
March 31, | |
|
June 30, | |
|
September 30, | |
|
|
2004 | |
|
2004 | |
|
2004 | |
|
|
| |
|
| |
|
| |
Net income (loss) attributed to common stockholders
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Previously reported
|
|
$ |
501 |
|
|
$ |
434 |
|
|
$ |
576 |
|
|
Adjustment depreciation expense
|
|
|
(139 |
) |
|
|
(79 |
) |
|
|
(79 |
) |
|
Adjustment minority interest expense
|
|
|
22 |
|
|
|
22 |
|
|
|
22 |
|
|
|
|
|
|
|
|
|
|
|
|
Restated
|
|
$ |
384 |
|
|
$ |
377 |
|
|
$ |
519 |
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) per share, basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Previously reported
|
|
$ |
0.13 |
|
|
$ |
0.07 |
|
|
$ |
0.05 |
|
|
Total adjustments
|
|
|
(0.03 |
) |
|
|
(0.01 |
) |
|
|
(0.01 |
) |
|
|
|
|
|
|
|
|
|
|
|
Restated
|
|
$ |
0.10 |
|
|
$ |
0.06 |
|
|
$ |
0.04 |
|
|
|
|
|
|
|
|
|
|
|
In addition, the accompanying 2003 financial statements have
been restated from the previously filed interim financial
statements included in
Form 10-Q for the
first, second and third quarters of 2003. An adjustment was
recorded in the fourth quarter of 2003 to reflect a change in
estimate of the recoverability of foreign taxes paid in 2002 and
2003. The effect of the significant fourth quarter
F-25
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
adjustment on the individual quarterly financial statements is
as follows (in thousands, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months | |
|
Three Months | |
|
Three Months | |
|
|
Ended | |
|
Ended | |
|
Ended | |
|
|
March 31, | |
|
June 30, | |
|
September 30, | |
|
|
2003 | |
|
2003 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Net income (loss) attributed to common stockholders
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Previously reported
|
|
$ |
(183 |
) |
|
$ |
(330 |
) |
|
$ |
1,136 |
|
|
Adjustment gain on sale of stock in a subsidiary
|
|
|
|
|
|
|
|
|
|
|
2,433 |
|
|
Adjustment depreciation expense
|
|
|
|
|
|
|
|
|
|
|
(49 |
) |
|
Adjustment minority interest expense
|
|
|
|
|
|
|
|
|
|
|
22 |
|
|
Adjustment foreign tax expense
|
|
|
(158 |
) |
|
|
(92 |
) |
|
|
(93 |
) |
|
|
|
|
|
|
|
|
|
|
|
Restated
|
|
$ |
(341 |
) |
|
$ |
(422 |
) |
|
$ |
3,449 |
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) per share, basic and diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Previously reported
|
|
$ |
(0.05 |
) |
|
$ |
(0.08 |
) |
|
$ |
0.29 |
|
|
Total adjustments
|
|
|
(0.04 |
) |
|
|
(0.03 |
) |
|
|
0.58 |
|
|
|
|
|
|
|
|
|
|
|
|
Restated
|
|
$ |
(0.09 |
) |
|
$ |
(0.11 |
) |
|
$ |
0.87 |
|
|
|
|
|
|
|
|
|
|
|
Note 3 Post Retirement Benefit Obligations
Pursuant to the Plan of Reorganization that was confirmed by the
Bankruptcy Court after acceptances by our creditors and
stockholders and was consummated on December 2, 1988, we
assumed the contractual obligation to Simplicity Manufacturing,
Inc. (SMI) to reimburse SMI for 50% of the actual cost of
medical and life insurance claims for a select group of retirees
(SMI Retirees) of the prior Simplicity Manufacturing
Division of Allis-Chalmers. The actuarial present value
of the expected retiree benefit obligation is determined by an
actuary and is the amount that results from applying actuarial
assumptions to (1) historical claims-cost data,
(2) estimates for the time value of money (through
discounts for interest) and (3) the probability of payment
(including decrements for death, disability, withdrawal, or
retirement) between today and expected date of benefit payments.
As of December 31, 2005, 2004 and 2003, we have
post-retirement benefit obligations of $335,000, $687,000 and
$545,000, respectively.
On June 30, 2003, we adopted the 401(k) Profit Sharing Plan
(the Plan). The Plan is a defined contribution
savings plan designed to provide retirement income to our
eligible employees. The Plan is intended to be qualified under
Section 401(k) of the Internal Revenue Code of 1986, as
amended. It is funded by voluntary pre-tax contributions from
eligible employees who may contribute a percentage of their
eligible compensation, limited and subject to statutory limits.
The Plan is also funded by
F-26
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
discretionary matching employer contributions from us. Eligible
employees cannot participate in the Plan until they have
attained the age of 21 and completed six-months of service with
us. Each participant is 100% vested with respect to the
participants contributions while our matching
contributions are vested over a three-year period in accordance
with the Plan document. Contributions are invested, as directed
by the participant, in investment funds available under the
Plan. Matching contributions of approximately $114,000, $35,000
and $10,000 were paid in 2005, 2004 and 2003, respectively.
Note 4 Acquisitions
In July 2003, through our subsidiary Mountain Air, we entered
into a limited liability company operating agreement with a
division of M-I, a joint venture between Smith International and
Schlumberger N.V. (Schlumberger Limited), to form AirComp,
a Texas limited liability company. The assets contributed by
Mountain Air were recorded at Mountain Airs historical
cost of $6.3 million, and the assets contributed by M-I
were recorded at a fair market value of $10.3 million. We
originally owned 55% and M-I originally owned 45% of AirComp. As
a result of our controlling interest and operating control, we
consolidated AirComp in our financial statements. AirComp
comprises the compressed air drilling services segment.
In September 2004, we acquired 100% of the outstanding stock of
Safco for $1.0 million. Safco leases spiral drill pipe and
provides related oilfield services to the oil drilling industry.
In September 2004, we acquired the remaining 19% of Tubular in
exchange for 1.3 million shares of our common stock. The
total value of the consideration paid to the seller, Jens
Mortensen, was $6.4 million which was equal to the number
of shares of common stock issued to Mr. Mortensen
(1.3 million) multiplied by the last sale price ($4.95) of
the common stock as reported on the American Stock Exchange on
the date of issuance. This amount was treated as a contribution
to stockholders equity. On the balance sheet, the
$1.9 million minority interest in Tubular was eliminated.
The balance of the contribution of $4.4 million was
allocated as follows: In June 2004, we obtained an appraisal of
the fixed assets of Tubular which valued the fixed assets at
$20.1 million. The book value of the fixed assets was
$15.8 million and the fixed assets appraised value was
$4.3 million over the book value. We increased the value of
our fixed assets by 19% of the amount of the excess of the
appraised value over the book value, or $.8 million. The
remaining balance of $3.6 million was allocated to goodwill.
In November 2004, AirComp acquired substantially all the assets
of Diamond Air for $4.6 million in cash and the assumption
of approximately $450,000 of accrued liabilities. We contributed
$2.5 million and M-I L.L.C. contributed $2.1 million
to AirComp LLC in order to fund the purchase. Goodwill of
$375,000 and other intangible assets of $2.3 million were
recorded in connection with the acquisition. Diamond Air
provides air drilling technology and products to the oil and gas
industry in West Texas, New Mexico and Oklahoma. Diamond Air is
a leading provider of air hammers and hammer bit products.
In December 2004, we acquired Downhole for approximately
$1.1 million in cash, 568,466 shares of our common stock
and the assumption of approximately $950,000 of debt. Goodwill
of $442,000 and other intangible assets of $795,000 were
recorded in connection with the acquisition. Downhole provides
economical chemical treatments to wells by inserting small
diameter, stainless steel coiled tubing into producing oil and
gas wells.
F-27
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
On April 1, 2005, we acquired 100% of the outstanding stock
of Delta for $4.6 million in cash, 223,114 shares of our
common stock and two promissory notes totaling $350,000. The
purchase price was allocated to fixed assets and inventory.
Delta, located in Lafayette, Louisiana, is a rental tool company
providing specialty rental items to the oil and gas industry
such as spiral heavy weight drill pipe, test plugs used to test
blow-out preventors, well head retrieval tools, spacer spools
and assorted handling tools.
On May 1, 2005, we acquired 100% of the outstanding capital
stock of Capcoil for $2.7 million in cash, 168,161 shares
of our common stock and the payment or assumption of
approximately $1.3 million of debt. Capcoil, located in
Kilgore, Texas, is engaged in downhole well servicing by
providing coil tubing services to enhance production from
existing wells. Goodwill of $184,000 and other identifiable
intangible assets of $1.4 million were recorded in
connection with the acquisition.
On July 11, 2005, we acquired the compressed air drilling
assets of W.T., based in South Texas, for $6.0 million in
cash. The equipment includes compressors, boosters, mist pumps
and vehicles. Goodwill of $82,000 and other identifiable
intangible assets of $1.5 million were recorded in
connection with the acquisition.
On July 11, 2005, we acquired from M-I its 45% interest in
AirComp and subordinated note in the principal amount of
$4.8 million issued by AirComp, for which we paid M-I
$7.1 million in cash and issued to M-I a $4.0 million
subordinated note bearing interest at 5% per annum. As a result,
we now own 100% of AirComp
Effective August 1, 2005, we acquired 100% of the
outstanding capital stock of Target for $1.3 million in
cash and forgiveness of a lease receivable of approximately
$0.6 million. The purchase price was allocated to the fixed
assets of Target and resulted in the recording of a
$0.8 million deferred tax liability. The results of Target
are included in our directional and horizontal drilling segment
as their Measure While Drilling equipment is utilized in that
segment.
On September 1, 2005, we acquired the casing and tubing
service assets of Patterson Services, Inc. for approximately
$15.6 million. These assets are located in Corpus Christi,
Texas; Kilgore, Texas; Lafayette, Louisiana and Houma, Louisiana.
The acquisitions were accounted for using the purchase method of
accounting. The results of operations of the acquired entities
since the date of acquisition are included in our consolidated
income statement.
The following unaudited pro forma consolidated summary financial
information for the year ended December 31, 2005
illustrates the effects of the acquisitions of Delta, Capcoil,
W.T. and the minority interest in AirComp as if the acquisitions
had occurred as of January 1, 2005, based on the historical
results of the acquisitions. The following unaudited pro forma
consolidated summary financial information for the years ended
December 31, 2004 and 2003 illustrates the effects of the
acquisitions of Diamond Air, Downhole, Delta, Capcoil, W.T. and
the minority interest in AirComp as if the acquisitions had
occurred as of beginning of the period, based on the historical
results of the acquisitions (unaudited) (in thousands, except
per share amounts):
F-28
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Revenues
|
|
$ |
110,383 |
|
|
$ |
70,988 |
|
|
$ |
52,588 |
|
Operating income
|
|
$ |
14,143 |
|
|
$ |
8,233 |
|
|
$ |
4,276 |
|
Net income
|
|
$ |
8,180 |
|
|
$ |
4,000 |
|
|
$ |
2,459 |
|
Net income per common share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$ |
0.55 |
|
|
$ |
0.46 |
|
|
$ |
0.53 |
|
|
Diluted
|
|
$ |
0.50 |
|
|
$ |
0.48 |
|
|
$ |
0.48 |
|
Note 5 Inventories
Inventories are comprised of the following (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Hammer bits
|
|
|
|
|
|
|
|
|
|
Finished goods
|
|
$ |
1,402 |
|
|
$ |
857 |
|
|
Work in process
|
|
|
787 |
|
|
|
385 |
|
|
Raw materials
|
|
|
233 |
|
|
|
151 |
|
|
|
|
|
|
|
|
|
Total hammer bits
|
|
|
2,422 |
|
|
|
1,393 |
|
Hammers
|
|
|
584 |
|
|
|
417 |
|
Drive pipe
|
|
|
666 |
|
|
|
|
|
Rental supplies
|
|
|
64 |
|
|
|
|
|
Chemicals
|
|
|
201 |
|
|
|
254 |
|
Coiled tubing and related inventory
|
|
|
1,145 |
|
|
|
309 |
|
Shop supplies and related inventory
|
|
|
863 |
|
|
|
|
|
|
|
|
|
|
|
|
Total inventory
|
|
$ |
5,945 |
|
|
$ |
2,373 |
|
|
|
|
|
|
|
|
Note 6 Property and Other Intangible Assets
Property and equipment is comprised of the following at December
31 (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation | |
|
|
|
|
|
|
Period | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
Land
|
|
|
|
|
|
$ |
27 |
|
|
$ |
27 |
|
Building and improvements
|
|
|
15-20 years |
|
|
|
637 |
|
|
|
633 |
|
Transportation equipment
|
|
|
3-7 years |
|
|
|
7,772 |
|
|
|
4,854 |
|
Machinery and equipment
|
|
|
3-20 years |
|
|
|
77,002 |
|
|
|
36,411 |
|
Furniture, computers, software and leasehold improvements
|
|
|
3-7 years |
|
|
|
2,073 |
|
|
|
1,005 |
|
Construction in progress equipment
|
|
|
N/A |
|
|
|
3,059 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
|
|
|
|
90,570 |
|
|
|
42,930 |
|
Less: accumulated depreciation
|
|
|
|
|
|
|
(9,996 |
) |
|
|
(5,251 |
) |
|
|
|
|
|
|
|
|
|
|
Property and equipment, net
|
|
|
|
|
|
$ |
80,574 |
|
|
$ |
37,679 |
|
|
|
|
|
|
|
|
|
|
|
F-29
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
The net book value of equipment recorded under capital leases
was $908 and $0 at December 31, 2005 and 2004, respectively.
Intangible assets are as follows at December 31 (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Amortization | |
|
|
|
|
|
|
Period | |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
| |
Intellectual property
|
|
|
20 years |
|
|
$ |
1,009 |
|
|
$ |
1,009 |
|
Non-compete agreements
|
|
|
3-5 years |
|
|
|
4,630 |
|
|
|
2,856 |
|
Patent
|
|
|
15 years |
|
|
|
496 |
|
|
|
496 |
|
Other intangible assets
|
|
|
3-10 years |
|
|
|
3,811 |
|
|
|
2,732 |
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
|
|
|
$ |
9,946 |
|
|
$ |
7,093 |
|
Less: accumulated amortization
|
|
|
|
|
|
|
(3,163 |
) |
|
|
(2,036 |
) |
|
|
|
|
|
|
|
|
|
|
Intangibles assets, net
|
|
|
|
|
|
$ |
6,783 |
|
|
$ |
5,057 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
|
|
Gross | |
|
Accumulated | |
|
Current Year | |
|
Gross | |
|
Accumulated | |
|
Current Year | |
|
|
Value | |
|
Amortization | |
|
Amortization | |
|
Value | |
|
Amortization | |
|
Amortization | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Intellectual property
|
|
$ |
1,009 |
|
|
$ |
293 |
|
|
$ |
54 |
|
|
$ |
1,009 |
|
|
$ |
239 |
|
|
$ |
56 |
|
Non-compete agreements
|
|
|
4,630 |
|
|
|
1,916 |
|
|
|
884 |
|
|
|
2,856 |
|
|
|
1,032 |
|
|
|
300 |
|
Patent
|
|
|
496 |
|
|
|
39 |
|
|
|
33 |
|
|
|
496 |
|
|
|
6 |
|
|
|
6 |
|
Other intangible assets
|
|
|
3,811 |
|
|
|
915 |
|
|
|
277 |
|
|
|
2,732 |
|
|
|
759 |
|
|
|
420 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
9,946 |
|
|
$ |
3,163 |
|
|
$ |
1,248 |
|
|
$ |
7,093 |
|
|
$ |
2,036 |
|
|
$ |
782 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Future amortization of intangible assets at December 31,
2005 is as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Intangible Amortization by Period | |
|
|
| |
|
|
Years Ended December 31, | |
|
|
| |
|
|
|
|
2010 and | |
|
|
2006 | |
|
2007 | |
|
2008 | |
|
2009 | |
|
Thereafter | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
Intellectual property
|
|
$ |
55 |
|
|
$ |
55 |
|
|
$ |
55 |
|
|
$ |
55 |
|
|
$ |
496 |
|
Non-compete agreements
|
|
|
1,043 |
|
|
|
804 |
|
|
|
480 |
|
|
|
327 |
|
|
|
60 |
|
Patent
|
|
|
33 |
|
|
|
33 |
|
|
|
33 |
|
|
|
33 |
|
|
|
325 |
|
Other intangible assets
|
|
|
395 |
|
|
|
370 |
|
|
|
359 |
|
|
|
359 |
|
|
|
1,413 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Intangible Amortization
|
|
$ |
1,526 |
|
|
$ |
1,262 |
|
|
$ |
927 |
|
|
$ |
774 |
|
|
$ |
2,294 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-30
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Note 7 Income Taxes
The income tax provision consists of the following (in
thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Current Provision
|
|
|
|
|
|
|
|
|
|
|
|
|
Federal
|
|
$ |
123 |
|
|
$ |
|
|
|
$ |
|
|
State
|
|
|
595 |
|
|
|
|
|
|
|
|
|
Foreign
|
|
|
626 |
|
|
|
514 |
|
|
|
370 |
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
1,344 |
|
|
$ |
514 |
|
|
$ |
370 |
|
|
|
|
|
|
|
|
|
|
|
We are required to file a consolidated U.S. federal income tax
return. We pay foreign income taxes in Mexico related to
Allis-Chalmers Tubular Services Mexico revenues. There are
approximately $1.6 million of U.S. foreign tax credits
available to us and of that amount, the available U.S. foreign
tax credits may or may not be recoverable by us depending upon
the availability of taxable income in future years and
therefore, have not been recorded as an asset as of
December 31, 2005. Our foreign tax credits begin to expire
in the year 2007.
The following table reconciles the U.S. statutory tax rate to
our actual tax rate:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Income tax expense based on the U.S. statutory tax rate
|
|
|
34.0 |
% |
|
|
34.0 |
% |
|
|
34.0 |
% |
State taxes, net of federal benefit
|
|
|
6.1 |
|
|
|
|
|
|
|
|
|
Foreign income at other than U.S. rate
|
|
|
7.3 |
|
|
|
36.6 |
|
|
|
11.2 |
|
Valuation allowances
|
|
|
(98.7 |
) |
|
|
(209.4 |
) |
|
|
28.6 |
|
Nondeductible items, permanent differences and other
|
|
|
67.1 |
|
|
|
175.4 |
|
|
|
(62.6 |
) |
|
|
|
|
|
|
|
|
|
|
Effective tax rate
|
|
|
15.8 |
% |
|
|
36.6 |
% |
|
|
11.2 |
% |
|
|
|
|
|
|
|
|
|
|
Temporary differences are differences between the tax basis of
assets and liabilities and their reported amounts in the
financial statements that will result in differences between
income for tax purposes and income for financial statement
purposes in future years. A valuation allowance is established
for deferred tax assets when management, based upon available
information, considers it more likely than not that a benefit
from such assets will not be realized. We have recorded a
valuation allowance equal to the excess of deferred tax assets
over deferred tax liabilities as we were unable to determine
that it is more likely than not that the deferred tax asset will
be realized.
The Tax Reform Act of 1986 contains provisions that limit the
utilization of net operating loss and tax credit carry forwards
if there has been a change of ownership as described
in Section 382 of the Internal Revenue Code. Such a change
of ownership may limit the our utilization of our net operating
loss and tax credit carry forwards, and could be triggered by a
public offering or by subsequent sales of securities by us or
our stockholders.
F-31
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Deferred income tax assets and the related allowance as of
December 31, were as follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Deferred non-current income tax assets:
|
|
|
|
|
|
|
|
|
Net future (taxable) deductible items
|
|
$ |
384 |
|
|
$ |
533 |
|
Net operating loss carry forwards
|
|
|
5,656 |
|
|
|
4,894 |
|
A-C Reorganization Trust claims
|
|
|
29,098 |
|
|
|
30,112 |
|
|
|
|
|
|
|
|
Total deferred non-current income tax assets
|
|
|
35,138 |
|
|
|
35,539 |
|
Valuation allowance
|
|
|
(27,131 |
) |
|
|
(30,367 |
) |
|
|
|
|
|
|
|
Net deferred non-current income taxes
|
|
$ |
8,007 |
|
|
$ |
5,172 |
|
Deferred non-current income tax liabilities Depreciation
|
|
$ |
(8,007 |
) |
|
$ |
(5,172 |
) |
|
|
|
|
|
|
|
Net deferred income tax assets
|
|
$ |
|
|
|
$ |
|
|
|
|
|
|
|
|
|
Net operating loss carry forwards for tax purposes at
December 31, 2005 and 2004 were estimated to be
$16.6 million and $14.5 million, respectively,
expiring through 2024.
Net future tax-deductible items relate primarily to timing
differences. Our 1988 Plan of Reorganization established the A-C
Reorganization Trust to settle claims and to make distributions
to creditors and certain stockholders. We transferred cash and
certain other property to the A-C Reorganization Trust on
December 2, 1988. Payments made by us to the A-C
Reorganization Trust did not generate tax deductions for us upon
the transfer but generate deductions for us as the A-C
Reorganization Trust makes payments to holders of claims.
The Plan of Reorganization also created a trust to process and
liquidate product liability claims. Payments made by the A-C
Reorganization Trust to the product liability trust did not
generate current tax deductions for us upon the payment but
generate deductions for us as the product liability trust makes
payments to liquidate claims or incurs other expenses.
We believe the above-named trusts are grantor trusts and
therefore we include the income or loss of these trusts in our
income or loss for tax purposes, resulting in an adjustment of
the tax basis of net operating and capital loss carry forwards.
The income or loss of these trusts is not included in our
results of operations for financial reporting purposes.
F-32
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Note 8 Debt
Our long-term debt consists of the following: (in
thousands)
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Bank term loans
|
|
$ |
42,090 |
|
|
$ |
13,373 |
|
Revolving line of credit
|
|
|
6,400 |
|
|
|
3,873 |
|
Subordinated note payable to M-I LLC
|
|
|
4,000 |
|
|
|
4,818 |
|
Subordinated seller note
|
|
|
3,031 |
|
|
|
4,000 |
|
Seller note
|
|
|
850 |
|
|
|
1,600 |
|
Notes payable under non-compete agreements
|
|
|
698 |
|
|
|
664 |
|
Notes payable to former directors
|
|
|
96 |
|
|
|
402 |
|
Notes payable to former shareholders
|
|
|
|
|
|
|
49 |
|
Real estate loan
|
|
|
548 |
|
|
|
|
|
Vendor financing
|
|
|
|
|
|
|
1,164 |
|
Equipment & vehicle installment notes
|
|
|
1,939 |
|
|
|
530 |
|
Capital lease obligations
|
|
|
917 |
|
|
|
|
|
|
|
|
|
|
|
|
Total debt
|
|
|
60,569 |
|
|
|
30,473 |
|
Less: short-term debt and current maturities
|
|
|
5,632 |
|
|
|
5,541 |
|
|
|
|
|
|
|
|
Long-term debt obligations
|
|
$ |
54,937 |
|
|
$ |
24,932 |
|
|
|
|
|
|
|
|
As of December 31, 2005 and 2004, our debt was
approximately $60.6 million and $30.5 million,
respectively. Our weighted average interest rate for all of our
outstanding debt was approximately 7.5% at December 31, 2005 and
7.3% at December 31, 2004.
Maturities of debt obligations at December 31, 2005 are as
follows (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Debt | |
|
Capital Leases | |
|
Total | |
|
|
| |
|
| |
|
| |
Year Ending:
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2006
|
|
$ |
5,158 |
|
|
$ |
474 |
|
|
$ |
5,632 |
|
December 31, 2007
|
|
|
49,620 |
|
|
|
443 |
|
|
|
50,063 |
|
December 31, 2008
|
|
|
4,267 |
|
|
|
|
|
|
|
4,267 |
|
December 31, 2009
|
|
|
69 |
|
|
|
|
|
|
|
69 |
|
December 31, 2010
|
|
|
538 |
|
|
|
|
|
|
|
538 |
|
Thereafter
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
59,652 |
|
|
$ |
917 |
|
|
$ |
60,569 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Bank loans and line of
credit agreements |
On July 11, 2005, we replaced our previous credit agreement
with a new agreement that provided for the following senior
secured credit facilities:
|
|
|
|
|
A $13.0 million revolving line of credit. Borrowings were
limited to 85% of eligible accounts receivable plus 50% of
eligible inventory (up to a maximum of $2.0 million of
borrowings based |
F-33
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
on inventory). This line of
credit was used to finance working capital requirements and
other general corporate purposes, including the issuance of
standby letters of credit. Outstanding borrowings under this
line of credit were $6.4 million at a margin above prime
and LIBOR rates plus margin averaging approximately 8.1% as of
December 31, 2005.
|
|
|
|
Two term loans totaling
$42.0 million. Outstanding borrowings under these term
loans were $42.0 million as of December 31, 2005.
These loans were at LIBOR rates plus a margin which averages
approximately 7.8%.
|
We borrowed against the July 2005 facilities to refinance our
prior credit facility and the AirComp credit facility, to fund
the acquisition of M-Is interest in AirComp and the air
drilling assets of W.T. and to pay transaction costs related to
the refinancing and the acquisitions. We incurred debt
retirement expense of $1.1 million related to the
refinancing. This amount includes prepayment penalties and the
write-off of deferred financing fees of the previous financing,
which has been included in interest expense in the consolidated
statement of operations.
Borrowings under the July 2005 credit facilities were to mature
in July 2007. Amounts outstanding under the term loans as of
July 2006 were to be repaid in monthly principal payments based
on a 48 month repayment schedule with the remaining balance
due at maturity. Additionally, during the second year, we were
to be required to prepay the remaining balance of the term loans
by 75% of excess cash flow, if any, after debt service and
capital expenditures. The interest rate payable on borrowings
was based on a margin over the London Interbank Offered Rate,
referred to as LIBOR, or the prime rate, and there was a 0.5%
fee on the undrawn portion of the revolving line of credit. The
margin over LIBOR was to increase by 1.0% in the second year.
The credit facilities were secured by substantially all of our
assets and contain customary events of default and financial and
other covenants, including limitations on our ability to incur
additional indebtedness, make capital expenditures, pay
dividends or make other distributions, create liens and sell
assets.
All amounts outstanding under our July 2005 credit agreement
were paid off with the proceeds of our senior notes offering in
January 2006. We executed an amended and restated credit
agreement which provides a $25.0 million revolving line of
credit (See Note 22).
Prior to July 11, 2005, we had a credit agreement dated
December 7, 2004 that provided for the following credit
facilities:
|
|
|
|
|
A $10.0 million revolving line of credit. Borrowings were
limited to 85% of eligible accounts receivables, as defined.
Outstanding borrowings under this line of credit were
$2.4 million as of December 31, 2004. |
|
|
|
A term loan in the amount of $6.3 million to be repaid in
monthly payments of principal of $105,583 per month. We were
also required to prepay this term loan by an amount equal to 20%
of receipts from our largest customer in Mexico. Proceeds of the
term loan were used to prepay the term loan owed by Tubular
Services and to prepay the 12% $2.4 million subordinated
note and retire its related warrants. The outstanding balance
was $6.3 million as of December 31, 2004. |
|
|
|
A $6.0 million capital expenditure and acquisition line of
credit. Borrowings under this facility were payable monthly over
four years beginning in January 2006. Availability of this
capital |
F-34
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
expenditure term loan facility
was subject to security acceptable to the lender in the form of
equipment or other acquired collateral. There were no
outstanding borrowings as of December 31, 2004.
|
These credit facilities were to mature on December 31, 2007
and were secured by liens on substantially all of our assets.
The agreement governing these credit facilities contained
customary events of default and financial covenants. It also
limited our ability to incur additional indebtedness, make
capital expenditures, pay dividends or make other distributions,
create liens and sell assets. Interest accrued at an adjustable
rate based on the prime rate and was 6.25% as of
December 31, 2004. We paid a 0.5% per annum fee on the
undrawn portion of the revolving line of credit and the capital
expenditure line.
In connection with the acquisition of Tubular and Strata in
2002, we issued a 12% secured subordinated note in the original
amount of $3.0 million. In connection with this
subordinated note, we issued redeemable warrants valued at
$1.5 million, which were recorded as a discount to the
subordinated debt and as a liability. The discount was amortized
over the life of the subordinated note beginning
February 6, 2002 as additional interest expense of which
$350,000 and $300,000 were recognized in the years ended
December 31, 2004 and December 31, 2003, respectively.
The debt was recorded at $2.7 million at December 31,
2003, net of the unamortized portion of the put obligation. On
December 7, 2004, we prepaid the $2.4 million balance
of the 12% subordinated note and retired the $1.5 million
of warrants, with a portion of the proceeds from our
$6.3 million bank term loan.
Prior to July 11, 2005, our AirComp subsidiary had the
credit facilities described below. These credit facilities were
repaid in connection with our acquisition of the minority
interest in AirComp and the refinancing of our bank credit
facilities described above.
|
|
|
|
|
A $3.5 million bank line of credit. Interest accrued at an
adjustable rate based on the prime rate. We paid a 0.5% per
annum fee on the undrawn portion. Borrowings under the line of
credit were subject to a borrowing base consisting of 80% of
eligible accounts receivable. The balance at December 31,
2004 was $1.5 million. |
|
|
|
A $7.1 million term loan that accrued interest at an
adjustable rate based on either LIBOR or the prime rate.
Principal payments of $286,000 plus interest were due quarterly,
with a final maturity date of June 27, 2007. The balance at
December 31, 2004 was $6.8 million. |
|
|
|
A delayed draw term loan facility in the amount of
$1.5 million to be used for capital expenditures. Interest
accrued at an adjustable rate based on either the LIBOR or the
prime rate. Quarterly principal payments were to commence on
March 31, 2006 in an amount equal to 5.0% of the
outstanding balance as of December 31, 2005, with a final
maturity of June 27, 2007. There were no borrowings
outstanding under this facility as of December 31, 2004. |
The AirComp credit facilities were secured by liens on
substantially all of AirComps assets. The agreement
governing these credit facilities contained customary events of
default and required that AirComp satisfy various financial
covenants. It also limited AirComps ability to incur
additional indebtedness, make capital expenditures, pay
dividends or make other distributions, create liens and sell
assets. We guaranteed 55% of the obligations of AirComp under
these facilities.
F-35
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Tubular had two bank term loans with a remaining balance
totaling $90,000 and $263,000 at December 31, 2005 and
2004, with interest accruing at a floating interest rate based
on prime plus 2.0%. The interest rate was 9.25% and 7.25% at
December 31, 2005 and 2004. Monthly principal payments are
$13,000 plus interest. The maturity date of one of the loans,
with a balance of $60,000, was September 17, 2006, while
the second loan, with a balance of $30,000, had a final maturity
of January 12, 2007. The balances of these two loans were repaid
in full in January 2006 with the proceeds from our senior notes
offering.
|
|
|
Notes payable and real
estate loan |
AirComp had a subordinated note payable to M-I in the amount of
$4.8 million bearing interest at an annual rate of 5.0%. In
2007 each party had the right to cause AirComp to sell its
assets (or the other party may buy out such partys
interest), and in such event this note (including accrued
interest) was due and payable. The note was also due and payable
if M-I sells its interest in AirComp or upon a termination of
AirComp. At December 31, 2004, $376,000 of interest was
included in accrued interest. On July 11, 2005, we acquired
from M-I its 45% equity interest in AirComp and the subordinated
note in the principal amount of $4.8 million issued by
AirComp, for which we paid M-I $7.1 million in cash and
issued a new $4.0 million subordinated note bearing
interest at 5% per annum. The subordinated note issued to M-I
requires quarterly interest payments and the principal amount is
due October 9, 2007. Contingent upon a future equity
offering, the subordinated note is convertible into up to
700,000 shares of our common stock at a conversion price equal
to the market value of the common stock at the time of
conversion.
Tubular had a subordinated note payable to Jens Mortensen, the
seller of Tubular and one of our directors, in the amount of
$4.0 million with a fixed interest rate of 7.5%. Interest
was payable quarterly and the final maturity of the note is
January 31, 2006. The subordinated note was subordinated to
the rights of our bank lenders. The balance outstanding for this
note at December 31, 2005 and 2004 was $3.0 and
$4.0 million, respectively. The balance of this
subordinated note was repaid in full in January 2006 with
proceeds from our senior notes offering.
As part of the acquisition of Mountain Air in 2001, we issued a
note to the sellers of Mountain Air in the original amount of
$2.2 million accruing interest at a rate of 5.75% per
annum. The note was reduced to $1.5 million as a result of
the settlement of a legal action against the sellers in 2003. In
March 2005, we reached an agreement with the sellers and holders
of the note as a result of an action brought against us by the
sellers. Under the terms of the agreement, we paid the holders
of the note $1.0 million in cash, and agreed to pay an
additional $350,000 on June 1, 2006, and an additional
$150,000 on June 1, 2007, in settlement of all claims. (See
Note 16). At December 31, 2005 and 2004 the
outstanding amounts due were $500,000 and $1.6 million,
including accrued interest.
In connection with the purchase of Delta, we issued to the
sellers a note in the amount of $350,000. The note bears
interest at 2% and the principal and accrued interest is due on
April 1, 2006.
In connection with the purchase of Tubular, we agreed to pay a
total of $1.2 million to Mr. Mortensen in exchange for
a non-compete agreement. Monthly payments of $20,576 are due
under this agreement through January 31, 2007. In connection
with the purchase of Safco, we also agreed to pay a total of
$150,000 to the sellers in exchange for a non-compete agreement.
We are required to make annual payments of $50,000 through
September 30, 2007. In connection with the purchase of
F-36
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Capcoil, we agreed to pay a total of $500,000 to two management
employees in exchange for non-compete agreements. We are
required to make annual payments of $110,000 through May 2008.
Total amounts due under non-compete agreements at
December 31, 2005 and 2004 were $698,000 and $664,000,
respectively.
In 2000 we compensated directors, including current directors
Nederlander and Toboroff, who served on the board of directors
from 1989 to March 31, 1999 without compensation, by
issuing promissory notes totaling $325,000. The notes bear
interest at the rate of 5.0%. At December 31, 2005 and
2004, the principal and accrued interest on these notes totaled
approximately $96,000 and $402,000, respectively.
Our subsidiary, Downhole, had notes payable to two former
shareholders totaling $49,000. We were required to make monthly
payments of $8,878 through June 30, 2005. At
December 31, 2005 and 2004, the amounts outstanding were $0
and $49,000.
We also have a real estate loan which is payable in equal
monthly installments of $4,344 with the remaining outstanding
balance due on January 1, 2010. The loan has a floating
interest rate based on prime plus 2.0%. The outstanding
principal balance was $548,000 at December 31, 2005. The
balance of this loan was prepaid in full in January 2006 with
proceeds from our senior notes offering.
In December 2003, Strata, our directional drilling subsidiary,
entered into a financing agreement with a major supplier of
downhole motors for repayment of motor lease and repair cost
totaling $1.7 million. The agreement provided for repayment
of all amounts not later than December 30, 2005. Payment of
interest was due monthly and principal payments of $582,000 were
due on April 2005 and December 2005. The interest rate was fixed
at 8.0%. As of December 31, 2005 and 2004, the outstanding
balance was $0 and $1.2 million.
We have various equipment financing loans with interest rates
ranging from 5% to 11.5% and terms ranging from 2 to
5 years. As of December 31, 2005 and 2004, the
outstanding balances for equipment financing loans were
$1.9 million and $530,000, respectively. We also have
various capital leases with terms that expire in 2008. As of
December 31, 2005 and 2004, amounts outstanding under
capital leases were $917,000 and $0, respectively. In January
2006, we prepaid $350,000 of the outstanding equipment loans
with proceeds from our senior notes offering.
Note 9 Commitments and Contingencies
We have placed orders for capital equipment totaling
$6.8 million to be received and paid for through 2006. Of
this amount, $3.1 million is for six measurement while
drilling kits and ancillary equipment for our directional
drilling segment and $3.7 million is for two new capillary
tubing units and two new coil tubing units for our production
services segment. Of the $6.8 million in orders, we are
firmly committed to approximately $4.4 million as the
balance may be subject to cancellation with minimal loss of
prior cash deposits, if any.
F-37
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
We rent office space on a five-year lease which expires November
2009. We also rent certain other facilities and shop yards for
equipment storage and maintenance. Facility rent expense for the
years ended December 31, 2005, 2004 and 2003 was $987,000,
$577,000, and $370,000, respectively.
At December 31, 2005, future minimum rental commitments for
all operating leases are as follows (in thousands):
|
|
|
|
|
Years Ending:
|
|
|
|
|
December 31, 2006
|
|
$ |
926 |
|
December 31, 2007
|
|
|
833 |
|
December 31, 2008
|
|
|
629 |
|
December 31, 2009
|
|
|
446 |
|
December 31, 2010
|
|
|
44 |
|
Thereafter
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
2,878 |
|
|
|
|
|
Note 10 Stockholders Equity
In connection with the formation of AirComp in July 2003, we
eliminated $955,000 of our negative investment in the assets
contributed to AirComp. Under purchase accounting, we recognized
a $955,000 increase in stockholders equity. For the year ended
December 31, 2003, we accrued $350,000 of dividends payable
to the Preferred Stock holders. No dividends were declared or
paid.
On March 3, 2004, we entered into an agreement with an
investment banking firm whereby they would provide underwriting
and fundraising activities on our behalf. In exchange for their
services, the investment banking firm received a stock purchase
warrant to purchase 340,000 shares of common stock at an
exercise price of $2.50 per share. The warrant was exercised in
August of 2005. The fair value of the total warrants issued in
connection with the fundraising activities was established in
accordance with the Black-Scholes valuation model and as a
result, $641,000 was added to stockholders equity. The
following assumptions were utilized to determine fair value: no
dividend yield; expected volatility of 89.7%; risk free interest
rate of 7.00%; and expected life of five years.
During 2004, we issued two warrants (Warrants A and
B) for the purchase of 233,000 total shares of our common
stock at an exercise price of $0.75 per share and one warrant
for the purchase of 67,000 shares of our common stock at an
exercise price of $5.00 per share (Warrant C) in
connection with their subordinated debt financing. Warrants A
and B were redeemed for a total of $1,500,000 on
December 7, 2004. The fair value of Warrant C was
established in accordance with the Black-Scholes valuation model
and as a result, $47,000 was added to stockholders equity.
The following assumptions were utilized to determine fair value:
no dividend yield; expected volatility of 67.24%; risk free
interest rate of 5.00%; and expected life of four years.
On April 2, 2004, we completed the following transactions:
|
|
|
|
|
In exchange for an investment of $2.0 million, we issued
620,000 shares of our common stock for a purchase price equal to
$2.50 per share, and issued warrants to purchase 800,000 shares
of our common stock at an exercise price of $2.50 per share,
expiring on April 1, 2006, to an investor group (the
Investor Group) consisting of entities affiliated
with Donald and |
F-38
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
Christopher Engel and directors
Robert Nederlander and Leonard Toboroff. The aggregate purchase
price for the common stock was $1.55 million and the fair
value for the warrants was $450,000.
|
|
|
|
Energy Spectrum converted its
3,500,000 shares of Series A 10% Cumulative Convertible
Preferred Stock, including accrued dividend rights, into
1,718,090 shares of common stock. Energy Spectrum was granted
the preferred stock in connection with the Strata acquisition.
|
On August 10, 2004, we completed the private placement of
3,504,667 shares of our common stock at a price of $3.00 per
share. Our net proceeds, after selling commissions and expenses,
were approximately $9.6 million. We issued shares pursuant
to an exemption from the Securities Act of 1933, and agreed to
subsequently register the common stock under the Securities Act
of 1933 to allow investors to resell the common stock in public
markets.
On September 30, 2004, we completed the private placement
of 1,956,634 shares of our common stock at a price of $3.00 per
share. Our net proceeds, after selling commission and expenses,
were approximately $5.3 million. We issued shares pursuant
to an exemption from the Securities Act of 1933, and agreed to
subsequently register the common stock under the Securities Act
of 1933 to allow investors to resell the common stock in public
markets.
On September 30, 2004, we issued 1.3 million shares of
common stock to Jens Mortensen, a former director, in exchange
for his 19% interest in Tubular. As a result of this
transaction, we own 100% of Tubular. The total value of the
consideration paid to Jens was $6.4 million, which was
equal to the number of shares of common stock issued to
Mr. Mortensen multiplied by the last sale price ($4.95) of
the common stock as reported on the American Stock Exchange on
the date of issuance. This amount was treated as a contribution
to stockholders equity.
On December 10, 2004, we acquired Downhole for
approximately $1.1 million in cash, 568,466 shares of our
common stock and payment or assumption of $950,000 of debt.
Approximately $2.2 million, the value of the common stock
issued to Downholes sellers based on the closing price of
our common stock issued at the date of the acquisition, was
added to stockholders equity.
As of January 1, 2005, in relation to the acquisition of
Downhole, we executed a business development agreement with CTTV
Investments LLC, an affiliate of ChevronTexaco Inc., whereby we
issued 20,000 shares of our common stock to CTTV and further
agreed to issue up to an additional 60,000 shares to CTTV
contingent upon our subsidiaries receiving certain levels of
revenues in 2005 from ChevronTexaco and its affiliates. CTTV was
a minority owner of Downhole, which we acquired in 2004. Based
on the terms of the agreement, no additional shares were issued
in 2005.
On April 1, 2005, we acquired 100% of the outstanding stock
of Delta, for $4.6 million in cash, 223,114 shares of our
common stock and two promissory notes totaling $350,000.
Approximately $1.0 million, the value of the common stock
issued to Deltas sellers based on the closing price of our
common stock issued at the date of the acquisition, was added to
stockholders equity.
On May 1, 2005, we acquired 100% of the outstanding capital
stock of Capcoil for $2.7 million in cash, 168,161 shares
of our common stock and the payment or assumption of
approximately $1.3 million of debt. Approximately $750,000,
the value of the common stock issued to Capcoils sellers
F-39
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
based on the closing price of our common stock issued at the
date of the acquisition, was added to stockholders equity.
In August 2005, our stockholders approved an amendment to our
certificate of incorporation to increase the authorized number
of shares of our common stock from 20 million to
100 million and to increase our authorized preferred stock
from 10 million shares to 25 million shares and, we
completed a secondary public offering in which we sold 1,761,034
shares for approximately $15.5 million, net of expenses.
We also had options and warrants exercised during 2005. Those
exercises resulted in 1,076,154 shares of our common stock being
issued for $1.4 million.
Note 11 Reverse Stock Split
We effected a reverse stock split on June 10, 2004. As a
result of the reverse stock split, every five shares of our
common stock was combined into one share of common stock. The
reverse stock split reduced the number of shares of outstanding
common stock from 31,393,789 to approximately 6,265,000 and
reduced the number of our stockholders from 6,070 to
approximately 2,140. All share and related amounts presented
have been retroactively adjusted for the stock split.
Note 12 Stock Options
In 2000, we issued stock options and promissory notes to certain
current and former directors as compensation for services as
directors (See Note 8), and our Board of Directors granted
stock options to these same individuals. Options to purchase
4,800 shares of our common stock were granted with an exercise
price of $13.75 per share. These options vested immediately and
may be exercised any time prior to March 28, 2010. As of
December 31, 2005, none of the stock options had been
exercised. No compensation expense has been recorded for these
options that were issued with an exercise price equal to the
fair value of the common stock at the date of grant.
On May 31, 2001, the Board granted to Leonard Toboroff, one
of our directors, an option to purchase 100,000 shares of our
common stock at $2.50 per share, exercisable for 10 years
from October 15, 2001. The option was granted for services
provided by Mr. Toboroff to OilQuip prior to the merger,
including providing financial advisory services, assisting in
OilQuips capital structure and assisting OilQuip in
finding strategic acquisition opportunities. We recorded
compensation expense of $500,000 for the issuance of the option
for the year ended December 31, 2001.
The 2003 Incentive Stock Plan, as amended, permits us to grant
to our key employees and outside directors various forms of
stock incentives, including, among others, incentive and
non-qualified stock options and restricted stock. Stock
incentive terms are not to be in excess of ten years. As
disclosed in Note 1, we account for our stock-based
compensation using APB No. 25. We have adopted the
disclosure-only provisions of SFAS No. 123 for the
stock options granted to our employees and directors.
Accordingly, no compensation cost has been recognized for these
options.
F-40
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
A summary of our stock option activity and related information
is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, 2005 | |
|
December 31, 2004 | |
|
December 31, 2003 | |
|
|
| |
|
| |
|
| |
|
|
Shares | |
|
Weighted | |
|
Shares | |
|
|
|
Shares | |
|
|
|
|
Under | |
|
Avg. Exercise | |
|
Under | |
|
Weighted Avg. | |
|
Under | |
|
Weighted Avg. | |
|
|
Option | |
|
Price | |
|
Option | |
|
Exercise Price | |
|
Option | |
|
Exercise Price | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Beginning balance
|
|
|
1,215,000 |
|
|
$ |
3.20 |
|
|
|
973,300 |
|
|
$ |
2.78 |
|
|
|
104,800 |
|
|
$ |
3.00 |
|
Granted
|
|
|
1,695,000 |
|
|
|
6.44 |
|
|
|
248,000 |
|
|
|
4.85 |
|
|
|
868,500 |
|
|
|
2.75 |
|
Canceled
|
|
|
(15,300 |
) |
|
|
3.33 |
|
|
|
(6,300 |
) |
|
|
2.78 |
|
|
|
|
|
|
|
|
|
Exercised
|
|
|
(33,833 |
) |
|
|
2.80 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ending balance
|
|
|
2,860,867 |
|
|
$ |
5.10 |
|
|
|
1,215,000 |
|
|
$ |
3.20 |
|
|
|
973,300 |
|
|
$ |
2.78 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The following table summarizes additional information about our
stock options outstanding as of December 31, 2005:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted Average | |
|
|
|
|
|
|
Shares Under | |
|
Remaining | |
|
Options | |
|
|
Exercise Price |
|
Option | |
|
Contractual Life | |
|
Exercisable | |
|
Exercise Price | |
|
|
| |
|
| |
|
| |
|
| |
$ 2.50
|
|
|
100,000 |
|
|
|
5.79 years |
|
|
|
100,000 |
|
|
$ |
2.50 |
|
$ 2.75
|
|
|
829,067 |
|
|
|
7.96 years |
|
|
|
829,067 |
|
|
$ |
2.75 |
|
$ 3.86
|
|
|
920,000 |
|
|
|
9.09 years |
|
|
|
306,667 |
|
|
$ |
3.86 |
|
$ 4.85
|
|
|
259,000 |
|
|
|
8.73 years |
|
|
|
172,667 |
|
|
$ |
4.85 |
|
$ 4.87
|
|
|
154,000 |
|
|
|
9.40 years |
|
|
|
51,333 |
|
|
$ |
4.87 |
|
$10.85
|
|
|
594,000 |
|
|
|
9.96 years |
|
|
|
198,000 |
|
|
$ |
10.85 |
|
$13.75
|
|
|
4,800 |
|
|
|
4.24 years |
|
|
|
4,800 |
|
|
$ |
13.75 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ 5.11
|
|
|
2,860,867 |
|
|
|
8.82 years |
|
|
|
1,662,534 |
|
|
$ |
4.22 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 13 Stock Purchase Warrants
In conjunction with the Mountain Air purchase by OilQuip in
February of 2001, Mountain Air issued a common stock warrant for
620,000 shares to a third-party investment firm that assisted us
in its initial identification and purchase of the Mountain Air
assets. The warrant entitles the holder to acquire up to 620,000
shares of common stock of Mountain Air at an exercise price of
$.01 per share over a nine-year period commencing on
February 7, 2001.
We issued two warrants (Warrants A and B) for the
purchase of 233,000 total shares of our common stock at an
exercise price of $0.75 per share and one warrant for the
purchase of 67,000 shares of our common stock at an exercise
price of $5.00 per share (Warrant C) in connection
with our subordinated debt financing for Mountain Air in 2001.
Warrants A and B were paid off on December 7, 2004. Warrant
C is still outstanding at December 31, 2005.
On February 6, 2002, in connection with the acquisition of
substantially all of the outstanding stock of Strata, we issued
a warrant for the purchase of 87,500 shares of our common stock
at an exercise price of $0.75 per share over the term of four
years. The warrants were exercised in August of 2005.
F-41
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
In connection with the Strata Acquisition, on February 19,
2003, we issued Energy Spectrum an additional warrant to
purchase 175,000 shares of our common stock at an exercise price
of $0.75 per share. The warrants were exercised in August of
2005.
In March 2004, we issued a warrant to purchase 340,000 shares of
our common stock at an exercise price of $2.50 per share to
Morgan Joseph & Co., in consideration of financial advisory
services to be provided by Morgan Joseph pursuant to a
consulting agreement. The warrants were exercised in August 2005.
In April 2004, we issued warrants to purchase 20,000 shares of
common stock at an exercise price of $0.75 per share to Wells
Fargo Credit, Inc., in connection with the extension of credit
by Wells Fargo Credit Inc. The warrants were exercised in August
2005.
In April 2004, we completed a private placement of 620,000
shares of common stock and warrants to purchase 800,000 shares
of common stock to the following investors: Christopher Engel;
Donald Engel; the Engel Defined Benefit Plan; RER Corp., a
corporation wholly-owned by director Robert Nederlander; and
Leonard Toboroff, a director. The investors invested $1,550,000
in exchange for 620,000 shares of common stock for a purchase
price equal to $2.50 per share, and invested $450,000 in
exchange for warrants to purchase 800,000 shares of common stock
at an exercise of $2.50 per share, expiring on April 1,
2006. A total of 486,557 of these warrants were exercised in
2005.
In May 2004, we issued a warrant to purchase 3,000 shares of our
common stock at an exercise price of $4.75 per share to Jeffrey
R. Freedman in consideration of financial advisory services to
be provided by Mr. Freedman pursuant to a consulting
agreement. The warrants were exercised in May 2004.
Mr. Freedman was also granted 16,000 warrants in May of
2004 exercisable at $4.65 per share. These warrants were
exercised in November of 2005.
Warrants for 4,000 shares of our common stock at an exercise
price of $4.65 were also issued in May 2004 and remain
outstanding as of December 31, 2005.
Note 14 Lease Receivable
In June 2002, our subsidiary, Strata, sold its
measurement-while-drilling assets to a third party for
$1.3 million. Under the terms of the sale, we would receive
at least $15,000 per month for thirty-six months. After
thirty-six months, the purchaser had the option to pay the
remaining balance or continue paying a minimum of $15,000 per
month for twenty-four additional months. After the expiration of
the additional twenty-four months, the purchaser would repay any
remaining balance. This transaction had been accounted for as a
direct financing lease with the nominal residual gain from the
asset sale deferred into income over the life of the lease. In
August of 2005, we acquired 100% of the outstanding stock of the
buyer and the balance of the lease receivable was part of the
consideration of the acquisition. During the years ended
December 31, 2005, 2004 and 2003, we received a total of
$146,000, $229,000, and $251,000, respectively, in payments from
the third party related to this lease.
Note 15 Related Party Transactions
In July 2005, we entered into a lease of a yard in Buffalo,
Texas which is part owned by our Chief Operating Officer, David
Wilde. The monthly rent is $3,500.
F-42
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Alya H. Hidayatallah, the daughter of our Chairman and Chief
Executive Officer, Munawar H. Hidayatallah, has served as our
Vice President-Planning and Development since April 2005. In
2005, we paid Ms. Hidayatallah a salary at a rate of $80,000 per
annum.
At December 31, 2005 and 2004, we owed our Chief Executive
Officer, $0 and $175,000, respectively, related to deferred
compensation. In March and April of 2005 we paid all amounts due
Mr. Hidayatallah.
Until December 2004, our Chief Executive Officer and Chairman,
Munawar H. Hidayatallah and his wife were personal guarantors of
substantially all of the financing extended to us by commercial
banks. In December 2004, we refinanced most of our outstanding
bank debt and obtained the release of certain guarantees. After
the refinancing, Mr. Hidayatallah continued to guarantee the
Tubular $4.0 million subordinated seller note until July
2005. We paid Mr. Hidayatallah an annual guarantee fee
equal to one-quarter of one percent of the total amount of the
debt guaranteed by Mr. Hidayatallah. These fees aggregated
to $7,250 during 2005 and were paid quarterly, in arrears, based
upon the average amount of debt outstanding in the prior quarter.
In April 2004, we entered into an oral consulting agreement with
Leonard Toboroff, one of our directors, pursuant to which we pay
him $10,000 per month to advise us regarding financing and
acquisition opportunities.
Jens Mortensen, one of our former directors, is the former owner
of Tubular and held a 19% minority interest in Tubular until
September 30, 2004. He was also the holder of a
$4.0 million subordinated note payable issued by Tubular
and at December 31, 2005 was owed $60,000 in accrued
interest and $267,000 related to a non-compete agreement. (See
Note 8). The subordinated note was repaid in January of
2006 (See Note 22) and the accrued interest was paid in
January 2006. Mr. Mortensen, formerly the sole proprietor
of Tubular, owns a shop yard which he leases to Jens on a
monthly basis. Lease payments made under the terms of the lease
were $16,800, $28,800 and $28,800 for the years ended
December 31, 2005, 2004 and 2003, respectively. In
addition, Mr. Mortensen and members of his family own 100%
of Tex-Mex Rental & Supply Co., a Texas corporation, that
sold approximately $0, $167,000 and $173,000 of equipment and
other supplies to Tubular for the years ended December 31,
2005, 2004 and 2003, respectively.
As described in Note 8, several of our former directors
were issued promissory notes in 2000 in lieu of compensation for
services. Our current maturities of long-term debt includes
$96,000 and $402,000 as of December 31, 2005 and 2004,
respectively, relative to these notes.
Note 16 Settlement of Lawsuit
In June 2003, our subsidiary, Mountain Air, filed a lawsuit
against the former owners of Mountain Air Drilling Service
Company for breach of the asset purchase agreement pursuant to
which Mountain Air acquired Mountain Air Drilling Services
Company, alleging that the sellers stored hazardous materials on
the property leased by us without our consent and violated the
non-compete clause in the asset purchase agreement. On July 15,
2003, we entered into a settlement agreement with the sellers.
As of the date of the agreement, we owed the sellers a total of
$2.6 million including $2.2 million in principal and
approximately $363,000 in accrued interest. As part of the
settlement agreement, the note payable to the sellers was
reduced from $2.2 million to $1.5 million and the due
date of the note
F-43
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
payable was extended from February 6, 2006 to
September 30, 2007. The lump-sum payment due the sellers at
that date was $1.9 million. We recorded a one-time gain on
the reduction of the note payable to the sellers of
$1.0 million in the third quarter of 2003. The gain was
calculated by discounting the note payable to $1.5 million
using a present value calculation and accreting the note payable
to $1.9 million the amount due in September 2007. In March
2005, we reached an agreement with the sellers to settle an
action brought by the sellers under the note. Under the terms of
the agreement, we paid $1.0 million in April of 2005 and
will pay $350,000 on June 1, 2006 and the remaining
$150,000 on June 1, 2007, in settlement of all claims.
Note 17 Gain on Sale of Interest in a
Subsidiary
In July 2003, through the subsidiary Mountain Air, we entered
into a limited liability company operating agreement with a
division of M-I to form a Texas limited liability company named
AirComp. Both companies contributed assets with a combined value
of $16.6 million to AirComp. The contributed assets from
Mountain Air were contributed at a historical book value of
approximately $6.3 million and the assets contributed by
M-I were contributed at a fair market value of approximately
$10.3 million. Prior to the formation of AirComp, we owned
100% of Mountain Air and after the formation of AirComp,
Mountain Air owned 55% and M-I owned 45% of the business
combination. The business combination was accounted for as a
purchase and we recorded a one-time non-operating gain on the
sale of the 45% interest in the subsidiary of approximately
$2,433,000. The gain was calculated after recording the assets
contributed by M-I of approximately $10.3 million less the
subordinated note issued to M-I in the amount of approximately
$4.8 million, recording minority interest of approximately
$2,049,000 and an increase in equity of $955,000 in accordance
with Staff Accounting Bulletin No. 51
(SAB 51). We have not recorded any deferred
income taxes because the increase in assets and gain is a
permanent timing difference. We have adopted a policy that any
gain or loss in the future incurred on the sale in the stock or
an interest of a subsidiary would be recognized as such in the
income statement.
Note 18 Segment Information
At December 31, 2005, we had five operating segments
including: Directional Drilling Services (Strata and Target),
Compressed Air Drilling Services (AirComp), Casing and Tubing
Services (Tubular), Rental Tools (Safco and Delta) and
Production Services (Downhole and Capcoil). All of the segments
provide services to the energy industry. The revenues, operating
income (loss), depreciation and
F-44
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
amortization, capital expenditures and assets of each of the
reporting segments plus the Corporate function are reported
below for (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
|
|
|
|
(Restated) | |
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
43,901 |
|
|
$ |
24,787 |
|
|
$ |
16,008 |
|
Compressed air drilling services
|
|
|
25,662 |
|
|
|
11,561 |
|
|
|
6,679 |
|
Casing and tubing services
|
|
|
20,932 |
|
|
|
10,391 |
|
|
|
10,037 |
|
Rental tools
|
|
|
5,059 |
|
|
|
611 |
|
|
|
|
|
Production services
|
|
|
9,790 |
|
|
|
376 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenues
|
|
$ |
105,344 |
|
|
$ |
47,726 |
|
|
$ |
32,724 |
|
|
|
|
|
|
|
|
|
|
|
Operating Income (Loss):
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
7,389 |
|
|
$ |
3,061 |
|
|
$ |
1,103 |
|
Compressed air drilling services
|
|
|
5,612 |
|
|
|
1,169 |
|
|
|
17 |
|
Casing and tubing services
|
|
|
4,994 |
|
|
|
3,217 |
|
|
|
3,628 |
|
Rental tools
|
|
|
1,300 |
|
|
|
(71 |
) |
|
|
|
|
Production services
|
|
|
(99 |
) |
|
|
4 |
|
|
|
|
|
General corporate
|
|
|
(5,978 |
) |
|
|
(3,153 |
) |
|
|
(2,123 |
) |
|
|
|
|
|
|
|
|
|
|
Total income from operations
|
|
$ |
13,218 |
|
|
$ |
4,227 |
|
|
$ |
2,625 |
|
|
|
|
|
|
|
|
|
|
|
Depreciation and Amortization Expense:
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
887 |
|
|
$ |
466 |
|
|
$ |
275 |
|
Compressed air drilling services
|
|
|
1,946 |
|
|
|
1,329 |
|
|
|
1,139 |
|
Casing and tubing services
|
|
|
2,006 |
|
|
|
1,597 |
|
|
|
1,413 |
|
Rental tools
|
|
|
492 |
|
|
|
40 |
|
|
|
|
|
Production services
|
|
|
912 |
|
|
|
26 |
|
|
|
|
|
General corporate
|
|
|
418 |
|
|
|
120 |
|
|
|
109 |
|
|
|
|
|
|
|
|
|
|
|
Total depreciation and amortization expense
|
|
$ |
6,661 |
|
|
$ |
3,578 |
|
|
$ |
2,936 |
|
|
|
|
|
|
|
|
|
|
|
Capital Expenditures:
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
2,922 |
|
|
$ |
1,552 |
|
|
$ |
1,066 |
|
Compressed air drilling services
|
|
|
7,008 |
|
|
|
1,399 |
|
|
|
2,093 |
|
Casing and tubing services
|
|
|
5,207 |
|
|
|
1,285 |
|
|
|
2,176 |
|
Rental tools
|
|
|
435 |
|
|
|
232 |
|
|
|
|
|
Production services
|
|
|
1,514 |
|
|
|
106 |
|
|
|
|
|
General corporate
|
|
|
681 |
|
|
|
29 |
|
|
|
19 |
|
|
|
|
|
|
|
|
|
|
|
Total capital expenditures
|
|
$ |
17,767 |
|
|
$ |
4,603 |
|
|
$ |
5,354 |
|
|
|
|
|
|
|
|
|
|
|
F-45
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
|
|
|
|
(Restated) | |
Goodwill:
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
4,168 |
|
|
$ |
4,168 |
|
|
$ |
4,168 |
|
Compressed air drilling services
|
|
|
3,950 |
|
|
|
3,510 |
|
|
|
3,493 |
|
Casing and tubing services
|
|
|
3,673 |
|
|
|
3,673 |
|
|
|
|
|
Rental tools
|
|
|
|
|
|
|
|
|
|
|
|
|
Production services
|
|
|
626 |
|
|
|
425 |
|
|
|
|
|
General corporate
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total goodwill
|
|
$ |
12,417 |
|
|
$ |
11,776 |
|
|
$ |
7,661 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
As of December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
20,960 |
|
|
$ |
14,166 |
|
|
$ |
11,529 |
|
Compressed air drilling services
|
|
|
46,045 |
|
|
|
29,147 |
|
|
|
22,735 |
|
Casing and tubing services
|
|
|
45,351 |
|
|
|
21,197 |
|
|
|
18,191 |
|
Rental tools
|
|
|
8,034 |
|
|
|
1,291 |
|
|
|
|
|
Production services
|
|
|
12,282 |
|
|
|
5,806 |
|
|
|
|
|
General corporate
|
|
|
4,683 |
|
|
|
8,585 |
|
|
|
1,207 |
|
|
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
137,355 |
|
|
$ |
80,192 |
|
|
$ |
53,662 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
$ |
98,583 |
|
|
$ |
42,466 |
|
|
$ |
28,995 |
|
International
|
|
|
6,761 |
|
|
|
5,260 |
|
|
|
3,729 |
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
105,344 |
|
|
$ |
47,726 |
|
|
$ |
32,724 |
|
|
|
|
|
|
|
|
|
|
|
F-46
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Note 19 Supplemental Cash Flows Information (in
thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
(Restated) | |
Interest paid
|
|
$ |
3,924 |
|
|
$ |
2,159 |
|
|
$ |
2,341 |
|
|
|
|
|
|
|
|
|
|
|
Income taxes paid
|
|
$ |
676 |
|
|
$ |
514 |
|
|
$ |
370 |
|
|
|
|
|
|
|
|
|
|
|
Other non-cash investing and financing transactions:
|
|
|
|
|
|
|
|
|
|
|
|
|
Sale of property & equipment in connection with direct
financing lease (Note 14)
|
|
|
|
|
|
|
|
|
|
|
|
|
(Gain) on settlement of debt
|
|
$ |
|
|
|
$ |
|
|
|
$ |
(1,034 |
) |
Amortization of discount on debt
|
|
|
|
|
|
|
|
|
|
|
442 |
|
Purchase of equipment financed through assumption of debt or
accounts payable
|
|
|
592 |
|
|
|
|
|
|
|
906 |
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
592 |
|
|
$ |
|
|
|
$ |
314 |
|
|
|
|
|
|
|
|
|
|
|
AirComp formation:
|
|
|
|
|
|
|
|
|
|
|
|
|
Issuance of debt to joint venture by M-I
|
|
$ |
|
|
|
$ |
|
|
|
$ |
(4,818 |
) |
Contribution of property, plant and equipment by M-I to joint
venture
|
|
|
|
|
|
|
|
|
|
|
10,268 |
|
Increase in minority interest
|
|
|
|
|
|
|
|
|
|
|
(2,063 |
|
(Gain) on sale of stock in a subsidiary
|
|
|
|
|
|
|
|
|
|
|
(2,433 |
) |
Difference of our investment cost basis in AirComp and their
share of underlying equity of net assets of AirComp
|
|
|
|
|
|
|
|
|
|
|
(954 |
) |
|
|
|
|
|
|
|
|
|
|
Net cash paid in connection with the joint venture
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
Non-cash investing and financing transactions in connection with
acquisitions:
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair value of net assets acquired
|
|
$ |
|
|
|
$ |
(4,867 |
) |
|
$ |
|
|
Goodwill and other intangibles
|
|
|
|
|
|
|
(3,839 |
) |
|
|
|
|
Value of common stock, issued
|
|
|
1,750 |
|
|
|
2,177 |
|
|
|
|
|
Value of minority interest contribution
|
|
|
|
|
|
|
2,070 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
1,750 |
|
|
$ |
(4,459 |
) |
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
Acquisition of the remaining 19% of Jens:
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair value of net assets acquired
|
|
$ |
|
|
|
$ |
(813 |
) |
|
$ |
|
|
Goodwill and other intangibles
|
|
|
|
|
|
|
(3,676 |
) |
|
|
|
|
Value of common stock issued
|
|
|
|
|
|
|
6,434 |
|
|
|
|
|
Value of minority interest retirement
|
|
|
|
|
|
|
(1,945 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
F-47
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Note 20 Quarterly Results (Unaudited)
(in thousands, except per share amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
First | |
|
Second | |
|
Third | |
|
Fourth | |
|
|
Quarter | |
|
Quarter | |
|
Quarter | |
|
Quarter | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(Restated) | |
|
|
|
|
|
|
Year 2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
$ |
19,334 |
|
|
$ |
23,588 |
|
|
$ |
28,908 |
|
|
$ |
33,514 |
|
Operating income
|
|
|
2,247 |
|
|
|
2,914 |
|
|
|
3,524 |
|
|
|
4,533 |
|
Net income
|
|
|
1,567 |
|
|
|
1,769 |
|
|
|
1,293 |
|
|
|
2,546 |
|
Preferred stock dividend
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income attributed to common shares
|
|
$ |
1,567 |
|
|
$ |
1,769 |
|
|
$ |
1,293 |
|
|
$ |
2,546 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$ |
0.12 |
|
|
$ |
0.13 |
|
|
$ |
0.09 |
|
|
$ |
0.15 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
$ |
0.11 |
|
|
$ |
0.12 |
|
|
$ |
0.08 |
|
|
$ |
0.14 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
First | |
|
Second | |
|
Third | |
|
Fourth | |
|
|
Quarter | |
|
Quarter | |
|
Quarter | |
|
Quarter | |
|
|
| |
|
| |
|
| |
|
| |
|
|
(Restated) | |
|
|
|
|
|
|
Year 2004
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revenues
|
|
$ |
9,661 |
|
|
$ |
11,422 |
|
|
$ |
11,906 |
|
|
$ |
14,737 |
|
Operating income
|
|
|
1,030 |
|
|
|
1,150 |
|
|
|
1,237 |
|
|
|
810 |
|
Net income (loss)
|
|
|
472 |
|
|
|
413 |
|
|
|
515 |
|
|
|
(512 |
) |
Preferred stock dividend
|
|
|
(88 |
) |
|
|
(36 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributed to common shares
|
|
$ |
384 |
|
|
$ |
377 |
|
|
$ |
515 |
|
|
$ |
(512 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$ |
0.10 |
|
|
$ |
0.06 |
|
|
$ |
0.06 |
|
|
$ |
(0.04 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
$ |
0.08 |
|
|
$ |
0.05 |
|
|
$ |
0.05 |
|
|
$ |
(0.04 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 21 Legal Matters
We are named from time to time in legal proceedings related to
our activities prior to our bankruptcy in 1988; however, we
believe that we were discharged from liability for all such
claims in the bankruptcy and believe the likelihood of a
material loss relating to any such legal proceeding is remote.
We are involved in various other legal proceedings in the
ordinary course of business. The legal proceedings are at
different stages; however, we believe that the likelihood of
material loss relating to any such legal proceeding is remote.
Note 22 Subsequent Events
In January of 2006, we acquired 100% of the outstanding stock of
Specialty Rental Tools, Inc. (Specialty) for
$96.0 million in cash. Specialty, located in Lafayette,
Louisiana, is engaged in the
F-48
ALLIS-CHALMERS ENERGY INC.
NOTES TO CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
rental of high quality drill pipe, heavy weight spiral drill
pipe, tubing work strings, blow-out preventors, choke manifolds
and various valves and handling tools for oil and natural gas
drilling. During the nine months ended September 30, 2005,
Specialty generated aggregate revenues of $21.8 million.
In January of 2006, we closed on a private offering, to
qualified institutional buyers pursuant to Rule 144A under
the Securities Act of 1933, of $160.0 million principal
amount of our 9.0% senior notes due 2014, which we refer to as
our senior notes. The proceeds of the offering were used to fund
the acquisition of Specialty, to repay existing debt and for
general corporate purposes.
In January of 2006, we amended and restated our July 2005 credit
agreement to increase our borrowing capacity by exchanging the
existing two year $55.0 million facility for a new four
year $25.0 million facility. We refer to the July 2005
credit agreement, as so amended and restated, as our credit
agreement. All amounts outstanding under the previous
$55.0 million credit facility were repaid with proceeds
from the issuance of our senior notes. The credit
agreements interest rate is based on a margin over LIBOR
or the prime rate, and there is a 0.5% fee for the undrawn
portion. The credit facility is secured by a first priority lien
on substantially all of our assets.
In January 2006, with proceeds from the sale of our senior notes
we also prepaid the $3.0 million subordinated seller note
due to Jens Mortensen, the $548,000 real estate loan and
$430,000 in various outstanding term and equipment loans.
In February of 2006, David Groshoff resigned from our Board of
Directors and the Audit Committee. Mr. Groshoff served on
our Board since 1999, initially under an agreement on behalf of
the Pension Benefit Guaranty Corporation, which is a client of
Mr. Groshoffs employer. That agreement permitted the
PBGC to appoint a member to our Board so long as the PBGC held a
minimum number of shares of our stock. The PBGC sold all its
holdings in our stock in August 2005. As an investment
management employee of JPMorgan Asset Management,
Mr. Groshoff is subject to his employers policies
which generally prohibit employees from serving on public
company boards of directors without a meaningful client interest
in such companies. In light of the PBGCs sale of our
stock, these policies required Mr. Groshoffs
resignation from our Board. In March 2006, Robert Nederlander
was appointed to the Audit Committee to replace
Mr. Groshoff.
Through March 13, 2006, we received proceeds of
approximately $784,000 from the exercise of 313,000 warrants.
F-49
ALLIS-CHALMERS ENERGY INC.
CONSOLIDATED CONDENSED BALANCE SHEETS
(In thousands, except for share and per share amounts)
|
|
|
|
|
|
|
|
|
|
|
|
June 30, | |
|
December 31, | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
|
|
(Unaudited) | |
|
|
ASSETS |
Cash and cash equivalents
|
|
$ |
6,208 |
|
|
$ |
1,920 |
|
Trade receivables, net
|
|
|
49,114 |
|
|
|
26,964 |
|
Inventory
|
|
|
9,897 |
|
|
|
5,945 |
|
Prepaid expenses and other
|
|
|
2,655 |
|
|
|
823 |
|
|
|
|
|
|
|
|
|
Total current assets
|
|
|
67,874 |
|
|
|
35,652 |
|
Property and equipment, net
|
|
|
185,750 |
|
|
|
80,574 |
|
Goodwill
|
|
|
12,417 |
|
|
|
12,417 |
|
Other intangible assets, net
|
|
|
7,131 |
|
|
|
6,783 |
|
Debt issuance costs, net
|
|
|
6,187 |
|
|
|
1,298 |
|
Other assets
|
|
|
1,327 |
|
|
|
631 |
|
|
|
|
|
|
|
|
|
Total assets
|
|
$ |
280,686 |
|
|
$ |
137,355 |
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY |
Current maturities of long-term debt
|
|
$ |
4,059 |
|
|
$ |
5,632 |
|
Trade accounts payable
|
|
|
9,616 |
|
|
|
9,018 |
|
Accrued salaries, benefits and payroll taxes
|
|
|
2,270 |
|
|
|
1,271 |
|
Accrued interest
|
|
|
6,654 |
|
|
|
289 |
|
Accrued income taxes
|
|
|
1,686 |
|
|
|
668 |
|
Accrued expenses
|
|
|
6,095 |
|
|
|
3,682 |
|
Accounts payable, related parties
|
|
|
|
|
|
|
60 |
|
|
|
|
|
|
|
|
|
Total current liabilities
|
|
|
30,380 |
|
|
|
20,620 |
|
Accrued postretirement benefit obligations
|
|
|
319 |
|
|
|
335 |
|
Long-term debt, net of current maturities
|
|
|
165,957 |
|
|
|
54,937 |
|
Other long-term liabilities
|
|
|
749 |
|
|
|
588 |
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
197,405 |
|
|
|
76,480 |
|
Commitments and contingencies
|
|
|
|
|
|
|
|
|
|
STOCKHOLDERS EQUITY |
Preferred stock, $0.01 par value (25,000,000 shares authorized,
no shares issued)
|
|
|
|
|
|
|
|
|
Common stock, $0.01 par value (100,000,000 shares authorized;
18,516,714 issued and outstanding at June 30, 2006 and
16,859,988 issued and outstanding at December 31, 2005)
|
|
|
185 |
|
|
|
169 |
|
Capital in excess of par value
|
|
|
67,261 |
|
|
|
58,889 |
|
Retained earnings
|
|
|
15,835 |
|
|
|
1,817 |
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
83,281 |
|
|
|
60,875 |
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity
|
|
$ |
280,686 |
|
|
$ |
137,355 |
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of the Consolidated
Condensed Financial Statements.
F-50
ALLIS-CHALMERS ENERGY INC.
CONSOLIDATED CONDENSED INCOME STATEMENTS
(In thousands, except per share amounts)
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three Months | |
|
For the Six Months | |
|
|
Ended June 30, | |
|
Ended June 30, | |
|
|
| |
|
| |
|
|
2006 | |
|
2005 | |
|
2006 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
60,470 |
|
|
$ |
23,588 |
|
|
$ |
107,498 |
|
|
$ |
42,922 |
|
Cost of revenues
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Direct costs
|
|
|
31,966 |
|
|
|
15,691 |
|
|
|
59,081 |
|
|
|
28,476 |
|
|
Depreciation
|
|
|
3,828 |
|
|
|
1,092 |
|
|
|
7,158 |
|
|
|
2,006 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total cost of revenues
|
|
|
35,794 |
|
|
|
16,783 |
|
|
|
66,239 |
|
|
|
30,482 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross margin
|
|
|
24,676 |
|
|
|
6,805 |
|
|
|
41,259 |
|
|
|
12,440 |
|
General and administrative
|
|
|
8,139 |
|
|
|
3,465 |
|
|
|
15,482 |
|
|
|
6,459 |
|
Amortization
|
|
|
666 |
|
|
|
426 |
|
|
|
1,273 |
|
|
|
820 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income from operations
|
|
|
15,871 |
|
|
|
2,914 |
|
|
|
24,504 |
|
|
|
5,161 |
|
Other income (expense):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest
|
|
|
(3,797 |
) |
|
|
(645 |
) |
|
|
(7,425 |
) |
|
|
(1,166 |
) |
|
Other
|
|
|
(6 |
) |
|
|
10 |
|
|
|
20 |
|
|
|
158 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total other income (expense)
|
|
|
(3,803 |
) |
|
|
(635 |
) |
|
|
(7,405 |
) |
|
|
(1,008 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income before minority interest and income taxes
|
|
|
12,068 |
|
|
|
2,279 |
|
|
|
17,099 |
|
|
|
4,153 |
|
Minority interest in income of subsidiaries
|
|
|
|
|
|
|
(344 |
) |
|
|
|
|
|
|
(488 |
) |
Provision for income taxes
|
|
|
(2,474 |
) |
|
|
(166 |
) |
|
|
(3,081 |
) |
|
|
(329 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
9,594 |
|
|
$ |
1,769 |
|
|
$ |
14,018 |
|
|
$ |
3,336 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$ |
0.53 |
|
|
$ |
0.13 |
|
|
$ |
0.80 |
|
|
$ |
0.24 |
|
|
|
Diluted
|
|
$ |
0.50 |
|
|
$ |
0.12 |
|
|
$ |
0.74 |
|
|
$ |
0.22 |
|
Weighted average shares outstanding:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
18,050 |
|
|
|
13,967 |
|
|
|
17,578 |
|
|
|
13,800 |
|
|
|
Diluted
|
|
|
19,140 |
|
|
|
15,103 |
|
|
|
19,000 |
|
|
|
14,900 |
|
The accompanying Notes are an integral part of the Consolidated
Condensed Financial Statements.
F-51
ALLIS-CHALMERS ENERGY INC.
CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS
(in thousands)
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Six Months | |
|
|
Ended June 30, | |
|
|
| |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Cash Flows from Operating Activities:
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
14,018 |
|
|
$ |
3,336 |
|
|
Adjustments to reconcile net income to net cash provided by
operating activities:
|
|
|
|
|
|
|
|
|
|
|
Depreciation
|
|
|
7,158 |
|
|
|
2,006 |
|
|
|
Amortization
|
|
|
1,273 |
|
|
|
820 |
|
|
|
Imputed interest
|
|
|
355 |
|
|
|
|
|
|
|
Stock option expense
|
|
|
1,778 |
|
|
|
|
|
|
|
Provision for bad debts
|
|
|
279 |
|
|
|
|
|
|
|
Minority interest in income of subsidiaries
|
|
|
|
|
|
|
488 |
|
|
|
Loss on sale of property and equipment
|
|
|
119 |
|
|
|
|
|
|
|
Changes in operating assets and liabilities, net of acquisitions:
|
|
|
|
|
|
|
|
|
|
|
|
(Increase) in trade receivable
|
|
|
(13,581 |
) |
|
|
(3,024 |
) |
|
|
|
(Increase) in inventory
|
|
|
(1,499 |
) |
|
|
(1,090 |
) |
|
|
|
Decrease in other current assets
|
|
|
278 |
|
|
|
201 |
|
|
|
|
(Increase) in other assets
|
|
|
(663 |
) |
|
|
(375 |
) |
|
|
|
(Decrease) increase in accounts payable
|
|
|
(1,517 |
) |
|
|
610 |
|
|
|
|
Increase in accrued interest
|
|
|
6,365 |
|
|
|
35 |
|
|
|
|
Increase (decrease) in accrued expenses
|
|
|
1,818 |
|
|
|
(296 |
) |
|
|
|
Increase in accrued salaries, benefits and payroll taxes
|
|
|
657 |
|
|
|
172 |
|
|
|
|
Increase in other long-term liabilities
|
|
|
145 |
|
|
|
6 |
|
|
|
|
|
|
|
|
|
|
|
|
Net Cash Provided By Operating Activities
|
|
|
16,983 |
|
|
|
2,889 |
|
|
|
|
|
|
|
|
Cash Flows from Investing Activities:
|
|
|
|
|
|
|
|
|
|
Acquisition of businesses, net of cash received
|
|
|
(106,564 |
) |
|
|
(7,088 |
) |
|
Proceeds from sale of property and equipment
|
|
|
1,814 |
|
|
|
|
|
|
Purchase of property and equipment
|
|
|
(14,246 |
) |
|
|
(5,463 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net Cash Used In Investing Activities
|
|
|
(118,996 |
) |
|
|
(12,551 |
) |
|
|
|
|
|
|
|
Cash Flows from Financing Activities:
|
|
|
|
|
|
|
|
|
|
Proceeds from exercises of options and warrants
|
|
|
4,960 |
|
|
|
|
|
|
Proceeds from long-term debt
|
|
|
161,412 |
|
|
|
5,210 |
|
|
Proceeds from line of credit
|
|
|
5,000 |
|
|
|
|
|
|
Repayments on long-term debt
|
|
|
(45,291 |
) |
|
|
|
|
|
Repayments on related party debt
|
|
|
(3,031 |
) |
|
|
|
|
|
Repayments on line of credit
|
|
|
(11,400 |
) |
|
|
|
|
|
Debt issuance costs
|
|
|
(5,349 |
) |
|
|
(199 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net Cash Provided By Financing Activities
|
|
|
106,301 |
|
|
|
5,011 |
|
|
|
|
|
|
|
|
Net change in cash and cash equivalents
|
|
|
4,288 |
|
|
|
(4,651 |
) |
Cash and cash equivalents at beginning of year
|
|
|
1,920 |
|
|
|
7,344 |
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$ |
6,208 |
|
|
$ |
2,693 |
|
|
|
|
|
|
|
|
The accompanying Notes are an integral part of the Consolidated
Condensed Financial Statements.
F-52
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS
Note 1 Nature of Business and Summary of
Significant Accounting Policies
Nature of Operations
We are a multi-faceted oilfield service company that provides
services and equipment to oil and natural gas exploration and
production companies, domestically in Texas, Louisiana, New
Mexico, Colorado, Oklahoma, Mississippi, Utah, Wyoming, offshore
in the Gulf of Mexico, and internationally in Mexico. We operate
in five sectors of the oil and natural gas service industry:
directional drilling services; rental tools; casing and tubing
services; compressed air drilling services; and production
services.
We derive operating revenues from rates per day and rates per
job that we charge for the labor and equipment required to
provide a service. The price we charge for our services depends
upon several factors, including the level of oil and natural gas
drilling activity and the competitive environment in the
particular geographic regions in which we operate. Contracts are
awarded based on price, quality of service and equipment and
general reputation and experience of our personnel. The
principal operating costs are direct and indirect labor and
benefits, repairs and maintenance of our equipment, insurance,
equipment rentals, fuel, depreciation and general and
administrative expenses.
Basis of Presentation
Our unaudited consolidated condensed financial statements
included herein have been prepared pursuant to the rules and
regulations of the Securities and Exchange Commission, or SEC.
Accordingly, certain information and disclosures normally
included in financial statements prepared in accordance with
generally accepted accounting principles have been condensed or
omitted. We believe that the presentations and disclosures
herein are adequate to make the information not misleading. The
unaudited consolidated condensed financial statements reflect
all adjustments (consisting of normal recurring adjustments)
necessary for a fair presentation of the interim periods. These
unaudited consolidated condensed financial statements should be
read in conjunction with our audited consolidated financial
statements included in our Annual Report on
Form 10-K for the
year ended December 31, 2005. The results of operations for
the interim periods are not necessarily indicative of the
results of operations to be expected for the full year.
Certain reclassifications have been made to the prior
years consolidated condensed financial statements to
conform with the current period presentation.
The preparation of financial statements in conformity with
accounting principles generally accepted in the United States of
America requires management to make estimates and assumptions
that affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of
the financial statements and the reported amounts of revenues
and expenses during the reporting period. Future events and
their effects cannot be perceived with certainty. Accordingly,
our accounting estimates require the exercise of judgment. While
management believes that the estimates and assumptions used in
the preparation of the consolidated financial statements are
appropriate, actual results could differ from those estimates.
Estimates are used for, but are not limited to, determining the
following: allowance for doubtful accounts, recoverability of
long-lived assets and intangibles, useful lives used in
depreciation and amortization, income taxes and valuation
allowances. The accounting estimates used in the
F-53
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
preparation of the consolidated financial statements may change
as new events occur, as more experience is acquired, as
additional information is obtained and as our operating
environment changes.
In July 2006, the FASB issued FASB Interpretation No. 48,
Accounting for Uncertainty in Income Taxes an
interpretation of FASB Statement No. 109
(FIN 48). FIN 48 clarifies the
accounting for uncertainty in income taxes recognized in an
enterprises financial statements in accordance with
SFAS No. 109, Accounting for Income Taxes. It
prescribes a recognition threshold and measurement attribute for
financial statement recognition and measurement of a tax
position taken or expected to be taken in a tax return. This
interpretation is effective for fiscal years beginning after
December 15, 2006. We are currently evaluating the
provisions of FIN 48 and have not yet determined the
impact, if any, on our financial statements.
Note 2 Acquisitions
Effective April 1, 2006, we acquired 100% of the
outstanding stock of Rogers Oil Tools, Inc., or Rogers, based in
Lafayette, Louisiana, for a total consideration of approximately
$13.7 million, which includes $11.3 million in cash,
$1.6 million in our common stock and a $750,000 three-year
promissory note. In addition, we purchased all the patents and
proprietary technology that Tommie L. Rogers, Rogers
founder and Chief Executive Officer, developed at Rogers. Rogers
provides service for tubing tongs and casing tongs and rents and
sells specialized automated power tongs to the snubbing and well
control markets. Rogers also rents and sells drill pipe tongs,
accessories, hydraulic power units and hydraulic tong
positioners. The following table summarizes the allocation of
the purchase price to the estimated fair value of the assets
acquired and liabilities assumed at the date of acquisition:
|
|
|
|
|
|
Current assets
|
|
$ |
4,520 |
|
Property and equipment
|
|
|
9,866 |
|
Intangible assets
|
|
|
1,131 |
|
|
|
|
|
|
Total assets acquired
|
|
|
15,517 |
|
|
|
|
|
Current liabilities
|
|
|
1,717 |
|
Other long-term liabilities
|
|
|
100 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
1,817 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
13,700 |
|
|
|
|
|
Approximately $380,000 of costs were incurred in relation to the
Rogers acquisition. Rogers historical property and
equipment values were increased by approximately
$8.4 million based on third-party valuations. Intangible
assets include $981,000 assigned to patents and $150,000
assigned to non-compete based on third-party valuations and
employment contracts. The intangibles have a weighted-average
useful life of 9 years.
Effective January 1, 2006, we acquired 100% of the
outstanding stock of Specialty Rental Tools, Inc., or Specialty,
for $96.0 million in cash. The results of Specialtys
operations have been included in the consolidated financial
statements since that date. Specialty, located in Lafayette,
Louisiana, is engaged in the rental of high quality drill pipe,
heavy weight spiral drill pipe, tubing work strings, blow-out
preventors, choke manifolds and various valves and handling
tools for oil and natural gas drilling.
F-54
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
For the year ended December 31, 2005, Specialty had
revenues of $32.7 million. The following table summarizes
the allocation of the purchase price to the estimated fair value
of the assets acquired and liabilities assumed at the date of
acquisition:
|
|
|
|
|
|
Accounts receivable
|
|
$ |
7,167 |
|
|
|
|
|
Other current assets
|
|
|
425 |
|
|
|
|
|
Property and equipment
|
|
|
90,540 |
|
|
|
|
|
|
Total assets acquired
|
|
|
98,132 |
|
|
|
|
|
Current liabilities
|
|
|
2,058 |
|
Long-term debt
|
|
|
74 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
2,132 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
96,000 |
|
|
|
|
|
Approximately $453,000 of costs were incurred in relation to the
Specialty acquisition. Specialtys historical property and
equipment values were increased by approximately
$71.5 million based on third-party valuations.
On September 1, 2005, we acquired the casing and tubing
service assets of Patterson Services, Inc. for approximately
$15.6 million. These assets are located in Corpus Christi,
Texas; Kilgore, Texas; Lafayette, Louisiana and Houma, Louisiana.
Effective August 1, 2005, we acquired 100% of the
outstanding capital stock of Target Energy Inc., or Target, for
$1.3 million in cash and forgiveness of a lease receivable
of approximately $0.6 million. The purchase price was
allocated to the fixed assets of Target. The results of Target
are included in our directional and horizontal drilling segment
as their measurement while drilling, or MWD, equipment is
utilized in that segment.
On July 11, 2005, we acquired the compressed air drilling
assets of W.T. Enterprises, Inc., or WT, based in South Texas,
for $6.0 million in cash. The equipment includes
compressors, boosters, mist pumps and vehicles. Goodwill of
$82,000 and other identifiable intangible assets of
$1.5 million were recorded in connection with the
acquisition.
On July 11, 2005, we acquired from M-I its 45% interest in
AirComp L.L.C., or AirComp, and a subordinated note in the
principal amount of $4.8 million issued by AirComp, for
which we paid M-I $7.1 million in cash and issued to M-I a
$4.0 million subordinated note bearing interest at 5% per
annum. As a result, we now own 100% of AirComp.
On May 1, 2005, we acquired 100% of the outstanding capital
stock of Capcoil Tubing Services, Inc., or Capcoil, for
$2.7 million in cash, 168,161 shares of our common stock
and the payment or assumption of approximately $1.3 million
of debt. Capcoil, located in Kilgore, Texas, is engaged in
downhole well servicing by providing coil tubing services to
enhance production from existing wells. Goodwill of $184,000 and
other identifiable intangible assets of $1.4 million were
recorded in connection with the acquisition.
F-55
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
On April 1, 2005, we acquired 100% of the outstanding stock
of Delta Rental Service, Inc., or Delta, for $4.6 million
in cash, 223,114 shares of our common stock and two promissory
notes totaling $350,000. The purchase price was allocated to
fixed assets and inventory. Delta, located in Lafayette,
Louisiana, is a rental tool company providing specialty rental
items to the oil and gas industry such as spiral heavy weight
drill pipe, test plugs used to test blow-out preventors, well
head retrieval tools, spacer spools and assorted handling tools.
These acquisitions were accounted for using the purchase method
of accounting. The results of operations of the acquired
entities since the date of acquisition are included in our
consolidated condensed income statement. The following unaudited
pro forma consolidated summary financial information illustrates
the effects of the acquisition of Rogers, Specialty, WT, the
minority interest in AirComp, Capcoil and Delta as if the
acquisitions had occurred as of January 1, 2005, based on
the historical statements of operations (in thousands, except
per share amounts).
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three | |
|
For the Six | |
|
|
Months Ended | |
|
Months Ended | |
|
|
June 30, | |
|
June 30, | |
|
|
| |
|
| |
|
|
2006 | |
|
2005 | |
|
2006 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
60,470 |
|
|
$ |
35,572 |
|
|
$ |
109,583 |
|
|
$ |
65,567 |
|
Operating income
|
|
|
15,871 |
|
|
|
7,369 |
|
|
|
24,510 |
|
|
|
10,834 |
|
Net income
|
|
|
9,594 |
|
|
|
4,307 |
|
|
|
13,910 |
|
|
|
5,322 |
|
Net income per common share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
$ |
0.53 |
|
|
$ |
0.31 |
|
|
$ |
0.79 |
|
|
$ |
0.37 |
|
|
Diluted
|
|
$ |
0.50 |
|
|
$ |
0.28 |
|
|
$ |
0.73 |
|
|
$ |
0.35 |
|
Note 3 Stock-Based Compensation
We adopted SFAS No. 123R, Share-Based Payment,
effective January 1, 2006. This statement requires all
share-based payments to employees, including grants of employee
stock options, to be recognized in the financial statements
based on their grant-date fair values. Compensation cost for
awards granted prior to, but not vested, as of January 1,
2006 would be based on the grant date attributes originally used
to value those awards for pro forma purposes under
SFAS No. 123. We adopted SFAS No. 123R using
the modified prospective transition method, utilizing the
Black-Scholes option pricing model for the calculation of the
fair value of our employee stock options. Under the modified
prospective method, we record compensation cost related to
unvested stock awards as of December 31, 2005 by
recognizing the unamortized grant date fair value of these
awards over the remaining vesting periods of those awards with
no change in historical reported earnings. We estimated
forfeiture rates for the first six months of 2006 based on our
historical experience.
The Black-Scholes model incorporates assumptions to value
stock-based awards. The risk-free rate of interest is the
related U.S. Treasury yield curve for periods within the
expected term of the option at the time of grant. The dividend
yield on our common stock is assumed to be zero as we have
historically not paid dividends and have no current plans to do
so in the future. The expected volatility is based on historical
volatility of our common stock.
F-56
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
Prior to January 1, 2006, we accounted for our stock-based
compensation using Accounting Principle Board Opinion
No. 25. Under APB No. 25, compensation expense is
recognized for stock options with an exercise price that is less
than the market price on the grant date of the option. For stock
options with exercise prices at or above the market value of the
stock on the grant date, we adopted the disclosure-only
provisions of SFAS No. 123, Accounting For
Stock-Based Compensation. We also adopted the
disclosure-only provisions of SFAS No. 123 for the
stock options granted to our employees and directors.
Accordingly, no compensation cost was recognized under APB
No. 25. Our net income for the three and six months ended
June 30, 2006 includes approximately $836,000 and
$1,778,000 of compensation costs related to share-based
payments. As of June 30, 2006 there is $2.3 million of
unrecognized compensation expense related to non-vested stock
option grants. We expect approximately $1.5 million to be
recognized over the remainder of 2006 and approximately $860,000
to be recognized in 2007.
A summary of our stock option activity and related information
as of June 30, 2006 is as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted | |
|
Weighted- | |
|
|
|
|
Shares | |
|
Average | |
|
Average | |
|
Aggregate | |
|
|
Under | |
|
Exercise | |
|
Contractual | |
|
Intrinsic Value | |
|
|
Option | |
|
Price | |
|
Life (Years) | |
|
(millions) | |
|
|
| |
|
| |
|
| |
|
| |
Balance at beginning of period
|
|
|
2,860,867 |
|
|
$ |
5.10 |
|
|
|
|
|
|
|
|
|
Granted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Canceled
|
|
|
(38,333 |
) |
|
|
4.52 |
|
|
|
|
|
|
|
|
|
Exercised
|
|
|
(1,217,999 |
) |
|
|
3.43 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding at end of period
|
|
|
1,604,535 |
|
|
|
6.39 |
|
|
|
8.74 |
|
|
$ |
11.6 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Exercisable at end of period
|
|
|
782,702 |
|
|
|
5.34 |
|
|
|
8.46 |
|
|
$ |
6.5 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The aggregate intrinsic value in the table above represents the
total pre-tax intrinsic value (the difference between the
closing price of our common stock on the last trading day of the
second quarter of 2006 and the exercise price, multiplied by the
number of in-the-money options) that would have been received by
the option holders had all option holders exercised their
options on June 30, 2006. The total intrinsic value of
options exercised during the three and six months ended
June 30, 2006 was $15.6 and $16.2 million,
respectively. The total cash received from option exercises
during the three and six months ended June 30, 2006 was
$4.0 and $4.2 million, respectively.
F-57
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
No options were granted in the first six months of 2006. The
following summarizes the assumptions used in the June 30,
2005 Black-Scholes model:
|
|
|
|
|
|
|
|
|
|
|
For the Three | |
|
For the Six | |
|
|
Months Ended | |
|
Months Ended | |
|
|
June 30, 2005 | |
|
June 30, 2005 | |
|
|
| |
|
| |
Expected dividend yield
|
|
|
|
|
|
|
|
|
Expected price volatility
|
|
|
89.91 |
% |
|
|
98.65 |
% |
Risk-free interest rate
|
|
|
6.25 |
% |
|
|
6.63 |
% |
Expected life of options
|
|
|
7 years |
|
|
|
7 years |
|
Weighted average fair value of options
|
|
|
|
|
|
|
|
|
granted at market value
|
|
$ |
4.01 |
|
|
$ |
3.12 |
|
The following table illustrates the pro-forma effect on net
income and net income per share for the three and six months
ended June 30, 2005 had we applied the fair value
recognition provisions of SFAS No. 123R (in thousands,
except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months | |
|
Six Months | |
|
|
|
|
| |
|
| |
|
|
|
|
Ended June 30, | |
|
|
|
|
| |
|
|
|
|
2005 | |
|
2005 | |
|
|
|
|
| |
|
| |
Net income: As reported
|
|
|
|
|
|
$ |
1,769 |
|
|
$ |
3,336 |
|
Less total stock based employee compensation expense determined
under fair value based method for all awards net of tax related
effects
|
|
|
|
|
|
|
(836 |
) |
|
|
(1,505 |
) |
|
|
|
|
|
|
|
|
|
|
Pro forma net income
|
|
|
|
|
|
$ |
933 |
|
|
$ |
1,831 |
|
|
|
|
|
|
|
|
|
|
|
Net income per share:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
As reported |
|
|
$ |
0.13 |
|
|
$ |
0.24 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma |
|
|
$ |
0.07 |
|
|
$ |
0.13 |
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
As reported |
|
|
$ |
0.12 |
|
|
$ |
0.22 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma |
|
|
$ |
0.06 |
|
|
$ |
0.12 |
|
|
|
|
|
|
|
|
|
|
|
Note 4 Income Per Common Share
We compute income per common share in accordance with the
provisions of SFAS No. 128, Earnings Per Share.
SFAS No. 128 requires companies with complex capital
structures to present basic and diluted earnings per share.
Basic earnings per share are computed on the basis of the
weighted average number of shares of common stock outstanding
during the period. Diluted earnings per share is similar to
basic earnings per share, but presents the dilutive effect on a
per share basis of potential common shares (e.g., convertible
preferred stock, stock options, etc.) as if they had been
converted.
F-58
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
Potential dilutive common shares that have an anti-dilutive
effect (e.g., those that increase income per share) are excluded
from diluted earnings per share.
The components of basic and diluted earnings per share are as
follows (in thousands, except per share amounts):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three | |
|
For the Six | |
|
|
Months Ended | |
|
Months Ended | |
|
|
June 30, | |
|
June 30, | |
|
|
| |
|
| |
|
|
2006 | |
|
2005 | |
|
2006 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
Numerator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
9,594 |
|
|
$ |
1,769 |
|
|
$ |
14,018 |
|
|
$ |
3,336 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Denominator:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic earnings per share weighted average shares
outstanding
|
|
|
18,050 |
|
|
|
13,967 |
|
|
|
17,578 |
|
|
|
13,800 |
|
Effect of potentially dilutive common shares:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Warrants and employee and director stock options
|
|
|
1,090 |
|
|
|
1,136 |
|
|
|
1,422 |
|
|
|
1,100 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted earnings per share weighted average shares
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Outstanding and assumed conversions
|
|
|
19,140 |
|
|
|
15,103 |
|
|
|
19,000 |
|
|
|
14,900 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per share basic
|
|
$ |
0.53 |
|
|
$ |
0.13 |
|
|
$ |
0.80 |
|
|
$ |
0.24 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income per share diluted
|
|
$ |
0.50 |
|
|
$ |
0.12 |
|
|
$ |
0.74 |
|
|
$ |
0.22 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 5 Goodwill and Intangible Assets
In accordance with SFAS No. 142, Goodwill and Other
Intangible Assets, goodwill and indefinite-lived intangible
assets are not permitted to be amortized. Goodwill and
indefinite-lived intangible assets remain on the balance sheet
and are tested for impairment on an annual basis, or when there
is reason to suspect that their values may have been diminished
or impaired. Goodwill and indefinite-lived intangible assets
listed on the balance sheet totaled $12.4 million at
June 30, 2006 and December 31, 2005. Based on
impairment testing performed during 2005 pursuant to the
requirements of SFAS No. 142, these assets were not
impaired.
Intangible assets with definite lives continue to be amortized
over their estimated useful lives. Definite-lived intangible
assets that continue to be amortized under
SFAS No. 142 relate to our purchase of
customer-related and marketing-related intangibles. These
intangibles have useful lives ranging from five to ten years.
Amortization of intangible assets for the three and six months
ended June 30, 2006 were $429,000 and $813,000,
respectively, compared to $441,000 and $607,000, respectively
for the same periods last year. At June 30, 2006,
intangible assets totaled $7.1 million, net of
$3.4 million of accumulated amortization.
F-59
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
Note 6 Inventory
Inventory is comprised of the following (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
June 30, | |
|
December 31, | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Hammer bits
|
|
|
|
|
|
|
|
|
|
Finished goods
|
|
$ |
1,507 |
|
|
$ |
1,402 |
|
|
Work in process
|
|
|
1,616 |
|
|
|
787 |
|
|
Raw materials
|
|
|
2,429 |
|
|
|
233 |
|
|
|
|
|
|
|
|
|
|
Total hammer bits
|
|
|
5,552 |
|
|
|
2,422 |
|
Hammers
|
|
|
801 |
|
|
|
584 |
|
Drive pipe
|
|
|
572 |
|
|
|
666 |
|
Rental supplies
|
|
|
355 |
|
|
|
64 |
|
Chemicals
|
|
|
132 |
|
|
|
201 |
|
Coiled tubing and related inventory
|
|
|
1,278 |
|
|
|
1,145 |
|
Shop supplies and related inventory
|
|
|
1,207 |
|
|
|
863 |
|
|
|
|
|
|
|
|
|
|
Total inventory
|
|
$ |
9,897 |
|
|
$ |
5,945 |
|
|
|
|
|
|
|
|
Note 7 Debt
Our long-term debt consists of the following: (in thousands)
|
|
|
|
|
|
|
|
|
|
|
June 30, | |
|
December 31, | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Senior notes
|
|
$ |
160,000 |
|
|
$ |
|
|
Bank term loans
|
|
|
|
|
|
|
42,090 |
|
Revolving line of credit
|
|
|
|
|
|
|
6,400 |
|
Subordinated note payable to M-1 LLC
|
|
|
4,000 |
|
|
|
4,000 |
|
Subordinated seller note
|
|
|
|
|
|
|
3,031 |
|
Seller notes
|
|
|
900 |
|
|
|
850 |
|
Notes payable under non-compete agreements
|
|
|
443 |
|
|
|
698 |
|
Notes payable to former directors
|
|
|
32 |
|
|
|
96 |
|
Real estate loan
|
|
|
|
|
|
|
548 |
|
Equipment and vehicle installment notes
|
|
|
2,417 |
|
|
|
1,939 |
|
Insurance premium financing
|
|
|
1,553 |
|
|
|
|
|
Capital lease obligations
|
|
|
671 |
|
|
|
917 |
|
|
|
|
|
|
|
|
Total debt
|
|
|
170,016 |
|
|
|
60,569 |
|
Less: short-term debt and current maturities
|
|
|
4,059 |
|
|
|
5,632 |
|
|
|
|
|
|
|
|
Long-term debt obligations
|
|
$ |
165,957 |
|
|
$ |
54,937 |
|
|
|
|
|
|
|
|
F-60
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
Senior notes, bank loans and line of credit
agreements
On January 18, 2006, we closed on a private offering, to
qualified institutional buyers pursuant to Rule 144A under
the Securities Act of 1933, of $160.0 million aggregate
principal amount of our senior notes. The notes are due
January 15, 2014 and bear interest at 9.0%. The proceeds
were used to fund the acquisition of Specialty, to repay
existing debt and for general corporate purposes.
Prior to January 18, 2006, we were party to a July 2005
credit agreement that provided for the following senior secured
credit facilities:
|
|
|
|
|
A $13.0 million revolving line of credit. Borrowings were
limited to 85% of eligible accounts receivable plus 50% of
eligible inventory (up to a maximum of $2.0 million of
borrowings based on inventory). This line of credit was to be
used to finance working capital requirements and other general
corporate purposes, including the issuance of standby letters of
credit. Outstanding borrowings under this line of credit were
$6.4 million at a margin above prime and LIBOR rates plus
margin averaging approximately 8.1% as of December 31, 2005. |
|
|
|
Two term loans totaling $42.0 million. Outstanding
borrowings under these term loans were $42.0 million as of
December 31, 2005. These loans were at LIBOR rates plus a
margin which averages approximately 7.8% at December 31,
2005. |
Borrowings under the July 2005 credit facilities were to mature
in July 2007. Amounts outstanding under the term loans as of
July 2006 were to be repaid in monthly principal payments based
on a 48 month repayment schedule with the remaining balance
due at maturity. Additionally, during the second year, we were
to be required to prepay the remaining balance of the term loans
by 75% of excess cash flow, if any, after debt service and
capital expenditures. The interest rate payable on borrowings
was based on a margin over the London Interbank Offered Rate,
referred to as LIBOR, or the prime rate, and there was a 0.5%
fee on the undrawn portion of the revolving line of credit. The
margin over LIBOR was to increase by 1.0% in the second year.
All amounts outstanding under our July 2005 credit agreement
were paid off with the proceeds of our senior notes offering on
January 18, 2006. On January 18, 2006, we also
executed an amended and restated credit agreement which provides
for a $25.0 million revolving line of credit with a
maturity of January 2010. Our January 2006 amended and restated
credit agreement contains customary events of default and
financial covenants and limits our ability to incur additional
indebtedness, make capital expenditures, pay dividends or make
other distributions, create liens and sell assets. Our
obligations under the January 2006 amended and restated credit
agreement are secured by substantially all of our assets.
Notes payable and real estate loan
On July 11, 2005, we acquired from M-I its 45% equity
interest in AirComp and the subordinated note in the principal
amount of $4.8 million issued by AirComp, for which we paid
M-I $7.1 million in cash and issued a new $4.0 million
subordinated note bearing interest at 5% per annum. The
subordinated note issued to M-I requires quarterly interest
payments and the principal amount is due October 9, 2007.
Contingent upon a future equity offering, the subordinated note
is convertible into up
F-61
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
to 700,000 shares of our common stock at a conversion price
equal to the market value of the common stock at the time of
conversion. This note was repaid from the proceeds of our
offering of $95.0 million of 9.0% senior notes, which we
completed in August 2006.
As of December 31, 2005, Allis-Chalmers Tubular Services
Inc., or Tubular, had a subordinated note outstanding and
payable to Jens Mortensen, the seller of Tubular and one of our
former directors, in the amount of $4.0 million with a
fixed interest rate of 7.5%. Interest was payable quarterly and
the final maturity of the note was January 31, 2006. The
subordinated note was subordinated to the rights of our bank
lenders. The balance of this subordinated note was repaid in
full in January 2006 with proceeds from our senior notes
offering.
As part of the acquisition of Mountain Compressed Air Inc., or
Mountain Air, in 2001, we issued a note to the sellers of
Mountain Air in the original amount of $2.2 million
accruing interest at a rate of 5.75% per annum. The note was
reduced to $1.5 million as a result of the settlement of a
legal action against the sellers in 2003. In March 2005, we
reached an agreement with the sellers and holders of the note as
a result of an action brought against us by the sellers. Under
the terms of the agreement, we paid the holders of the note
$1.0 million in cash, and agreed to pay an additional
$350,000 on June 1, 2006, and an additional $150,000 on
June 1, 2007, in settlement of all claims. At June 30,
2006 and December 31, 2005 the outstanding amounts due were
$150,000 and $500,000, respectively.
In connection with the purchase of Delta, we issued to the
sellers a note in the amount of $350,000. The note bore interest
at 2% and the principal and accrued interest was repaid on its
maturity of April 1, 2006. In connection with the
acquisition of Rogers, we issued to the seller a note in the
amount of $750,000. The note bears interest at 5% and is due
April 3, 2009.
In connection with the purchase of Tubular, we agreed to pay a
total of $1.2 million to Mr. Mortensen in exchange for
a non-compete agreement. Monthly payments of $20,576 are due
under this agreement through January 31, 2007. In
connection with the purchase of Safco-Oil Field Products, Inc.,
or Safco, we also agreed to pay a total of $150,000 to the
sellers in exchange for a non-compete agreement. We are required
to make annual payments of $50,000 through September 30,
2007. In connection with the purchase of Capcoil, we agreed to
pay a total of $500,000 to two management employees in exchange
for non-compete agreements. We are required to make annual
payments of $110,000 through May 2008. Total amounts due under
these non-compete agreements at June 30, 2006 and
December 31, 2005 were $443,000 and $698,000, respectively.
In 2000 we compensated directors, including current directors
Nederlander and Toboroff, who served on the board of directors
from 1989 to March 31, 1999 without compensation, by
issuing promissory notes totaling $325,000. The notes bear
interest at the rate of 5.0%. At June 30, 2006 and
December 31, 2005, the principal and accrued interest on
these notes totaled approximately $32,000 and $96,000,
respectively.
We also had a real estate loan which was payable in equal
monthly installments of $4,344 with the remaining outstanding
balance due on January 1, 2010. The loan had a floating
interest rate based on prime plus 2.0%. The outstanding
principal balance was $548,000 at December 31, 2005. The
balance of this loan was repaid in full in January 2006 with
proceeds from our senior notes offering.
F-62
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
Other debt
We have various equipment financing loans with interest rates
ranging from 5% to 8.2% and terms ranging from 2 to
5 years. As of June 30, 2006 and December 31,
2005, the outstanding balances for equipment financing loans
were $2.4 million and $1.9 million, respectively. In
April 2006, we obtained an insurance premium financing in the
amount of $1.9 million with a fixed interest rate of 5.6%.
Under terms of the agreement, amounts outstanding are paid over
a 10 month repayment schedule. The outstanding balance of
this note was approximately $1.6 million as of
June 30, 2006. We also have various capital leases with
terms that expire in 2008. As of June 30, 2006 and
December 31, 2005, amounts outstanding under capital leases
were $671,000 and $917,000, respectively. In January 2006, we
prepaid $350,000 of the outstanding equipment loans with
proceeds from our senior notes offering.
Note 8 Stockholders Equity
We issued 125,285 shares of our common stock in relation to the
Rogers acquisition (see Note 2). We also had options
and warrants exercised in the first six months of 2006, which
resulted in 1,531,441 shares of our common stock being issued
for approximately $5.0 million. We recognized approximately
$1.8 million of compensation expense related to stock
options in the first six months of 2006 that was recorded as
additional paid in capital (see Note 3).
Note 9 Supplemental Cash Flow Information
|
|
|
|
|
|
|
|
|
|
|
|
For the Six | |
|
|
Months Ended | |
|
|
June 30, | |
|
|
| |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Cash paid for interest and income taxes:
|
|
|
|
|
|
|
|
|
|
Interest
|
|
$ |
832 |
|
|
$ |
1,166 |
|
|
Income taxes
|
|
$ |
2,063 |
|
|
$ |
329 |
|
Noncash activities:
|
|
|
|
|
|
|
|
|
|
Insurance premium financed
|
|
$ |
1,933 |
|
|
$ |
|
|
|
Common stock issued for acquisition of
|
|
|
|
|
|
|
|
|
|
business
|
|
$ |
1,650 |
|
|
$ |
|
|
|
Note payable issued for acquisition of
|
|
|
|
|
|
|
|
|
|
business
|
|
$ |
750 |
|
|
$ |
|
|
|
Non-compete payable in the future
|
|
$ |
150 |
|
|
$ |
|
|
Note 10 Segment Information
At June 30, 2006, we had five operating segments including
Directional Drilling Services (Strata and Target), Rental Tools,
Casing and Tubing Services (Tubular Service and Rogers),
Compressed Air Drilling Services (AirComp) and Production
Services. All of the segments provide services to the energy
F-63
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
industry. The revenues, operating income (loss), depreciation
and amortization, capital expenditures and assets of each of the
reporting segments, plus the corporate function, are reported
below (in thousands):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three | |
|
For the Six | |
|
|
Months Ended | |
|
Months Ended | |
|
|
June 30, | |
|
June 30, | |
|
|
| |
|
| |
|
|
2006 | |
|
2005 | |
|
2006 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
18,315 |
|
|
$ |
10,934 |
|
|
$ |
33,369 |
|
|
$ |
20,835 |
|
|
Rental tools
|
|
|
12,707 |
|
|
|
1,566 |
|
|
|
23,128 |
|
|
|
1,940 |
|
|
Casing and tubing services
|
|
|
14,569 |
|
|
|
3,933 |
|
|
|
24,028 |
|
|
|
7,493 |
|
|
Compressed air drilling services
|
|
|
10,949 |
|
|
|
4,866 |
|
|
|
20,048 |
|
|
|
9,047 |
|
|
Production services
|
|
|
3,930 |
|
|
|
2,289 |
|
|
|
6,925 |
|
|
|
3,607 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
60,470 |
|
|
$ |
23,588 |
|
|
$ |
107,498 |
|
|
$ |
42,922 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Three | |
|
For the Six | |
|
|
Months Ended | |
|
Months Ended | |
|
|
June 30, | |
|
June 30, | |
|
|
| |
|
| |
|
|
2006 | |
|
2005 | |
|
2006 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
Operating Income (Loss):
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
4,367 |
|
|
$ |
1,495 |
|
|
$ |
6,972 |
|
|
$ |
3,373 |
|
|
Rental tools
|
|
|
7,308 |
|
|
|
405 |
|
|
|
12,306 |
|
|
|
326 |
|
|
Casing and tubing services
|
|
|
4,314 |
|
|
|
1,354 |
|
|
|
6,165 |
|
|
|
2,679 |
|
|
Compressed air drilling services
|
|
|
3,204 |
|
|
|
1,002 |
|
|
|
5,441 |
|
|
|
1,529 |
|
|
Production services
|
|
|
341 |
|
|
|
36 |
|
|
|
618 |
|
|
|
(2 |
) |
|
General corporate
|
|
|
(3,663 |
) |
|
|
(1,378 |
) |
|
|
(6,998 |
) |
|
|
(2,744 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
15,871 |
|
|
$ |
2,914 |
|
|
$ |
24,504 |
|
|
$ |
5,161 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and Amortization:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
359 |
|
|
$ |
207 |
|
|
$ |
648 |
|
|
$ |
357 |
|
|
Rental tools
|
|
|
1,715 |
|
|
|
176 |
|
|
|
3,386 |
|
|
|
265 |
|
|
Casing and tubing services
|
|
|
1,069 |
|
|
|
468 |
|
|
|
1,768 |
|
|
|
908 |
|
|
Compressed air drilling services
|
|
|
731 |
|
|
|
422 |
|
|
|
1,415 |
|
|
|
870 |
|
|
Production services
|
|
|
299 |
|
|
|
189 |
|
|
|
592 |
|
|
|
325 |
|
|
General corporate
|
|
|
321 |
|
|
|
56 |
|
|
|
622 |
|
|
|
101 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
4,494 |
|
|
$ |
1,518 |
|
|
$ |
8,431 |
|
|
$ |
2,826 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Capital Expenditures:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
707 |
|
|
$ |
937 |
|
|
$ |
3,405 |
|
|
$ |
1,200 |
|
|
Rental tools
|
|
|
417 |
|
|
|
7 |
|
|
|
1,101 |
|
|
|
7 |
|
|
Casing and tubing services
|
|
|
4,373 |
|
|
|
217 |
|
|
|
5,500 |
|
|
|
1,857 |
|
|
Compressed air drilling services
|
|
|
792 |
|
|
|
1,147 |
|
|
|
3,016 |
|
|
|
1,926 |
|
|
Production services
|
|
|
365 |
|
|
|
253 |
|
|
|
1,046 |
|
|
|
290 |
|
|
General corporate
|
|
|
6 |
|
|
|
174 |
|
|
|
178 |
|
|
|
183 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
6,660 |
|
|
$ |
2,735 |
|
|
$ |
14,246 |
|
|
$ |
5,463 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-64
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
As of | |
|
|
| |
|
|
June 30, | |
|
December 31, | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Goodwill:
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
4,168 |
|
|
$ |
4,168 |
|
|
Rental tools
|
|
|
|
|
|
|
|
|
|
Casing and tubing services
|
|
|
3,673 |
|
|
|
3,673 |
|
|
Compressed air drilling services
|
|
|
3,950 |
|
|
|
3,950 |
|
|
Production services
|
|
|
626 |
|
|
|
626 |
|
|
General corporate
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
12,417 |
|
|
$ |
12,417 |
|
|
|
|
|
|
|
|
Assets:
|
|
|
|
|
|
|
|
|
|
Directional drilling services
|
|
$ |
28,496 |
|
|
$ |
20,960 |
|
|
Rental tools
|
|
|
105,994 |
|
|
|
8,034 |
|
|
Casing and tubing services
|
|
|
67,984 |
|
|
|
45,351 |
|
|
Compressed air drilling services
|
|
|
49,502 |
|
|
|
46,045 |
|
|
Production services
|
|
|
13,853 |
|
|
|
12,282 |
|
|
General corporate
|
|
|
14,857 |
|
|
|
4,683 |
|
|
|
|
|
|
|
|
|
|
$ |
280,686 |
|
|
$ |
137,355 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the | |
|
For the | |
|
|
Three Months | |
|
Six Months | |
|
|
Ended June 30, | |
|
Ended June 30, | |
|
|
| |
|
| |
|
|
2006 | |
|
2005 | |
|
2006 | |
|
2005 | |
|
|
| |
|
| |
|
| |
|
| |
Revenues:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
$ |
58,572 |
|
|
$ |
21,832 |
|
|
$ |
103,662 |
|
|
$ |
39,393 |
|
|
International
|
|
|
1,898 |
|
|
|
1,756 |
|
|
|
3,836 |
|
|
|
3,529 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
60,470 |
|
|
$ |
23,588 |
|
|
$ |
107,498 |
|
|
$ |
42,922 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 11 Legal Matters
We are named from time to time in legal proceedings related to
our activities prior to our bankruptcy in 1988. However, we
believe that we were discharged from liability for all such
claims in the bankruptcy and believe the likelihood of a
material loss relating to any such legal proceeding is remote.
We are also involved in various other legal proceedings in the
ordinary course of business. The legal proceedings are at
different stages; however, we believe that the likelihood of
material loss relating to any such legal proceeding is remote.
Note 12 Subsequent Events
On August 8, 2006, we entered into an amendment to our
amended and restated credit agreement dated as of
January 18, 2006. The amendment, among other things, amends
the credit agreement to (a) allow us to (i) issue and
sell $95.0 million aggregate principal amount of our 9.0%
senior notes due 2014 and (ii) issue and sell 3,450,000
shares of our common stock, (b) allow us to use the net
proceeds
F-65
ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
from the senior notes offering and the public offering to
purchase all the outstanding capital stock of DLS Drilling
Logistics and Services Corporation, or DLS, (c) exclude
certain existing indebtedness and investments of DLS and
investments and indebtedness related to the DLS Acquisition from
the covenants contained in the Credit Agreement and
(d) increase the amount of permitted lease obligations and
capital expenditures.
On August 8, 2006, we priced a public offering of
3.0 million shares of our common stock at $14.50 per share.
We have granted the underwriters a 30-day option to purchase up
to an additional 450,000 shares to cover over-allotments, if
any. On August 14, 2006, we closed the common stock
offering and the underwriters elected to exercise the
over-allotment option in full.
We also priced a private offering of $95.0 million
aggregate principal amount of 9.0% senior notes on
August 8, 2006. The notes were sold to investors at a price
of 100% of the principal amount thereof, plus accrued interest
from July 15, 2006. Fixed interest on the notes will be
payable on January 15 and July 15 of each year, beginning on
January 15, 2007 and the notes mature on January 15,
2014. The sale of the notes closed on August 14, 2006.
On August 14, 2006, we completed the acquisition of all of
the outstanding capital stock of DLS. The purchase price of DLS
consisted of $93.7 million in cash, 2.5 million shares
of our common stock and approximately $8.6 million of
assumed debt. DLS currently operates a fleet of 51 rigs,
including 20 drilling rigs, 18 workover rigs and 12 pulling rigs
in Argentina and one drilling rig in Bolivia.
In May of 2006, we filed a registration statement for the
offering of common stock described above to fund a portion of
the cash purchase price of DLS. We ultimately raised
approximately $47.0 million from such registered stock
offering and applied all such amount toward the cash component
of the purchase price of DLS. In August 2006, we also raised
approximately $92.7 million through the issuance of
additional 9.0% senior notes, and we applied a portion of such
amount to the payment of the remainder of the cash component of
the purchase price for DLS.
As part of the DLS acquisition, Carlos Alberto Bulgheroni and
Alejandro Pedro Bulgheroni have joined our board of directors,
filling vacancies created by the resignations of Jens H.
Mortensen, Jr. and Thomas O. Whitener, Jr.
F-66
INDEPENDENT AUDITORS REPORT
To the Stockholders
Delta Rental Service, Inc.
Scott, Louisiana
We have audited the accompanying Balance Sheets of Delta Rental
Service, Inc. (a Louisiana corporation) as of December 31,
2004 and 2003 and the related Statements of Income, Retained
Earnings and Cash Flows for the years then ended. These
financial statements are the responsibility of the
Companys management. Our responsibility is to express an
opinion on these financial statements based on our audits.
We conducted our audits in accordance with auditing standards
generally accepted in the United States of America. Those
standards require that we plan and perform the audits to obtain
reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in
the financial statements. An audit also includes assessing the
accounting principles used and significant estimates made by
management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a
reasonable basis for our opinion.
In our opinion, the financial statements referred to above
present fairly, in all material respects, the financial position
of Delta Rental Service, Inc. as of December 31, 2004 and
2003 and the results of their operations and cash flows for the
years then ended in conformity with accounting principles
generally accepted in the United States of America.
|
|
|
|
/s/ |
WRIGHT, MOORE, DEHART, |
|
|
|
DUPUIS & HUTCHINSON, L.L.C. |
|
|
|
Certified Public Accountants |
Lafayette, Louisiana
March 23, 2005
F-67
DELTA RENTAL SERVICE, INC.
BALANCE SHEETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
ASSETS |
CURRENT ASSETS
|
|
|
|
|
|
|
|
|
|
Cash
|
|
$ |
891,338 |
|
|
$ |
705,553 |
|
|
Accounts Receivable
|
|
|
1,095,587 |
|
|
|
713,929 |
|
|
Prepaid Insurance
|
|
|
13,838 |
|
|
|
14,067 |
|
|
Prepaid Income Taxes
|
|
|
|
|
|
|
51,411 |
|
|
Current Deferred Tax Asset
|
|
|
|
|
|
|
77,595 |
|
|
|
|
|
|
|
|
|
Employee Advances
|
|
|
|
|
|
|
|
|
|
|
Total Current Assets
|
|
|
2,000,763 |
|
|
|
1,562,555 |
|
|
|
|
|
|
|
|
PROPERTY AND EQUIPMENT
|
|
|
|
|
|
|
|
|
|
Office Equipment
|
|
|
33,624 |
|
|
|
32,407 |
|
|
Rental Equipment
|
|
|
3,699,987 |
|
|
|
3,341,816 |
|
|
Transportation Equipment
|
|
|
144,260 |
|
|
|
144,260 |
|
|
Yard Equipment
|
|
|
77,211 |
|
|
|
77,211 |
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
3,955,082 |
|
|
|
3,595,694 |
|
|
Less: Accumulated Depreciation
|
|
|
(2,610,143 |
) |
|
|
(2,307,864 |
) |
|
|
|
|
|
|
|
|
|
|
Net Property and Equipment
|
|
|
1,344,939 |
|
|
|
1,287,830 |
|
OTHER ASSETS
|
|
|
|
|
|
|
|
|
|
Cash Surrender Value of Life Insurance
|
|
|
38,261 |
|
|
|
35,446 |
|
|
|
|
|
|
|
|
|
|
Total Other Assets
|
|
|
38,261 |
|
|
|
35,446 |
|
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS
|
|
$ |
3,383,963 |
|
|
$ |
2,885,831 |
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of this statement.
F-68
DELTA RENTAL SERVICE, INC.
BALANCE SHEETS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
LIABILITIES AND STOCKHOLDERS EQUITY |
CURRENT LIABILITIES
|
|
|
|
|
|
|
|
|
|
Accounts Payable
|
|
$ |
53,949 |
|
|
$ |
40,829 |
|
|
Payroll Liabilities Payable
|
|
|
17,157 |
|
|
|
16,063 |
|
|
Sales Tax Payable
|
|
|
12,308 |
|
|
|
3,487 |
|
|
Accrued Interest Expense
|
|
|
3,734 |
|
|
|
4,244 |
|
|
Income Taxes Payable
|
|
|
92,448 |
|
|
|
|
|
|
Current Portion of Stockholder Loan
|
|
|
93,994 |
|
|
|
87,674 |
|
|
|
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
273,590 |
|
|
|
152,297 |
|
|
|
|
|
|
|
|
LONG-TERM LIABILITIES
|
|
|
|
|
|
|
|
|
|
Stockholder Loan (Less Current Portion)
|
|
|
547,784 |
|
|
|
641,775 |
|
|
Long-Term Deferred Tax Liability
|
|
|
353,147 |
|
|
|
311,762 |
|
|
|
|
|
|
|
|
|
Stockholder Loan
|
|
|
|
|
|
|
|
|
|
|
Total Long-Term Liabilities
|
|
|
900,931 |
|
|
|
953,537 |
|
|
|
|
|
|
|
|
|
|
Total Liabilities
|
|
|
1,174,521 |
|
|
|
1,105,834 |
|
|
|
|
|
|
|
|
STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
Common Stock (No Par Value, 300,000 Shares Authorized,
27,083 Shares Issued and 8,333 Outstanding)
|
|
|
27,083 |
|
|
|
27,083 |
|
|
Additional Paid-In Capital
|
|
|
64,574 |
|
|
|
64,574 |
|
|
Retained Earnings
|
|
|
3,117,785 |
|
|
|
2,688,340 |
|
|
Less: Treasury Stock (18,750 Shares at Cost)
|
|
|
(1,000,000 |
) |
|
|
(1,000,000 |
) |
|
|
|
|
|
|
|
|
|
Total Stockholders Equity
|
|
|
2,209,442 |
|
|
|
1,779,997 |
|
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES AND STOCKHOLDERS EQUITY
|
|
$ |
3,383,963 |
|
|
$ |
2,885,831 |
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of this statement.
F-69
DELTA RENTAL SERVICE, INC.
STATEMENTS OF OPERATIONS
|
|
|
|
|
|
|
|
|
|
|
|
|
Twelve Months Ended | |
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
REVENUES
|
|
$ |
3,249,338 |
|
|
$ |
2,662,091 |
|
COST OF REVENUES
|
|
|
|
|
|
|
|
|
|
Direct
|
|
|
796,194 |
|
|
|
766,196 |
|
|
|
|
|
|
|
|
GROSS PROFIT
|
|
|
2,453,144 |
|
|
|
1,895,895 |
|
ADMINISTRATIVE EXPENSES
|
|
|
|
|
|
|
|
|
|
General and Administrative
|
|
|
1,798,414 |
|
|
|
1,926,173 |
|
|
Depreciation
|
|
|
30,061 |
|
|
|
31,678 |
|
|
|
|
|
|
|
|
|
|
Total Administrative Expenses
|
|
|
1,828,475 |
|
|
|
1,957,851 |
|
|
|
|
|
|
|
|
INCOME (LOSS) FROM OPERATIONS
|
|
|
624,669 |
|
|
|
(61,956 |
) |
|
|
|
|
|
|
|
OTHER INCOME (EXPENSES)
|
|
|
|
|
|
|
|
|
|
Interest Expense
|
|
|
(48,503 |
) |
|
|
(61,177 |
) |
|
Interest Income
|
|
|
4,064 |
|
|
|
2,234 |
|
|
Life Insurance Dividends
|
|
|
930 |
|
|
|
930 |
|
|
Gain on Sale of Assets
|
|
|
113,435 |
|
|
|
354,382 |
|
|
|
|
|
|
|
|
|
|
Total Other Income (Expenses)
|
|
|
69,926 |
|
|
|
296,369 |
|
|
|
|
|
|
|
|
INCOME BEFORE PROVISION FOR INCOME TAXES
|
|
|
694,595 |
|
|
|
234,413 |
|
|
|
|
|
|
|
|
PROVISION FOR INCOME TAXES
|
|
|
|
|
|
|
|
|
|
Current
|
|
|
146,170 |
|
|
|
|
|
|
Deferred
|
|
|
118,980 |
|
|
|
134,274 |
|
|
|
|
|
|
|
|
|
|
Total Income Tax Provision
|
|
|
265,150 |
|
|
|
134,274 |
|
|
|
|
|
|
|
|
NET INCOME
|
|
$ |
429,445 |
|
|
$ |
100,139 |
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of this statement.
F-70
DELTA RENTAL SERVICE, INC.
STATEMENTS OF RETAINED EARNINGS
|
|
|
|
|
|
|
|
|
|
|
Twelve Months Ended | |
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
BEGINNING BALANCE
|
|
$ |
2,688,340 |
|
|
$ |
2,588,201 |
|
NET INCOME
|
|
|
429,445 |
|
|
|
100,139 |
|
|
|
|
|
|
|
|
ENDING BALANCE
|
|
$ |
3,117,785 |
|
|
$ |
2,688,340 |
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of this statement.
F-71
DELTA RENTAL SERVICE, INC.
STATEMENTS OF CASH FLOWS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Twelve Months Ended | |
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
CASH FLOWS FROM OPERATING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
Net Income
|
|
$ |
429,445 |
|
|
$ |
100,139 |
|
|
Adjustments to Reconcile Net Income to Net Cash Provided By
Operating Activities:
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and Amortization
|
|
|
346,615 |
|
|
|
308,587 |
|
|
|
|
Gain on Sale of Assets
|
|
|
(113,435 |
) |
|
|
(354,382 |
) |
Change in Assets and Liabilities:
|
|
|
|
|
|
|
|
|
|
|
Accounts Receivable
|
|
|
(381,658 |
) |
|
|
(7,963 |
) |
|
|
Prepaid Expenses
|
|
|
51,640 |
|
|
|
62,610 |
|
|
|
Accounts Payable and Accrued Expenses
|
|
|
114,973 |
|
|
|
(29,129 |
) |
|
|
Deferred Taxes
|
|
|
118,980 |
|
|
|
134,274 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Adjustments
|
|
|
137,115 |
|
|
|
113,997 |
|
|
|
|
|
|
|
|
Net Cash Provided By Operating Activities
|
|
|
566,560 |
|
|
|
214,136 |
|
|
|
|
|
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
Purchase of Equipment
|
|
|
(480,371 |
) |
|
|
(781,152 |
) |
|
Proceeds from Sale of Assets
|
|
|
190,082 |
|
|
|
522,911 |
|
|
Cash Surrender Value Life Insurance
|
|
|
(2,815 |
) |
|
|
(2,816 |
) |
|
|
|
|
|
|
|
Net Cash Used In Investing Activities
|
|
|
(293,104 |
) |
|
|
(261,057 |
) |
|
|
|
|
|
|
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
Principal Payments on Treasury Stock Note
|
|
|
|
|
|
|
(506,036 |
) |
|
Proceeds From Long-Term Debt
|
|
|
|
|
|
|
|
|
|
Proceeds From Stockholder Note Payable
|
|
|
|
|
|
|
450,000 |
|
|
Principal Payments Stockholder Note Payable
|
|
|
(87,671 |
) |
|
|
(20,550 |
) |
|
|
|
|
|
|
|
Net Cash Used in Financing Activities
|
|
|
(87,671 |
) |
|
|
(76,586 |
) |
|
|
|
|
|
|
|
NET INCREASE (DECREASE) IN CASH
|
|
|
185,785 |
|
|
|
(123,507 |
) |
CASH AT BEGINNING OF YEAR
|
|
|
705,553 |
|
|
|
829,060 |
|
|
|
|
|
|
|
|
CASH AT END OF YEAR
|
|
$ |
891,338 |
|
|
$ |
705,553 |
|
|
|
|
|
|
|
|
SUPPLEMENTAL DISCLOSURES:
|
|
|
|
|
|
|
|
|
|
Interest Paid
|
|
$ |
49,013 |
|
|
$ |
84,650 |
|
|
|
|
|
|
|
|
|
Income Taxes Paid
|
|
$ |
2,311 |
|
|
$ |
37,460 |
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of this statement.
F-72
DELTA RENTAL SERVICE, INC.
NOTES TO FINANCIAL STATEMENTS
(A) Summary of Significant
Accounting Policies
NATURE OF BUSINESS Delta Rental Service, Inc. (the
Company) is incorporated in the State of Louisiana. The Company
leases pipe, tubulars and other equipment to the service
companies of the petroleum exploration and production industry.
The Companys facility is located in Scott, Louisiana, and
leases equipment to companies primarily in the Louisiana Gulf
Coast Region.
REPORTING PERIOD The Company typically reports its
financial position and results of operations based on its
federal income tax fiscal year end of March 31. The
accompanying financial statements present the Companys
financial position as of December 31, and the results of
operations and cash flows for the twelve months ended
December 31.
INCOME TAXES Income taxes are provided for the tax
effects of transactions reported in the financial statements and
consist of accrued taxes plus deferred taxes related primarily
to the differences between the bases of certain assets and
liabilities for financial and tax reporting. The deferred taxes
represent the future tax return consequences of those
differences, which will either be taxable or deductible when the
assets and liabilities are recovered or settled.
PROPERTY AND EQUIPMENT Property and equipment of the
Company are stated at cost. Expenditures for property and
equipment which substantially increase the useful lives of
existing assets are capitalized at cost and depreciated. Routine
expenditures for repairs and maintenance are expensed as
incurred.
Depreciation is provided principally on the straight-line method
over the estimated useful lives of the assets for financial
reporting purposes. For income tax purposes, depreciation is
computed by use of the Modified Accelerated Cost Recovery System
(MACRS).
CASH AND CASH EQUIVALENTS The Company considers all
highly liquid debt instruments purchased with an original
maturity of three months or less to be cash equivalents. The
Company had no cash equivalents at December 31, 2004 and
2003.
USE OF ESTIMATES The preparation of financial
statements in conformity with accounting principles generally
accepted in the United States of America requires management to
make estimates and assumptions that affect the reported amounts
of assets and liabilities and disclosure of contingent assets
and liabilities at the date of the financial statements and the
reported amounts of revenues and expenses during the reporting
period. Actual results could differ from those estimates.
ACCOUNTS RECEIVABLE The Company generally does not
require collateral, and the majority of its trade receivables
are unsecured. The carrying amount for accounts receivable
approximates fair value.
ADVERTISING Advertising costs are charged to
operations when incurred. Advertising expense for the twelve
month periods ended December 31, 2004 and 2003 was $3,272
and $1,884, respectively.
F-73
DELTA RENTAL SERVICE, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
(B) Concentration of Credit
Risk
The Company maintains cash balances at two separate financial
institutions. Accounts are insured by the Federal Deposit
Insurance Corporation up to $100,000 per institution.
Balances in excess of insured limits at December 31, 2004
and 2003 were $692,208 and $507,438 respectively.
(C) Accounts Receivable
The balance in Accounts Receivable is comprised of billed
invoices as well as unbilled rentals which crossed accounting
periods. The breakdown of accounts receivable at
December 31, is as follows:
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Billed Accounts Receivable
|
|
$ |
699,442 |
|
|
$ |
407,556 |
|
Accrued Unbilled Revenue
|
|
|
396,145 |
|
|
|
306,373 |
|
|
|
|
|
|
|
|
Total
|
|
$ |
1,095,587 |
|
|
$ |
713,929 |
|
|
|
|
|
|
|
|
(D) Income Taxes
Income tax expense consists of the following at December 31:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Current
|
|
|
|
|
|
|
|
|
|
Federal
|
|
$ |
128,548 |
|
|
$ |
|
|
|
States
|
|
|
17,622 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Income Tax Expense
|
|
|
146,170 |
|
|
|
|
|
Deferred
|
|
|
118,980 |
|
|
|
134,274 |
|
|
|
|
|
|
|
|
|
|
|
Total Income Tax Expense
|
|
$ |
265,150 |
|
|
$ |
134,274 |
|
|
|
|
|
|
|
|
The effective tax on pre-taxable income is approximately
34 percent federal and 6 percent for the various
states. The primary reason for the difference between the
effective tax rates and the statutory marginal rates is due to
various book to tax timing differences, and non-deductible
expenses for income tax purposes.
Deferred income taxes are a result of timing differences between
book and taxable incomes as well as net operating loss
carryforwards. The major timing differences for deferred income
taxes at December 31 are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Depreciation Timing Difference
|
|
$ |
882,867 |
|
|
$ |
779,405 |
|
Net Operating Loss Carry-Forward
|
|
|
|
|
|
|
(163,311 |
) |
Charitable Contribution Carryover
|
|
|
|
|
|
|
(30,678 |
) |
|
|
|
|
|
|
|
|
|
|
882,867 |
|
|
|
585,416 |
|
Blended Federal and State Rates
|
|
|
40 |
% |
|
|
40 |
% |
|
|
|
|
|
|
|
|
Deferred Income Tax Liability (Net)
|
|
$ |
353,147 |
|
|
$ |
234,167 |
|
|
|
|
|
|
|
|
F-74
DELTA RENTAL SERVICE, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
These amounts have been presented in the Companys
financial statements as follows:
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Current Deferred Tax Asset
|
|
$ |
|
|
|
$ |
(77,595 |
) |
Long-Term Deferred Tax Liability
|
|
|
353,147 |
|
|
|
311,762 |
|
|
|
|
|
|
|
|
Total
|
|
$ |
353,147 |
|
|
$ |
234,167 |
|
|
|
|
|
|
|
|
(E) Employee Benefit Plans
The Company adopted a profit sharing retirement plan for its
employees effective April 1, 1979. The plan was restated to
update its terms, provisions and conditions effective
April 1, 2003. The restated plan continues to be for the
exclusive benefit of the employees of the Company. An employee
is eligible to participate upon the completion of one year of
eligible service and the attainment of age 21. The Company
determines annually the amount of current or accumulated profits
to be contributed to the plan. The plan vests one hundred
percent (100%) after six or more years of continuing service.
Contributions to the plan for the twelve months ended
December 31, 2004 and 2003 were $147,744 and $133,382
respectively.
(F) Note Payable Stockholder
The Company has a note payable to the stockholder dated
August 29, 2003, payable in monthly installments of $3,955,
bearing interest at 6.982% per annum, due August 1,
2010. The balance at December 31, 2004 and 2003 is $641,778
and $729,449, respectively.
Future maturities on this note are as follows:
|
|
|
|
|
|
|
Twelve Months Ending December 31,
|
|
|
|
|
|
2005
|
|
$ |
93,994 |
|
|
2006
|
|
|
100,772 |
|
|
2007
|
|
|
108,038 |
|
|
2008
|
|
|
115,827 |
|
|
2009
|
|
|
124,178 |
|
|
Later
|
|
|
98,969 |
|
|
|
|
|
|
|
Total
|
|
$ |
641,778 |
|
|
|
|
|
(G) Compensated Absences
Employees of the Company are entitled to paid vacation and paid
sick days, depending on length of service. No unused vacation or
sick leave is payable to an employee upon separation. The
Companys policy is to recognize the costs of compensated
absences when actually paid to employees. Accordingly, no
accruals have been made.
F-75
DELTA RENTAL SERVICE, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
(H) Related Party
Transactions
The Companys operations are conducted in a facility owned
by its stockholders. The Company entered into a formal lease
agreement for the facilities on June 6, 2000. The lease
agreement requires rental payments of $6,000 per month and
expires on June 30, 2005. For the twelve month periods
ended December 31, 2004 and 2003, $72,000 per period
was paid to the stockholders for rent.
Minimum future lease payments under the lease are as follows:
|
|
|
|
|
Twelve Months Ending December 31,
|
|
|
|
2005
|
|
$36,000 |
|
|
|
|
|
Total
|
|
$36,000 |
|
|
|
(I) Major Customers
Customers comprising ten percent (10%) or more of the
Companys revenues or accounts receivable balances for the
periods ended December 31 are as follows:
For the twelve months ended December 31, 2003:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Percentage of | |
|
|
Sales | |
|
Percentage of | |
|
Total Accounts | |
|
|
Amount | |
|
Total Revenue | |
|
Receivable | |
|
|
| |
|
| |
|
| |
Customer A
|
|
$ |
488,589 |
|
|
|
18.35 |
% |
|
|
14.39 |
% |
Customer B
|
|
$ |
401,265 |
|
|
|
15.07 |
% |
|
|
9.85 |
% |
Customer C
|
|
$ |
296,570 |
|
|
|
11.14 |
% |
|
|
11.71 |
% |
Customer D
|
|
$ |
269,963 |
|
|
|
10.14 |
% |
|
|
9.61 |
% |
For the year ended December 31, 2004:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Percentage of | |
|
|
Sales | |
|
Percentage of | |
|
Total Accounts | |
|
|
Amount | |
|
Total Revenue | |
|
Receivable | |
|
|
| |
|
| |
|
| |
Customer A
|
|
$ |
549,678 |
|
|
|
16.92 |
% |
|
|
14.31 |
% |
Customer B
|
|
$ |
528,474 |
|
|
|
16.26 |
% |
|
|
22.51 |
% |
Customer C
|
|
$ |
329,160 |
|
|
|
10.13 |
% |
|
|
6.40 |
% |
Customer D
|
|
$ |
308,133 |
|
|
|
9.48 |
% |
|
|
13.15 |
% |
(J) Subsequent Events
Subsequent to the balance sheet date, but prior to the date of
this report, the Companys stockholders entered into a
purchase agreement whereby they have agreed to sale all of their
interest in the Company to a third-party. The sale is scheduled
to close in April, 2005.
F-76
DELTA RENTAL SERVICE, INC.
BALANCE SHEET
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
March 31, | |
|
|
2005 | |
|
|
| |
ASSETS |
CURRENT ASSETS
|
|
|
|
|
|
Cash
|
|
$ |
169,154 |
|
|
Accounts Receivable
|
|
|
936,156 |
|
|
Prepaid Insurance
|
|
|
|
|
|
Prepaid Income Taxes
|
|
|
|
|
|
Current Deferred Tax Asset
|
|
|
160,349 |
|
|
|
|
|
|
Employee Advances
|
|
|
|
|
|
|
|
|
Total Current Assets
|
|
|
1,265,659 |
|
|
|
|
|
|
PROPERTY AND EQUIPMENT
|
|
|
|
|
|
Office Equipment
|
|
|
33,624 |
|
|
Rental Equipment
|
|
|
3,739,342 |
|
|
Transportation Equipment
|
|
|
144,180 |
|
|
Yard Equipment
|
|
|
77,211 |
|
|
|
|
|
|
|
Total
|
|
|
3,994,357 |
|
|
Less: Accumulated Depreciation
|
|
|
(2,652,825 |
) |
|
|
|
|
|
|
|
|
Net Property and Equipment
|
|
|
1,341,532 |
|
|
|
|
|
|
OTHER ASSETS
|
|
|
|
|
|
Cash Surrender Value of Life Insurance
|
|
|
|
|
|
|
|
|
|
|
|
Total Other Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS
|
|
$ |
2,607,191 |
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY |
CURRENT LIABILITIES
|
|
|
|
|
|
Accounts Payable
|
|
$ |
31,630 |
|
|
Payroll Liabilities Payable
|
|
|
398 |
|
|
Sales Tax Payable
|
|
|
7,433 |
|
|
Accrued Insurance Payable
|
|
|
19,447 |
|
|
Accrued Interest Expense
|
|
|
|
|
|
Accrued Profit Sharing Payable
|
|
|
|
|
|
Income Taxes Payable
|
|
|
374,492 |
|
|
Note Payable Insurance
|
|
|
|
|
|
Current Portion of Stockholder Loan
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
433,400 |
|
|
|
|
|
|
LONG-TERM LIABILITIES
|
|
|
|
|
|
Stockholder Loan (Less Current Portion)
|
|
|
|
|
|
Long-Term Deferred Tax Liability
|
|
|
373,153 |
|
|
|
|
|
|
|
|
Total Long-Term Liabilities
|
|
|
373,153 |
|
|
|
|
|
|
|
|
Total Liabilities
|
|
|
806,553 |
|
|
|
|
|
|
STOCKHOLDERS EQUITY
|
|
|
|
|
|
Common Stock (No Par Value, 300,000 Shares Authorized,
27,083 Shares Issued and 8,333 Outstanding)
|
|
|
27,083 |
|
|
Additional Paid-In Capital
|
|
|
64,574 |
|
|
Retained Earnings
|
|
|
2,708,981 |
|
|
Less: Treasury Stock (18,750 Shares at Cost)
|
|
|
(1,000,000 |
) |
|
|
|
|
|
|
|
Total Stockholders Equity
|
|
|
1,800,638 |
|
|
|
|
|
TOTAL LIABILITIES AND STOCKHOLDERS EQUITY
|
|
$ |
2,607,191 |
|
|
|
|
|
F-77
DELTA RENTAL SERVICE, INC.
STATEMENTS OF OPERATIONS
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
|
March 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
REVENUES
|
|
$ |
820,769 |
|
|
$ |
744,811 |
|
COST OF REVENUES
|
|
|
|
|
|
|
|
|
|
Direct
|
|
|
203,271 |
|
|
|
265,230 |
|
|
|
|
|
|
|
|
GROSS PROFIT
|
|
|
617,498 |
|
|
|
479,581 |
|
ADMINISTRATIVE EXPENSES
|
|
|
|
|
|
|
|
|
|
General and Administrative
|
|
|
984,505 |
|
|
|
1,106,656 |
|
|
Depreciation
|
|
|
7,578 |
|
|
|
7,465 |
|
|
|
|
|
|
|
|
|
|
Total Administrative Expenses
|
|
|
992,083 |
|
|
|
1,114,121 |
|
|
|
|
|
|
|
|
LOSS FROM OPERATIONS
|
|
|
(374,585 |
) |
|
|
(634,540 |
) |
|
|
|
|
|
|
|
OTHER INCOME (EXPENSES)
|
|
|
|
|
|
|
|
|
|
Interest Expense
|
|
|
(10,937 |
) |
|
|
(13,166 |
) |
|
Interest Income
|
|
|
2,896 |
|
|
|
364 |
|
|
Gain on Sale of Assets
|
|
|
115,519 |
|
|
|
36,850 |
|
|
|
|
|
|
|
|
|
|
Total Other Income (Expenses)
|
|
|
107,478 |
|
|
|
24,048 |
|
|
|
|
|
|
|
|
LOSS BEFORE PROVISION FOR INCOME TAXES
|
|
|
(267,107 |
) |
|
|
(610,492 |
) |
|
|
|
|
|
|
|
PROVISION (BENEFIT) FOR INCOME TAXES
|
|
|
|
|
|
|
|
|
|
Current
|
|
|
|
|
|
|
|
|
|
Deferred
|
|
|
141,697 |
|
|
|
(221,825 |
) |
|
|
|
|
|
|
|
|
|
Total Income Tax Provision (Benefit)
|
|
|
141,697 |
|
|
|
(221,825 |
) |
|
|
|
|
|
|
|
NET LOSS
|
|
$ |
(408,804 |
) |
|
$ |
(388,667 |
) |
|
|
|
|
|
|
|
F-78
DELTA RENTAL SERVICE, INC.
STATEMENT OF RETAINED EARNINGS
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
|
March 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
BEGINNING BALANCE
|
|
$ |
3,117,785 |
|
|
$ |
2,688,340 |
|
NET LOSS
|
|
|
(408,804 |
) |
|
|
(388,667 |
) |
|
|
|
|
|
|
|
ENDING BALANCE
|
|
$ |
2,708,981 |
|
|
$ |
2,299,673 |
|
|
|
|
|
|
|
|
F-79
DELTA RENTAL SERVICE, INC.
STATEMENTS OF CASH FLOWS
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
|
March 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
CASH FLOWS FROM OPERATING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
Net Loss
|
|
$ |
(408,804 |
) |
|
$ |
(388,667 |
) |
|
Adjustments to Reconcile Net Income to Net Cash Provided By
Operating Activities:
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and Amortization
|
|
|
94,220 |
|
|
|
83,854 |
|
|
|
|
Gain on Sale of Assets
|
|
|
(115,519 |
) |
|
|
(36,850 |
) |
Change in Assets and Liabilities:
|
|
|
|
|
|
|
|
|
|
|
Accounts Receivable
|
|
|
159,431 |
|
|
|
(97,326 |
) |
|
|
Prepaid Expenses
|
|
|
13,838 |
|
|
|
(10,933 |
) |
|
|
Accounts Payable and Accrued Expenses
|
|
|
253,804 |
|
|
|
256,078 |
|
|
|
Deferred Taxes
|
|
|
(140,343 |
) |
|
|
(221,825 |
) |
|
|
|
|
|
|
|
|
|
|
|
Total Adjustments
|
|
|
265,431 |
|
|
|
(27,002 |
) |
|
|
|
|
|
|
|
Net Cash Used In Operating Activities
|
|
|
(143,373 |
) |
|
|
(415,669 |
) |
|
|
|
|
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
Purchase of Equipment
|
|
|
(151,956 |
) |
|
|
(40,557 |
) |
|
Proceeds from Sale of Assets
|
|
|
176,662 |
|
|
|
44,440 |
|
|
Cash Surrender Value Life Insurance
|
|
|
38,261 |
|
|
|
(473 |
) |
|
|
|
|
|
|
|
Net Cash Used In Investing Activities
|
|
|
62,967 |
|
|
|
3,410 |
|
|
|
|
|
|
|
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
Principal Payments Stockholder Note Payable
|
|
|
(641,778 |
) |
|
|
(21,349 |
) |
Net Cash Used in Financing Activities
|
|
|
(641,778 |
) |
|
|
(21,349 |
) |
|
|
|
|
|
|
|
NET DECREASE IN CASH
|
|
|
(722,184 |
) |
|
|
(433,608 |
) |
CASH AT BEGINNING OF PERIOD
|
|
|
891,338 |
|
|
|
705,553 |
|
|
|
|
|
|
|
|
CASH AT END OF PERIOD
|
|
$ |
169,154 |
|
|
$ |
271,945 |
|
|
|
|
|
|
|
|
SUPPLEMENTAL DISCLOSURES:
|
|
|
|
|
|
|
|
|
|
Interest Paid
|
|
$ |
7,203 |
|
|
$ |
13,166 |
|
|
|
|
|
|
|
|
|
Income Taxes Paid
|
|
$ |
|
|
|
$ |
|
|
|
|
|
|
|
|
|
|
Non-Cash Financing of Insurance Premiums
|
|
$ |
|
|
|
$ |
30,351 |
|
|
|
|
|
|
|
|
F-80
INDEPENDENT AUDITORS REPORT
To the Board of Directors
Capcoil Tubing Services, Inc.
P.O. Box 2280 Kilgore, Texas
We have audited the balance sheets of Capcoil Tubing Services,
Inc. (a Texas corporation), as of December 31, 2004 and
2003, and the related statements of operations and retained
earnings, and cash flows for the years then ended. These
financial statements are the responsibility of the
Corporations management. Our responsibility is to express
an opinion on these financial statements based on our audits.
We conducted our audits in accordance with auditing standards
generally accepted in the United States of America. Those
standards require that we plan and perform the audits to obtain
reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes consideration
of internal control over financial reporting as a basis for
designing audit procedures that are appropriate in the
circumstances, but not for the purpose of expressing an opinion
on the effectiveness of the Corporations internal control
over financial reporting. Accordingly, we express no such
opinion. An audit also includes examining, on a test basis,
evidence supporting the amounts and disclosures in the financial
statements, assessing the accounting principles used and
significant estimates made by management, as well as evaluating
the overall financial statement presentation. We believe that
our audits provide a reasonable basis for our opinion.
In our opinion, the financial statements referred to above
present fairly, in all material respects, the financial position
of Capcoil Tubing Services, Inc. as of December 31, 2004
and 2003, and the results of its operations and its cash flows
for the years then ended in conformity with accounting
principles generally accepted in the United States of America.
|
|
|
/s/ CURTIS BLAKELY & CO., PC |
|
|
Kilgore, Texas
March 16, 2005
F-81
CAPCOIL TUBING SERVICES, INC.
BALANCE SHEETS
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
ASSETS |
CURRENT ASSETS:
|
|
|
|
|
|
|
|
|
|
Cash and Cash Equivalents
|
|
$ |
348,674 |
|
|
$ |
45,857 |
|
|
Accounts Receivable
|
|
|
538,658 |
|
|
|
818,736 |
|
|
Inventory
|
|
|
386,685 |
|
|
|
384,431 |
|
|
Prepaid Expenses
|
|
|
107,703 |
|
|
|
92,306 |
|
|
|
|
|
|
|
|
|
|
TOTAL CURRENT ASSETS
|
|
|
1,381,720 |
|
|
|
1,341,330 |
|
|
|
|
|
|
|
|
PROPERTY AND EQUIPMENT:
|
|
|
|
|
|
|
|
|
|
Furniture, Fixtures and Equipment
|
|
|
11,343 |
|
|
|
5,870 |
|
|
Software
|
|
|
3,127 |
|
|
|
3,127 |
|
|
Production Equipment
|
|
|
2,078,897 |
|
|
|
1,709,196 |
|
|
Vehicles
|
|
|
172,720 |
|
|
|
107,442 |
|
|
Production Equipment Under Construction
|
|
|
94,332 |
|
|
|
-0- |
|
|
|
|
|
|
|
|
|
|
TOTAL PROPERTY AND EQUIPMENT
|
|
|
2,360,419 |
|
|
|
1,825,635 |
|
|
Less: Accumulated Depreciation
|
|
|
(433,800 |
) |
|
|
(221,451 |
) |
|
|
|
|
|
|
|
|
|
NET PROPERTY AND EQUIPMENT
|
|
|
1,926,619 |
|
|
|
1,604,184 |
|
|
|
|
|
|
|
|
OTHER ASSETS:
|
|
|
|
|
|
|
|
|
|
Organizational Costs
|
|
|
12,057 |
|
|
|
18,085 |
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS
|
|
$ |
3,320,396 |
|
|
$ |
2,963,599 |
|
|
|
|
|
|
|
|
(The accompanying notes are an integral part of these financial
statements.)
F-82
CAPCOIL TUBING SERVICES, INC.
BALANCE SHEETS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
LIABILITIES AND STOCKHOLDERS EQUITY |
CURRENT LIABILITIES:
|
|
|
|
|
|
|
|
|
|
Current Portion of Long-term Debt
|
|
$ |
445,924 |
|
|
$ |
431,452 |
|
|
Current Portion of Obligation Under Capital Lease
|
|
|
447 |
|
|
|
-0- |
|
|
Current Portion of Long-term Debt Related Party
|
|
|
22,824 |
|
|
|
-0- |
|
|
Accounts Payable Trade
|
|
|
383,762 |
|
|
|
891,508 |
|
|
Accrued Interest Payable
|
|
|
4,018 |
|
|
|
-0- |
|
|
Accrued Wages
|
|
|
6,400 |
|
|
|
-0- |
|
|
Short-term Borrowings
|
|
|
430,314 |
|
|
|
422,321 |
|
|
Short-term Borrowings Related Party
|
|
|
130,000 |
|
|
|
-0- |
|
|
|
|
|
|
|
|
|
|
TOTAL CURRENT LIABILITIES
|
|
|
1,423,689 |
|
|
|
1,745,281 |
|
|
|
|
|
|
|
|
LONG-TERM DEBT, LESS CURRENT MATURITIES:
|
|
|
|
|
|
|
|
|
|
Long-term Debt
|
|
|
471,451 |
|
|
|
451,262 |
|
|
Long-term Debt Related Party
|
|
|
31,213 |
|
|
|
-0- |
|
|
Obligation Under Capital Lease
|
|
|
2,880 |
|
|
|
-0- |
|
|
|
|
|
|
|
|
|
|
TOTAL LONG-TERM DEBT
|
|
|
505,544 |
|
|
|
451,262 |
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES
|
|
|
1,929,233 |
|
|
|
2,196,543 |
|
|
|
|
|
|
|
|
STOCKHOLDERS EQUITY:
|
|
|
|
|
|
|
|
|
|
Common Stock $1 Par Value
|
|
|
|
|
|
|
|
|
|
|
100,000 Shares Authorized
|
|
|
|
|
|
|
|
|
|
|
1,000 Shares Issued and Outstanding
|
|
|
600,000 |
|
|
|
600,000 |
|
|
Additional Paid-in Capital
|
|
|
50,000 |
|
|
|
50,000 |
|
|
Retained Earnings
|
|
|
741,163 |
|
|
|
117,056 |
|
|
|
|
|
|
|
|
|
|
TOTAL STOCKHOLDERS EQUITY
|
|
|
1,391,163 |
|
|
|
767,056 |
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES AND STOCKHOLDERS EQUITY
|
|
$ |
3,320,396 |
|
|
$ |
2,963,599 |
|
|
|
|
|
|
|
|
(The accompanying notes are an integral part of these financial
statements.)
F-83
CAPCOIL TUBING SERVICES, INC.
STATEMENTS OF OPERATIONS AND RETAINED EARNINGS
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
REVENUE
|
|
$ |
5,774,442 |
|
|
$ |
5,478,666 |
|
Cost of Sales and Services
|
|
|
4,371,316 |
|
|
|
4,523,702 |
|
|
|
|
|
|
|
|
Gross Profit
|
|
|
1,403,126 |
|
|
|
954,964 |
|
|
|
|
|
|
|
|
OPERATING EXPENSES:
|
|
|
|
|
|
|
|
|
|
General and Administrative
|
|
|
159,677 |
|
|
|
131,254 |
|
|
Depreciation
|
|
|
35,456 |
|
|
|
24,648 |
|
|
Insurance
|
|
|
228,112 |
|
|
|
186,125 |
|
|
Lease Expense
|
|
|
29,250 |
|
|
|
27,000 |
|
|
Salaries Administration
|
|
|
126,520 |
|
|
|
89,287 |
|
|
Taxes
|
|
|
126,222 |
|
|
|
68,838 |
|
|
Interest
|
|
|
73,782 |
|
|
|
51,380 |
|
|
|
|
|
|
|
|
|
|
TOTAL OPERATING EXPENSES
|
|
|
779,019 |
|
|
|
578,532 |
|
|
|
|
|
|
|
|
|
|
NET INCOME
|
|
|
624,107 |
|
|
|
376,432 |
|
|
|
RETAINED EARNINGS (DEFICIT) BEGINNING OF PERIOD
|
|
|
117,056 |
|
|
|
(259,376 |
) |
|
|
|
|
|
|
|
|
|
RETAINED EARNINGS END OF PERIOD
|
|
$ |
741,163 |
|
|
$ |
117,056 |
|
|
|
|
|
|
|
|
(The accompanying notes are an integral part of these financial
statements.)
F-84
CAPCOIL TUBING SERVICES, INC.
STATEMENTS OF CASH FLOWS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Years Ended | |
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
CASH FLOWS FROM OPERATING ACTIVITIES:
|
|
|
|
|
|
|
|
|
|
Net Income
|
|
$ |
624,107 |
|
|
$ |
376,432 |
|
|
Adjustments to Reconcile Net Income to Net Cash Provided by
Operating Activities:
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and Amortization
|
|
|
218,375 |
|
|
|
170,317 |
|
|
Change in Assets and Liabilities:
|
|
|
|
|
|
|
|
|
|
|
Accounts Receivable
|
|
|
280,078 |
|
|
|
(595,486 |
) |
|
|
Inventory
|
|
|
(428,090 |
) |
|
|
298,810 |
|
|
|
Prepaids
|
|
|
(15,395 |
) |
|
|
(32,465 |
) |
|
|
Accounts Payable and Accruals
|
|
|
(42,242 |
) |
|
|
95,417 |
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL ADJUSTMENTS
|
|
|
12,726 |
|
|
|
(63,407 |
) |
|
|
|
|
|
|
|
NET CASH PROVIDED BY OPERATING ACTIVITIES
|
|
|
636,833 |
|
|
|
313,025 |
|
|
|
|
|
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES:
|
|
|
|
|
|
|
|
|
|
Additions to Plant and Equipment
|
|
|
(462,998 |
) |
|
|
(541,551 |
) |
|
|
|
|
|
|
|
NET CASH USED IN INVESTING ACTIVITIES
|
|
|
(462,998 |
) |
|
|
(541,551 |
) |
|
|
|
|
|
|
|
CASH FLOWS FROM FINANCING ACTIVITIES:
|
|
|
|
|
|
|
|
|
|
Payments of Short-term Borrowings
|
|
|
(101,736 |
) |
|
|
(124,513 |
) |
|
Payments of Long-term Debt
|
|
|
(519,383 |
) |
|
|
(377,668 |
) |
|
Payments of Capital Lease Obligation
|
|
|
(89 |
) |
|
|
-0- |
|
|
Proceeds From Short-term Debt Borrowing
|
|
|
239,729 |
|
|
|
223,578 |
|
|
Proceeds From Long-term Debt Borrowing
|
|
|
510,461 |
|
|
|
441,265 |
|
|
Proceeds From Additional Paid-in Capital
|
|
|
-0- |
|
|
|
50,000 |
|
|
|
|
|
|
|
|
NET CASH PROVIDED BY FINANCING ACTIVITIES
|
|
|
128,982 |
|
|
|
212,662 |
|
|
|
|
|
|
|
|
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
|
|
|
302,817 |
|
|
|
(15,864 |
) |
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR
|
|
|
45,857 |
|
|
|
61,721 |
|
|
|
|
|
|
|
|
CASH AND CASH EQUIVALENTS AT END OF YEAR
|
|
$ |
348,674 |
|
|
$ |
45,857 |
|
|
|
|
|
|
|
|
(The accompanying notes are an integral part of these financial
statements.)
F-85
CAPCOIL TUBING SERVICES, INC.
NOTES TO FINANCIAL STATEMENTS
|
|
Note 1 |
Summary of Significant Accounting Policies: |
Basis of Presentation
The Corporation began business in 2001, and is engaged in the
business of oil and gas well servicing. The Corporation
currently provides coil tubing services with capabilities from
1/4
capillary tubing to 1 coil tubing. Services include the
ability to deliver and inject nitrogen into wells. Most of the
work is service work related to existing wells in the field, but
some work is performed in relation to drilling activity.
The preparation of financial statements in conformity with
accounting principles generally accepted in the United States of
America requires management to make estimates and assumptions
that affect the reported amounts in the financial statements and
accompanying notes. Actual results could differ from these
estimates. Among other things, estimates are used in accounting
for depreciation.
Revenue Recognition
Revenues and expenses are recorded when services are rendered
and expenses are incurred and collectibility is reasonably
assured. Customers are billed as services are rendered.
Cash and Cash Equivalents
For purposes of the Statement of Cash Flows, the Corporation
considers cash and cash equivalents to include cash on hand and
demand deposits.
Accounts Receivable
Trade receivables are reported in the balance sheets at
outstanding principal less any allowances for doubtful accounts.
Trade receivables are short-term and interest is not accrued.
Trade receivables are written off at the time they are deemed
uncollectible. An allowance for uncollectible trade receivables
is recorded when deemed appropriate based on a review of aged
receivables and expected recoveries. The allowance for doubtful
accounts was $-0- at December 31, 2004 and 2003.
Inventory
Inventories, which consist principally of (i) products
which are consumed in the Corporations services provided
to customers, (ii) spare parts for equipment used in
providing these services and (iii) manufactured components
and attachments for equipment used in providing services, are
stated primarily at the lower of weighted-average cost or
market. Cost primarily represents invoice costs. The Corporation
regularly reviews inventory quantities on hand.
Property and Equipment
Property and equipment is stated substantially at original cost.
Additions, replacements, and renewals of property determined to
be units of property are charged to the property and equipment
accounts. The replacement of property and equipment determined
not to be a unit of property and the cost of maintenance and
repairs are charged to operating expense. Property and equipment
is stated at
F-86
CAPCOIL TUBING SERVICES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
cost and when sold or retired, a gain or loss is recognized.
Depreciation expense is computed using the straight-line
composite method based on estimated service lives of the various
classes of depreciable property.
Property and equipment are reviewed for impairment whenever
events or circumstances indicate their carrying value may not be
recoverable. When such events or circumstances arise, an
estimate of the future undiscounted cash flows produced by the
asset, or the appropriate grouping of assets, is compared to the
assets carrying value to determine if any impairment
exists pursuant to the requirements of SFAS No. 144,
Accounting for the Impairment or Disposal of Long-Lived
Assets (SFAS No. 144). If the asset is
determined to be impaired, the impairment loss is measured based
on the excess of its carrying value over its fair value.
Internal Use Software
In accordance with Statement of Position (SOP) 98-1, the
Corporation capitalizes software developed or obtained for
internal use. These capitalized costs are included in property
and equipment. Initial operating system software is amortized
over the life of the associated hardware. Application software
is amortized over a useful life of three years.
Asset Retirement Obligations
Effective January 1, 2003, the Corporation adopted
SFAS No. 143, Accounting for Asset Retirement
Obligations. This statement provides the accounting for
the cost of legal obligations associated with the retirement of
long-lived assets. SFAS No. 143 requires that
companies recognize the fair value of a liability for asset
retirement obligations in the period in which the obligations
are incurred and capitalize that amount as part of the book
value of the long-lived asset. The Corporation has no legal
obligation to remove assets. Therefore, the adoption of
SFAS No. 143 did not have a material effect on the
Corporations financial statements.
Income Taxes
The Corporation is a Subchapter S Corporation under the
Internal Revenue Code. The taxable income or losses of the
Corporation are includable in the tax return of the stockholder
for federal income tax purposes. The Corporation is subject to
state income tax.
Deferred state income taxes should be recognized for the future
tax consequences attributable to differences between the
financial statement carrying amounts of existing assets and
liabilities and their respective tax bases. However, management
considers their amount to be immaterial and thus deferred state
income taxes are not recorded on the Corporations
financial statements.
|
|
Note 2 |
Organizational Costs: |
Organizational costs represent the unamortized balance of
organizational costs. The organizational costs were incurred in
2001 and are being amortized over 5 years. Amortization for
both 2004 and 2003 totaled $6,028.
F-87
CAPCOIL TUBING SERVICES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
|
|
Note 3 |
Property and Equipment: |
Net property and equipment at December 31, 2004 and 2003
was composed of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation | |
|
|
|
|
|
|
Rate (%) | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Furniture, fixtures, and equipment
|
|
|
20% |
|
|
$ |
11,343 |
|
|
$ |
5,870 |
|
Software
|
|
|
33% |
|
|
|
3,127 |
|
|
|
3,127 |
|
Production equipment
|
|
|
10% 20% |
|
|
|
2,078,897 |
|
|
|
1,709,196 |
|
Vehicles
|
|
|
20% |
|
|
|
172,720 |
|
|
|
107,442 |
|
Production equipment under construction
|
|
|
N/A |
|
|
|
94,332 |
|
|
|
-0- |
|
|
|
|
|
|
|
|
|
|
|
|
Total Property and Equipment
|
|
|
|
|
|
|
2,360,419 |
|
|
|
1,825,635 |
|
|
Less: Accumulated Depreciation
|
|
|
|
|
|
|
(433,800 |
) |
|
|
(221,451 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net Property and Equipment
|
|
|
|
|
|
$ |
1,926,619 |
|
|
$ |
1,604,184 |
|
|
|
|
|
|
|
|
|
|
|
Substantially all of the plant is pledged as security for
long-term debt to various lenders.
Depreciation expense was $212,347 and $164,289 for the years
ended December 31, 2004 and 2003, respectively, of which
$182,919 and $145,669 was included in cost of sales in 2004 and
2003.
|
|
Note 4 |
Capital Lease Obligations: |
The Corporation leases office equipment with a lease term
through October 2007. This obligation has been recorded in the
accompanying financial statements at the present value of future
minimum lease payments, discounted at an interest rate of
20 percent. Capitalized costs of $3,416, less accumulated
depreciation of $-0-at December 31, 2004, are included in
property and equipment in the accompanying financial statements.
Depreciation expense for this equipment for 2004 was $-0-.
Obligation under capital leases consist of the following:
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
|
|
|
| |
Total |
|
$ |
3,327 |
|
Less:
|
|
Current portion |
|
|
(447 |
) |
|
|
|
|
|
|
|
|
Long-Term Portion |
|
$ |
2,880 |
|
|
|
|
|
|
|
F-88
CAPCOIL TUBING SERVICES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
The future minimum lease payments under the capital leases and
the net present value of the future minimum lease payments are
as follows for the year ended December 31, 2004:
|
|
|
|
|
|
|
2004 | |
|
|
| |
2005
|
|
$ |
1,072 |
|
2006
|
|
|
1,072 |
|
2007
|
|
|
1,072 |
|
2008
|
|
|
1,072 |
|
2009
|
|
|
894 |
|
|
|
|
|
|
|
|
5,182 |
|
Less: Amount representing interest
|
|
|
(1,855 |
) |
|
|
|
|
Present Value of Future Minimum Lease payments
|
|
$ |
3,327 |
|
|
|
|
|
Note 5 Short-Term Borrowings:
Short-term borrowings at December 31, 2004 and 2003 are
comprised of the following:
|
|
|
|
|
|
|
|
|
|
|
Creditor |
|
Terms |
|
Collateral | |
|
2004 |
|
2003 |
|
|
|
|
| |
|
|
|
|
Texas Bank & Trust
|
|
$350,000 line-of-credit expiring December 2005 bearing interest
at prime (5.25 percent at December 31, 2004). |
|
|
Equipment |
|
|
$349,923 |
|
$350,000 |
Texas Bank & Trust
|
|
$375,000 line of credit expiring December 2004 bearing interest
at prime. |
|
|
Equipment |
|
|
-0- |
|
3,029 |
AICCO, Inc.
|
|
Due $11,760 per month through July 2005 including interest
at 7.15 percent. |
|
|
None |
|
|
80,391 |
|
-0- |
AICCO, Inc.
|
|
Due $10,114 per month through July 2004 including interest
at 6.50 percent. |
|
|
None |
|
|
-0- |
|
69,292 |
|
|
|
|
|
|
|
|
|
|
Total Short-Term Borrowings
|
|
|
|
|
|
|
|
$430,314 |
|
$422,321 |
|
|
|
|
|
|
|
|
|
|
Note 6 Short-Term Borrowings
Related Party:
Short-term borrowings from related parties at December 31,
2004 and 2003 are comprised of the following:
|
|
|
|
|
|
|
|
|
|
|
Creditor |
|
Terms |
|
Collateral | |
|
2004 |
|
2003 |
|
|
|
|
| |
|
|
|
|
M Bar Ranch, L.P.
|
|
$130,000 promissory note, interest of 8 percent and
principal due at maturity date August 2005. |
|
|
None |
|
|
$130,000 |
|
$-0- |
A stockholder of the corporation holds an interest in M Bar
Ranch, L.P.
Interest expense of $4,018 has been accrued on this short-term
borrowing at December 31, 2004.
F-89
CAPCOIL TUBING SERVICES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
Note 7 Long-Term Notes Payable:
Long-term notes payable to unrelated parties are comprised of
the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Creditor |
|
Terms |
|
Collateral |
|
2004 | |
|
2003 | |
|
|
|
|
|
|
| |
|
| |
Texas Bank & Trust
|
|
Due $6,048 per month through August 2006, including
interest at prime (5.25% at December 2004). |
|
Equipment - Accounts |
|
$ |
117,138 |
|
|
$ |
183,232 |
|
Texas Bank & Trust
|
|
Due $7,037 per month through March 2007, including interest
at prime (5.25% at December 2004). |
|
Equipment - Accounts |
|
|
176,501 |
|
|
|
251,566 |
|
Texas Bank & Trust
|
|
Due $7,000 per month through March 2006, including interest
at prime (5.25% at December 2004). |
|
Equipment - Accounts |
|
|
101,957 |
|
|
|
179,620 |
|
Texas Bank & Trust
|
|
Due $30,000 per month through June 2004, including interest
at prime (Pd in full at December 2004). |
|
Equipment - Accounts |
|
|
-0- |
|
|
|
171,541 |
|
Texas Bank & Trust
|
|
Due $7,407 per month through March 2007, including interest
at prime (5.25% at December 2004). |
|
Equipment - Accounts |
|
|
191,125 |
|
|
|
-0- |
|
Texas Bank & Trust
|
|
Due $6,100 per month through October 2007, including
interest at prime (5.25% at December 2004). |
|
Equipment - Accounts |
|
|
195,082 |
|
|
|
-0- |
|
Navistar
|
|
Due $1,055 per month through November 2005, including
interest at 9.95 percent. |
|
Equipment |
|
|
11,046 |
|
|
|
22,004 |
|
Navistar
|
|
Due $1,055 per month through November 2005, including
interest at 9.95 percent. |
|
Equipment |
|
|
11,046 |
|
|
|
21,075 |
|
Navistar
|
|
Due $998 per month through June 2007, including interest at
11.50 percent. |
|
Equipment |
|
|
24,405 |
|
|
|
-0- |
|
Ford Motor Credit
|
|
Due $738 per month through May 2006, including interest at
2.90 percent. |
|
Vehicle |
|
|
12,275 |
|
|
|
20,641 |
|
Ford Motor Credit
|
|
Due $1,112 per month through August 2006, including
interest at 5.50 percent. |
|
Vehicle |
|
|
21,211 |
|
|
|
33,035 |
|
Ford Motor Credit
|
|
Due $1,173 per month through July 2007, including interest
at 2.90 percent. |
|
Vehicle |
|
|
35,007 |
|
|
|
-0- |
|
Ford Motor Credit
|
|
Due $730 per month through August 2007, including interest
at 7.25 percent. |
|
Vehicle |
|
|
20,582 |
|
|
|
-0- |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Long-Term Notes Payable
|
|
|
|
|
|
|
917,375 |
|
|
|
882,714 |
|
|
Current Maturities
|
|
|
|
|
|
|
(445,924 |
) |
|
|
(431,452 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Long-Term Notes Payable,
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net of Current Maturities
|
|
|
|
|
|
$ |
471,451 |
|
|
$ |
451,262 |
|
|
|
|
|
|
|
|
|
|
|
|
F-90
CAPCOIL TUBING SERVICES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
Payments on the notes are due monthly in the approximate amount
of $40,453. The maturities of long-term debt for each of the
three years succeeding the balance sheet date are as follows:
|
|
|
|
|
|
2005
|
|
$ |
445,924 |
|
2006
|
|
|
349,064 |
|
2007
|
|
|
122,387 |
|
|
|
|
|
|
Total
|
|
$ |
917,375 |
|
|
|
|
|
Note 8 Long-Term
Note Payable Related Party:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Creditor |
|
Terms |
|
Collateral | |
|
2004 | |
|
2003 |
|
|
|
|
| |
|
| |
|
|
M Bar Ranch, L.P.
|
|
Due $2,194 per month through March 2007, including interest
at 8.00 percent. |
|
|
Vehicle |
|
|
$ |
54,037 |
|
|
$-0- |
|
Current Maturities
|
|
|
|
|
|
|
|
|
(22,824 |
) |
|
-0- |
|
|
|
|
|
|
|
|
|
|
|
|
Long-Term Note Payables Related Party, Net of
Current Maturities
|
|
|
|
|
|
|
|
$ |
31,213 |
|
|
$-0- |
|
|
|
|
|
|
|
|
|
|
|
The maturities of long-term debt for each of the three years
succeeding the balance sheet date are as follows:
|
|
|
|
|
|
2005
|
|
$ |
22,824 |
|
2006
|
|
|
24,719 |
|
2007
|
|
|
6,494 |
|
|
|
|
|
|
Total
|
|
$ |
54,037 |
|
|
|
|
|
Interest of $3,779 and principal of $8,986 was paid to the
related party on the note in 2004.
Note 9 Operating Leases:
The Corporation has various cancelable and noncancelable
operating leases for building space, storage facilities and
equipment. The noncancelable lease expired March 2005, but was
renewed through March 2007.
Future minimum rental payments for the next five years are as
follows:
|
|
|
|
|
2005
|
|
$ |
27,000 |
|
2006
|
|
|
27,000 |
|
2007
|
|
|
5,625 |
|
Rental expense under operating leases was $29,250 in 2004 and
$27,000 in 2003.
F-91
CAPCOIL TUBING SERVICES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
Note 10 Related Party Transactions:
The Corporation has received loans from affiliates and owners.
These transactions are described in previous footnotes to these
financial statements.
Note 11 Concentration of Credit Risk:
Financial instruments that potentially subject the Corporation
to significant concentrations of credit risk consists primarily
of cash equivalents and trade accounts receivable. The estimated
fair value of such financial instruments at December 31,
2004 and 2003 approximate their carrying value as reflected in
the balance sheet. At December 31, 2004, the Corporation
had deposits in checking accounts which exceed federally insured
limits by $248,674. The Corporation has not experienced any
material credit losses on its financial instruments.
Revenues from one customer represent 32 percent and
47 percent of total revenues in 2004 and 2003,
respectively. A second customer represented 14 percent of
total revenues in 2004. No other customers or entity accounted
for more than 10 percent of 2004 or 2003 revenues.
A majority of the Corporations trade receivables are
derived from large oil and gas production companies.
Concentration of credit risk with respect to receivables is
considered to be limited due to its customer base. However,
30 percent of trade receivables is due from one customer at
December 31, 2004. The Corporation performs ongoing credit
evaluations of its customers financial condition and
generally requires no collateral to secure accounts receivable.
The Corporation is exposed to credit loss in the event of
nonperformance by customers on trade receivables. The
Corporation does not anticipate significant nonperformance by
customers on trade receivables.
The Corporations sales are concentrated primarily in east
Texas and northern Louisiana.
Note 12 Additional Cash Flow Information:
|
|
|
|
|
|
|
|
|
|
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
Cash paid during the year:
|
|
|
|
|
|
|
|
|
|
Interest
|
|
$ |
69,764 |
|
|
$ |
51,380 |
|
Note 13 Significant Noncash Transactions:
The Corporation purchased equipment and vehicles in 2004 and
2003 and incurred $97,620 and $92,463, respectively, in debt
relative to these purchases.
Note 14 Subsequent Event:
Effective April 1, 2005, the stockholders of the
Corporation signed a letter of intent to sell their interests in
the Corporation to Allis-Chalmers Energy, Inc.
Effective January 1, 2005, the Corporation revoked its
S Corporation election for federal tax purposes and will be
taxed as a C Corporation.
F-92
INDEPENDENT AUDITORS REPORT ON ADDITIONAL
INFORMATION
To the Stockholders
of Capcoil Tubing Services, Inc.
Our report on our audits of the basic financial statements of
Capcoil Tubing Services, Inc. for December 31, 2004 and
2003, appears on page F-81. These audits were made for the
purpose of forming an opinion on the basic financial statements
taken as a whole. The additional information on pages F-94
and F-95 is presented for purposes of additional analysis and is
not a required part of the basic financial statements. Such
information has been subjected to the auditing procedures
applied in the audit of the basic financial statements and, in
our opinion, is fairly stated in all material respects in
relation to the basic financial statements taken as a whole.
|
|
|
/s/ CURTIS BLAKELY & CO.,
PC |
|
|
Longview, Texas
March 16, 2005
F-93
CAPCOIL TUBING SERVICES, INC.
STATEMENTS OF OPERATIONS WITH ADDITIONAL INFORMATION
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
REVENUE
|
|
$ |
5,774,442 |
|
|
$ |
5,478,666 |
|
COST OF SALES AND SERVICES:
|
|
|
|
|
|
|
|
|
|
Inventory Purchases
|
|
|
2,684,319 |
|
|
|
3,400,025 |
|
|
Wages
|
|
|
854,041 |
|
|
|
546,858 |
|
|
Contract Services
|
|
|
153,192 |
|
|
|
152,432 |
|
|
Location Expenses
|
|
|
84,709 |
|
|
|
58,027 |
|
|
Repairs and Maintenance
|
|
|
132,846 |
|
|
|
70,024 |
|
|
Depreciation
|
|
|
182,919 |
|
|
|
145,669 |
|
|
Fuel and Oil
|
|
|
114,112 |
|
|
|
74,836 |
|
|
Freight
|
|
|
14,432 |
|
|
|
11,646 |
|
|
Sales Commissions
|
|
|
15,352 |
|
|
|
323 |
|
|
Sales Expense
|
|
|
13,307 |
|
|
|
10,827 |
|
|
Supplies
|
|
|
61,494 |
|
|
|
28,165 |
|
|
Other Expenses
|
|
|
12,082 |
|
|
|
6,676 |
|
|
Equipment Leases and Rentals
|
|
|
48,511 |
|
|
|
18,194 |
|
|
|
|
|
|
|
|
|
|
TOTAL COST OF GOODS SOLD
|
|
|
4,371,316 |
|
|
|
4,523,702 |
|
|
|
|
|
|
|
|
GROSS PROFIT
|
|
|
1,403,126 |
|
|
|
954,964 |
|
|
|
|
|
|
|
|
GENERAL AND ADMINISTRATIVE:
|
|
|
|
|
|
|
|
|
|
Accounting
|
|
|
41,794 |
|
|
|
22,456 |
|
|
Telephone
|
|
|
26,939 |
|
|
|
19,842 |
|
|
Auto
|
|
|
17,955 |
|
|
|
15,203 |
|
|
Consulting
|
|
|
15,100 |
|
|
|
15,012 |
|
|
Advertising and Promotional
|
|
|
12,715 |
|
|
|
6,847 |
|
|
License and Fees
|
|
|
10,719 |
|
|
|
7,110 |
|
|
Office Supplies
|
|
|
7,818 |
|
|
|
7,644 |
|
|
Utilities
|
|
|
7,582 |
|
|
|
6,397 |
|
|
Janitorial
|
|
|
5,542 |
|
|
|
2,953 |
|
|
Office Expense
|
|
|
4,248 |
|
|
|
3,332 |
|
|
Postage
|
|
|
4,084 |
|
|
|
4,556 |
|
|
Other General and Administrative
|
|
|
1,643 |
|
|
|
829 |
|
|
Meals
|
|
|
1,393 |
|
|
|
1,899 |
|
|
Contract Service Office
|
|
|
1,145 |
|
|
|
16,779 |
|
|
Contributions
|
|
|
1,000 |
|
|
|
395 |
|
|
|
|
|
|
|
|
|
|
TOTAL GENERAL AND ADMINISTRATIVE
|
|
|
159,677 |
|
|
|
131,254 |
|
|
|
|
|
|
|
|
F-94
CAPCOIL TUBING SERVICES, INC.
STATEMENTS OF OPERATIONS WITH ADDITIONAL INFORMATION
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended | |
|
|
December 31, | |
|
|
| |
|
|
2004 | |
|
2003 | |
|
|
| |
|
| |
DEPRECIATION AND AMORTIZATION:
|
|
|
|
|
|
|
|
|
|
Depreciation Expense
|
|
|
29,428 |
|
|
|
18,620 |
|
|
Amortization Expense
|
|
|
6,028 |
|
|
|
6,028 |
|
|
|
|
|
|
|
|
|
|
TOTAL DEPRECIATION AND AMORTIZATION
|
|
|
35,456 |
|
|
|
24,648 |
|
|
|
|
|
|
|
|
INSURANCE EXPENSE:
|
|
|
|
|
|
|
|
|
|
Insurance General
|
|
|
119,039 |
|
|
|
118,023 |
|
|
Insurance Health
|
|
|
65,583 |
|
|
|
40,792 |
|
|
Insurance Workmens Compensation
|
|
|
41,445 |
|
|
|
25,265 |
|
|
Insurance Keyman Life
|
|
|
2,045 |
|
|
|
2,045 |
|
|
|
|
|
|
|
|
|
|
TOTAL INSURANCE
|
|
|
228,112 |
|
|
|
186,125 |
|
|
|
|
|
|
|
|
LEASE OF BUILDINGS AND STORAGE FACILITIES
|
|
|
29,250 |
|
|
|
27,000 |
|
|
|
|
|
|
|
|
SALARIES ADMINISTRATIVE
|
|
|
|
|
|
|
|
|
|
Salaries Officers
|
|
|
89,115 |
|
|
|
77,769 |
|
|
Salaries Office Employees
|
|
|
37,405 |
|
|
|
11,518 |
|
|
|
|
|
|
|
|
|
|
TOTAL SALARIES ADMINISTRATIVE
|
|
|
126,520 |
|
|
|
89,287 |
|
|
|
|
|
|
|
|
TAX EXPENSE:
|
|
|
|
|
|
|
|
|
|
Taxes Payroll
|
|
|
78,536 |
|
|
|
52,205 |
|
|
Taxes Property
|
|
|
43,495 |
|
|
|
13,926 |
|
|
Taxes Other
|
|
|
2,501 |
|
|
|
1,832 |
|
|
Taxes State Franchise
|
|
|
1,690 |
|
|
|
875 |
|
|
|
|
|
|
|
|
|
|
TOTAL TAX EXPENSE
|
|
|
126,222 |
|
|
|
68,838 |
|
|
|
|
|
|
|
|
INTEREST
|
|
|
73,782 |
|
|
|
51,380 |
|
|
|
|
|
|
|
|
|
|
TOTAL OPERATING EXPENSES
|
|
|
779,019 |
|
|
|
578,532 |
|
|
|
|
|
|
|
|
|
|
NET INCOME
|
|
$ |
624,107 |
|
|
$ |
376,432 |
|
|
|
|
|
|
|
|
F-95
CAPCOIL TUBING SERVICES, INC.
BALANCE SHEET
As of March 31, 2005
(unaudited)
|
|
|
|
|
|
|
|
ASSETS |
Current Assets
|
|
|
|
|
|
Cash in Bank TB&T
|
|
|
183,614.45 |
|
|
Accounts Receivable
|
|
|
1,021,133.53 |
|
|
Inventory
|
|
|
334,309.46 |
|
|
Prepaid Expenses
|
|
|
79,136.57 |
|
|
|
|
|
|
|
Total Current Assets
|
|
|
1,618,194.01 |
|
Property and Equipment Equipment
|
|
|
2,474,765.35 |
|
|
Accumulated Depreciation
|
|
|
(492,780.50 |
) |
|
|
|
|
|
Net Property and Equipment
|
|
|
1,981,984.85 |
|
|
Other Assets Organization Costs
|
|
|
2,242.25 |
|
|
Startup Costs
|
|
|
27,898.75 |
|
|
Accumulated Amortization
|
|
|
(19,590.00 |
) |
|
Deposits
|
|
|
10,875.00 |
|
|
|
|
|
|
|
Total Other Assets
|
|
|
21,426.00 |
|
|
|
|
|
|
|
|
Total Assets
|
|
|
3,621,604.86 |
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY |
Current Liabilities
|
|
|
|
|
|
Accounts Payable
|
|
|
449,217.60 |
|
|
Payroll Taxes Payable
|
|
|
3,448.71 |
|
|
Sales Tax Payable
|
|
|
44,997.92 |
|
|
Accrued Interest Payable
|
|
|
4,017.53 |
|
|
Salaries Payable
|
|
|
16,143.77 |
|
|
Current Income Taxes Payable
|
|
|
94,000.00 |
|
|
N/ P Insurance
|
|
|
46,139.99 |
|
|
N/ P M-BAR Ranch
|
|
|
130,000.00 |
|
|
N/ P TB&T LOC
|
|
|
349,923.29 |
|
|
Current Maturities of L-T
|
|
|
467,915.64 |
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
1,605,804.45 |
|
Long-Term Liabilities N/ P FMC
|
|
|
135,292.77 |
|
N/ P Navistar
|
|
|
39,147.38 |
|
N/ P TB&T
|
|
|
686,059.55 |
|
N/ P M-BAR
|
|
|
48,500.43 |
|
N/ P IKON RICOH
|
|
|
3,258.52 |
|
Current Maturities of L-T
|
|
|
(467,915.64 |
) |
|
|
|
|
|
|
Total Long-Term Liabilities
|
|
|
444,343.01 |
|
|
|
|
|
|
|
|
Total Liabilities
|
|
|
2,050,147.46 |
|
Deferred Income Taxes
|
|
|
6,898.00 |
|
Stockholders Equity Capital Stock
|
|
|
600,000.00 |
|
|
Contribution to Capital
|
|
|
50,000.00 |
|
|
Retained Earnings
|
|
|
914,559.40 |
|
|
|
|
|
|
|
Total Stockholders Equity
|
|
|
1,564,559.40 |
|
|
|
|
|
|
|
|
Total Liabilities and Stockholders Equity
|
|
|
3,621,604.86 |
|
|
|
|
|
F-96
CAPCOIL TUBING SERVICES, INC.
STATEMENT OF INCOME AND RETAINED EARNINGS
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
|
March 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Revenue
|
|
|
|
|
|
|
|
|
|
Sales Service
|
|
|
622,283.61 |
|
|
|
355,661.68 |
|
|
Sales Materials
|
|
|
911,615.67 |
|
|
|
1,190,200.66 |
|
|
|
|
|
|
|
|
|
|
Total Revenue
|
|
|
1,533,899.28 |
|
|
|
1,545,862.34 |
|
Cost of Goods Sold
|
|
|
950,535.70 |
|
|
|
1,131,968.64 |
|
|
|
|
|
|
|
|
|
|
Gross Profit
|
|
|
583,363.58 |
|
|
|
413,893.70 |
|
Operating Expenses Contract Services
|
|
|
3,007.50 |
|
|
|
8,548.13 |
|
|
Insurance
|
|
|
61,206.10 |
|
|
|
57,193.97 |
|
|
Lease
|
|
|
59,372.36 |
|
|
|
24,618.30 |
|
|
Supplies
|
|
|
28,500.98 |
|
|
|
14,705.44 |
|
|
Taxes
|
|
|
26,077.65 |
|
|
|
16,749.81 |
|
|
Accounting & Legal
|
|
|
28,478.91 |
|
|
|
13,481.21 |
|
|
Advertising & Promotional
|
|
|
844.43 |
|
|
|
882.50 |
|
|
Amortization
|
|
|
1,506.00 |
|
|
|
1,506.00 |
|
|
Bank Charges
|
|
|
128.60 |
|
|
|
129.20 |
|
|
Commission Salesman
|
|
|
4,000.00 |
|
|
|
0.00 |
|
|
Consulting
|
|
|
4,200.00 |
|
|
|
3,300.00 |
|
|
Depreciation
|
|
|
9,240.66 |
|
|
|
5,926.17 |
|
|
Dues & Subscriptions
|
|
|
1,189.39 |
|
|
|
0.00 |
|
|
Employee Medical
|
|
|
978.22 |
|
|
|
436.06 |
|
|
Freight
|
|
|
8,259.61 |
|
|
|
340.00 |
|
|
Interest
|
|
|
20,360.28 |
|
|
|
18,007.80 |
|
|
License & Fees
|
|
|
150.46 |
|
|
|
1,364.98 |
|
|
Maint & Repairs General
|
|
|
98.51 |
|
|
|
815.40 |
|
|
Meals & Entertainment
|
|
|
0.00 |
|
|
|
101.85 |
|
|
Office Expense
|
|
|
3,326.71 |
|
|
|
964.16 |
|
|
Postage
|
|
|
1,117.54 |
|
|
|
999.49 |
|
|
Janitorial
|
|
|
1,300.00 |
|
|
|
1,340.75 |
|
|
Salaries Officers
|
|
|
21,000.00 |
|
|
|
21,000.00 |
|
|
Salaries Office
|
|
|
8,830.06 |
|
|
|
5,805.94 |
|
|
Sales Expense
|
|
|
3,679.23 |
|
|
|
2,649.54 |
|
|
Telephone
|
|
|
8,483.66 |
|
|
|
4,296.17 |
|
|
Uniforms
|
|
|
824.89 |
|
|
|
0.00 |
|
|
Utilities
|
|
|
1,610.44 |
|
|
|
1,828.06 |
|
|
Waste Water
|
|
|
714.00 |
|
|
|
475.00 |
|
|
Travel
|
|
|
0.00 |
|
|
|
246.75 |
|
|
Truck Expense
|
|
|
583.27 |
|
|
|
218.00 |
|
|
|
|
|
|
|
|
|
|
Total Operating Expenses
|
|
|
309,069.46 |
|
|
|
207,930.68 |
|
|
|
|
|
|
|
|
|
|
Income/(Loss) Before Income Taxes
|
|
|
274,294.12 |
|
|
|
205,963.02 |
|
Income Taxes
|
|
|
(100,898.00 |
) |
|
|
0.00 |
|
Other Income
|
|
|
0.00 |
|
|
|
1,000.00 |
|
|
|
|
|
|
|
|
|
|
Net Income (Loss)
|
|
|
173,396.12 |
|
|
|
206,963.02 |
|
|
|
|
|
|
|
|
Retained Earnings at Beginning of Period
|
|
|
741,163.28 |
|
|
|
117,056.14 |
|
|
|
|
|
|
|
|
|
|
Retained Earnings at End of Period
|
|
|
914,559.40 |
|
|
|
324,019.16 |
|
|
|
|
|
|
|
|
F-97
CAPCOIL TUBING SERVICES, INC.
STATEMENTS OF CASH FLOWS
Three Months Ended March 31,
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended | |
|
|
March 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Cash flows from operating activities:
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
173,396 |
|
|
$ |
206,963 |
|
Adjustments to reconcile net (loss) to net cash provided by
operating activities:
|
|
|
|
|
|
|
|
|
Depreciation and amortization expense
|
|
|
51,247 |
|
|
|
44,236 |
|
Changes in working capital:
|
|
|
|
|
|
|
|
|
|
Decrease (increase) in accounts receivable
|
|
|
(482,476 |
) |
|
|
69,545 |
|
|
Decrease (increase) in other current assets
|
|
|
80,942 |
|
|
|
163,895 |
|
|
Decrease (increase) in other assets
|
|
|
(10,875 |
) |
|
|
(375 |
) |
|
(Decrease) increase in accounts payable
|
|
|
65,456 |
|
|
|
(306,063 |
) |
|
(Decrease) increase in accrued expenses
|
|
|
138,998 |
|
|
|
21,643 |
|
|
(Decrease) increase in other long-term liabilities
|
|
|
6,898 |
|
|
|
|
|
|
(Decrease) increase in accrued employee benefits and payroll
taxes
|
|
|
13,193 |
|
|
|
67 |
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
36,779 |
|
|
|
199,911 |
|
Cash flows from investing activities:
|
|
|
|
|
|
|
|
|
|
Purchase of equipment
|
|
|
(105,107 |
) |
|
|
(35,739 |
) |
|
|
|
|
|
|
|
Net cash provided (used) by investing activities
|
|
|
(105,107 |
) |
|
|
(35,739 |
) |
Cash flows from financing activities:
|
|
|
|
|
|
|
|
|
|
Repayments of long-term debt
|
|
|
(96,732 |
) |
|
|
(161,241 |
) |
|
Proceeds from issuance of long-term debt
|
|
|
|
|
|
|
307,399 |
|
Net cash provided (used) by financing activities
|
|
|
(96,732 |
) |
|
|
146,158 |
|
|
|
|
|
|
|
|
Net increase (decrease) in cash and cash equivalents
|
|
|
(165,060 |
) |
|
|
310,330 |
|
Cash and cash equivalents at beginning of year
|
|
|
348,674 |
|
|
|
45,857 |
|
|
|
|
|
|
|
|
Cash and cash equivalents at end of period
|
|
$ |
183,614 |
|
|
$ |
356,187 |
|
|
|
|
|
|
|
|
F-98
INDEPENDENT AUDITORS REPORT
To the Board of Directors and Stockholders
of W.T. Enterprises, Inc.
We have audited the accompanying balance sheets of W.T.
Enterprises, Inc. (a Texas Corporation) (the Company) as of
March 31, 2005, and December 31, 2004 and 2003 and the
related statements of income, stockholders equity, and
cash flows for the three months ended March 31, 2005 and
the years ended December 31, 2004 and 2003. These financial
statements are the responsibility of the Companys
management. Our responsibility is to express an opinion on these
financial statements based on our audit.
We conducted our audit in accordance with auditing standards
generally accepted in the United States of America. Those
standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in
the financial statements. An audit also includes assessing the
accounting principles used and significant estimates made by
management, as well as evaluating the overall financial
statement presentation. We believe that our audit provides a
reasonable basis for our opinion.
In our opinion the financial statements referred to in the first
paragraph present fairly, in all material respects, the
financial position of W.T. Enterprises, Inc. as of
March 31, 2005 and December 31, 2004 and 2003, and the
results of its operations and its cash flows for the three
months ended March 31, 2005 and the years ended
December 31, 2004 and 2003 in conformity with accounting
principles generally accepted in the United States of America.
|
|
|
Accounting & Consulting Group, LLP |
Carlsbad, New Mexico
June 10, 2005
F-99
W.T. ENTERPRISES, INC.
BALANCE SHEETS
March 31, 2005, December 31, 2004 and 2003
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
March 31, | |
|
December 31, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
ASSETS |
Current Assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
123,093 |
|
|
$ |
49,695 |
|
|
$ |
39,821 |
|
|
Accounts receivable
|
|
|
359,875 |
|
|
|
418,290 |
|
|
|
446,646 |
|
|
Unbilled receivables
|
|
|
129,325 |
|
|
|
101,400 |
|
|
|
47,000 |
|
|
Related party receivable (Note 2)
|
|
|
7,967 |
|
|
|
9,673 |
|
|
|
15,991 |
|
|
Prepaid income taxes
|
|
|
|
|
|
|
|
|
|
|
3,507 |
|
|
Prepaid expenses
|
|
|
10,497 |
|
|
|
11,593 |
|
|
|
11,697 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Assets
|
|
|
630,757 |
|
|
|
590,651 |
|
|
|
564,662 |
|
|
|
|
|
|
|
|
|
|
|
Property and Equipment:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Transportation equipment
|
|
|
137,555 |
|
|
|
137,555 |
|
|
|
137,555 |
|
|
Machinery and equipment
|
|
|
1,905,235 |
|
|
|
1,867,336 |
|
|
|
1,248,414 |
|
|
Office furniture and equipment
|
|
|
7,131 |
|
|
|
7,131 |
|
|
|
7,131 |
|
|
Accumulated depreciation
|
|
|
(748,646 |
) |
|
|
(677,475 |
) |
|
|
(428,031 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Total Property and Equipment
|
|
|
1,301,275 |
|
|
|
1,334,547 |
|
|
|
965,069 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets
|
|
$ |
1,932,032 |
|
|
$ |
1,925,198 |
|
|
$ |
1,529,731 |
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY |
Current Liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current maturities of long-term debt (Note 4)
|
|
$ |
283,194 |
|
|
$ |
312,414 |
|
|
$ |
235,137 |
|
|
Short-term notes payable (Note 3)
|
|
|
54,601 |
|
|
|
86,765 |
|
|
|
149,995 |
|
|
Accounts payable
|
|
|
82,369 |
|
|
|
117,928 |
|
|
|
129,895 |
|
|
Accrued expenses
|
|
|
131,188 |
|
|
|
62,726 |
|
|
|
63,514 |
|
|
Deferred income taxes (Note 9)
|
|
|
68,644 |
|
|
|
72,204 |
|
|
|
33,425 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
619,996 |
|
|
|
652,037 |
|
|
|
611,966 |
|
|
|
|
|
|
|
|
|
|
|
Long-Term Debt (Note 4)
|
|
|
89,959 |
|
|
|
153,675 |
|
|
|
279,349 |
|
Deferred income taxes (Note 9)
|
|
|
136,593 |
|
|
|
132,577 |
|
|
|
78,565 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities
|
|
|
846,548 |
|
|
|
938,289 |
|
|
|
969,880 |
|
|
|
|
|
|
|
|
|
|
|
Stockholders Equity:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock, par value $10 100 shares issued and
outstanding
|
|
|
1,000 |
|
|
|
1,000 |
|
|
|
1,000 |
|
|
|
|
|
|
|
|
|
|
|
|
Retained earnings
|
|
|
1,084,484 |
|
|
|
985,909 |
|
|
|
558,851 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total stockholders equity
|
|
|
1,085,484 |
|
|
|
986,909 |
|
|
|
559,851 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities and stockholders equity
|
|
$ |
1,932,032 |
|
|
$ |
1,925,198 |
|
|
$ |
1,529,731 |
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these financial
statements.
F-100
W.T. ENTERPRISES, INC.
STATEMENTS OF INCOME
For the Three Months Ended March 31, 2005
and Years Ended December 31, 2004 and 2003
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
March 31, | |
|
December 31, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Revenue
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service revenue
|
|
$ |
926,906 |
|
|
$ |
3,862,005 |
|
|
$ |
2,415,266 |
|
|
Other income
|
|
|
|
|
|
|
|
|
|
|
2,800 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total revenue
|
|
|
926,906 |
|
|
|
3,862,005 |
|
|
|
2,418,066 |
|
|
|
|
|
|
|
|
|
|
|
Expenses
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service-related expenses
|
|
|
552,472 |
|
|
|
2,514,373 |
|
|
|
1,582,313 |
|
|
Selling, general, and administrative expenses
|
|
|
150,499 |
|
|
|
514,211 |
|
|
|
459,186 |
|
|
Depreciation and amortization
|
|
|
71,171 |
|
|
|
249,444 |
|
|
|
174,386 |
|
|
Interest expense
|
|
|
8,656 |
|
|
|
44,344 |
|
|
|
27,604 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total expenses
|
|
|
782,798 |
|
|
|
3,322,372 |
|
|
|
2,243,489 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating income
|
|
|
144,108 |
|
|
|
539,633 |
|
|
|
174,577 |
|
|
|
|
|
|
|
|
|
|
|
Other income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gain (loss) on sale of assets
|
|
|
|
|
|
|
|
|
|
|
6,723 |
|
|
Interest income
|
|
|
93 |
|
|
|
585 |
|
|
|
905 |
|
|
|
|
|
|
|
|
|
|
|
Income before income taxes
|
|
|
144,201 |
|
|
|
540,218 |
|
|
|
182,205 |
|
Federal and state income taxes (Note 9)
|
|
|
45,626 |
|
|
|
113,160 |
|
|
|
37,121 |
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
98,575 |
|
|
$ |
427,058 |
|
|
$ |
145,084 |
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these financial
statements.
F-101
W.T. ENTERPRISES, INC.
STATEMENTS OF STOCKHOLDERS EQUITY
For the Three Months Ended March 31, 2005 and
The Years Ended December 31, 2004 and 2003
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common | |
|
Paid-in |
|
Retained | |
|
|
|
|
Stock | |
|
Capital |
|
Earnings | |
|
Total | |
|
|
| |
|
|
|
| |
|
| |
Balance, January 1, 2003
|
|
$ |
1,000 |
|
|
$ |
|
|
|
$ |
413,767 |
|
|
$ |
414,767 |
|
Net Income
|
|
|
|
|
|
|
|
|
|
|
145,084 |
|
|
|
145,084 |
|
Dividends paid
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, December 31, 2003
|
|
|
1,000 |
|
|
|
|
|
|
|
558,851 |
|
|
|
559,851 |
|
Net Income
|
|
|
|
|
|
|
|
|
|
|
427,058 |
|
|
|
427,058 |
|
Dividends paid
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, December 31, 2004
|
|
|
1,000 |
|
|
|
|
|
|
|
985,909 |
|
|
|
986,909 |
|
Net Income
|
|
|
|
|
|
|
|
|
|
|
98,575 |
|
|
|
98,575 |
|
Dividends paid
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, March 31, 2005
|
|
$ |
1,000 |
|
|
$ |
|
|
|
$ |
1,084,484 |
|
|
$ |
1,085,484 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these financial
statements.
F-102
W.T. ENTERPRISES, INC.
STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2005 and
The Years Ended December 31, 2004 and 2003
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
March 31, | |
|
December 31, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Cash flows from operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
98,575 |
|
|
$ |
427,058 |
|
|
$ |
145,084 |
|
Adjustments to reconcile net income to net cash provided
(used) by operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation and amortization
|
|
|
71,171 |
|
|
|
249,444 |
|
|
|
174,386 |
|
|
Gain (loss) on sale of property, plant, and equipment
|
|
|
|
|
|
|
|
|
|
|
(6,723 |
) |
|
Deferred income taxes
|
|
|
457 |
|
|
|
92,791 |
|
|
|
37,121 |
|
Change in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts receivable
|
|
|
30,490 |
|
|
|
(26,044 |
) |
|
|
(309,046 |
) |
|
Prepaid expenses
|
|
|
1,096 |
|
|
|
104 |
|
|
|
(858 |
) |
|
Prepaid income tax
|
|
|
|
|
|
|
3,507 |
|
|
|
(3,507 |
) |
|
Accounts payable
|
|
|
(35,559 |
) |
|
|
(11,967 |
) |
|
|
81,718 |
|
|
Accrued payroll and employee benefits
|
|
|
29,696 |
|
|
|
(14,467 |
) |
|
|
31,379 |
|
|
Income tax payable
|
|
|
38,764 |
|
|
|
13,679 |
|
|
|
(2,076 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net Cash Provided (Used) by Operating Activities
|
|
|
234,690 |
|
|
|
734,105 |
|
|
|
147,478 |
|
|
|
|
|
|
|
|
|
|
|
Cash flows from investing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Proceeds from sale of property, plant, and equipment
|
|
|
|
|
|
|
|
|
|
|
25,000 |
|
Principal payments received on shareholder loans
|
|
|
1,707 |
|
|
|
6,318 |
|
|
|
5,695 |
|
Capital expenditures on property, plant, and equipment
|
|
|
(37,899 |
) |
|
|
(406,618 |
) |
|
|
(220,385 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net Cash Provided (Used) by Investing Activities
|
|
|
(36,192 |
) |
|
|
(400,300 |
) |
|
|
(189,690 |
) |
|
|
|
|
|
|
|
|
|
|
Cash flows from financing activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
Repayment of long-term debt
|
|
|
(92,936 |
) |
|
|
(322,686 |
) |
|
|
(190,748 |
) |
Proceeds from issuance of long-term debt
|
|
|
|
|
|
|
160,000 |
|
|
|
155,105 |
|
Repayment of short-term debt
|
|
|
(32,164 |
) |
|
|
(1,550,165 |
) |
|
|
(479,550 |
) |
Proceeds from issuance of short-term debt
|
|
|
|
|
|
|
1,388,920 |
|
|
|
561,260 |
|
|
|
|
|
|
|
|
|
|
|
|
Net Cash Provided (Used) by Financing Activities
|
|
|
(125,100 |
) |
|
|
(323,931 |
) |
|
|
46,067 |
|
|
|
|
|
|
|
|
|
|
|
Net Increase (Decrease) in Cash and Cash Equivalents
|
|
|
73,398 |
|
|
|
9,874 |
|
|
|
3,855 |
|
Cash and Cash Equivalents at Beginning of Year
|
|
|
49,695 |
|
|
|
39,821 |
|
|
|
35,966 |
|
|
|
|
|
|
|
|
|
|
|
Cash and Cash Equivalents at End of Year
|
|
$ |
123,093 |
|
|
$ |
49,695 |
|
|
$ |
39,821 |
|
|
|
|
|
|
|
|
|
|
|
Supplemental Schedule of Noncash Investing and Financing
Activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchase of equipment financed with debt proceeds
|
|
$ |
|
|
|
$ |
212,303 |
|
|
$ |
378,396 |
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for interest
|
|
$ |
8,954 |
|
|
$ |
44,045 |
|
|
$ |
27,022 |
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes are an integral part of these financial
statements.
F-103
W.T. ENTERPRISES, INC.
NOTES TO FINANCIAL STATEMENTS
March 31, 2005, December 31, 2004 and 2003
|
|
Note 1: |
Summary of Significant Accounting Policies |
Nature of Operations. W.T. Enterprises, Inc. (the
Company), is primarily engaged in the business of providing
compressed air for the drilling of oil and gas wells in the
state of Texas. The work is generally performed under fixed
price per day contracts.
Cash and Cash Equivalents. Cash and cash equivalents
include all cash balances and highly liquid investments with an
initial maturity of three months or less. The Company places its
temporary cash investments with a high credit quality financial
institution. At times such deposits may be in excess of the
Federal Deposit Insurance Corporation (FDIC) insurance limit.
Trade Accounts Receivable. Trade receivables are carried
at their estimated collectible amounts. Trade credit is
generally extended on a short-term basis; thus trade receivables
do not bear interest. Trade accounts receivable are periodically
evaluated for collectibility based on past credit history with
customers and their current financial condition. Trade
receivables are considered fully collectible and therefore no
allowance for doubtful accounts has been provided.
Unbilled Receivables. Unbilled receivables represent
revenue earned in the current period but not billed to the
customer until future dates, usually within one month.
Property, plant and equipment. Property, plant and
equipment are recorded at cost less depreciation and
amortization. Depreciation is provided over the estimated useful
life of each class of depreciable asset and is computed using
the straight line method. Estimated useful lives for equipment
and transportation equipment range from three to seven years.
Betterments and large renewals which extend the life of the
asset are capitalized whereas maintenance and repairs and small
renewals are expensed as incurred.
Revenue Recognition. Revenue is recognized in the
financial statements in the period the services were provided.
Advertising Costs. Advertising costs are expensed as
incurred.
Income Taxes. Deferred taxes are provided on a liability
method whereby deferred tax assets are recognized for deductible
temporary differences and operating loss and tax credit
carryforwards and deferred tax liabilities are recognized for
taxable temporary differences. Temporary differences are the
differences between the reported amounts of assets and
liabilities and their tax bases. The Company files its income
tax returns on the cash basis of accounting. The Companys
temporary differences relate primarily to accounts receivable,
accounts payable and accrued expenses and property and
equipment. Deferred tax assets are reduced by a valuation
allowance when, in the opinion of management, it is more likely
than not that some portion or all of the deferred tax assets
will not be realized. Deferred tax assets and liabilities are
adjusted for the effects of changes in tax laws and rates on the
date of enactment.
Use of Estimates. The preparation of financial statements
in conformity with generally accepted accounting principles
requires management to make estimates and assumptions that
affect the reported amounts of assets and liabilities and
disclosure of contingent assets and liabilities at the date of
the
F-104
W.T. ENTERPRISES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
financial statements and the reported amounts of revenues and
expenses during the reporting period. Actual results could
differ from those estimates.
|
|
Note 2: |
Related-Party Transactions |
A summary of amounts due from shareholders follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
March 31, | |
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Note receivables from shareholders, due upon demand, bearing
interest of 0%, unsecured
|
|
$ |
7,967 |
|
|
$ |
9,673 |
|
|
$ |
15,991 |
|
|
|
|
|
|
|
|
|
|
|
The Company leases equipment and a storage facility from
shareholders under informal
month-to-month
operating leases. Rental expense for these leases totaled
$8,700, $34,800 and $6,000 for the three months ended
March 31, 2005 and the years ended December 31, 2004
and 2003, respectively.
|
|
Note 3: |
Pledged Assets and Short-Term Notes Payable |
Short-term notes payable are collateralized by equipment and
receivables and as of March 31, 2005 and December 31,
2004 and 2003 consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
March 31, | |
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Note payable, FNB, $150,000 line of credit, 6.0 to 6.25%
interest rate
|
|
$ |
|
|
|
$ |
|
|
|
$ |
103,850 |
|
Note payable, FNB, $53,485, 6.0 to 7.75% interest rate
|
|
|
|
|
|
|
|
|
|
|
24,299 |
|
Note payable, FNB, $53,485, 6.25 to 8.75% interest rate
|
|
|
|
|
|
|
|
|
|
|
21,846 |
|
Note payable, FNB, $46,145, 6.0 to 7.25% interest rate
|
|
|
13,380 |
|
|
|
21,106 |
|
|
|
|
|
Note payable, CAT Financial, $98,013, 6.7% interest rate
|
|
|
41,221 |
|
|
|
65,659 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
54,601 |
|
|
$ |
86,765 |
|
|
$ |
149,995 |
|
|
|
|
|
|
|
|
|
|
|
F-105
W.T. ENTERPRISES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
|
|
Note 4: |
Pledged Assets and Long-Term Debt |
Long-term debt and the related assets pledged thereon as of
March 31, 2005, and December 31, 2004 and 2003,
consisted of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
March 31, | |
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Various notes payable to banks and financing companies for
vehicles and equipment, due in installments through March, 2008
at fixed interest rates ranging from 0.0% to 8.75%,
collateralized by vehicles, equipment and accounts receivable
|
|
$ |
138,594 |
|
|
$ |
160,674 |
|
|
$ |
250,893 |
|
Various notes payable to banks and financing companies for
vehicles and equipment, due in installments through March, 2007
at variable interest rates ranging from 4.15% to 7.25%,
collateralized by vehicles, equipment and accounts receivable
|
|
|
234,559 |
|
|
|
305,415 |
|
|
|
263,593 |
|
|
|
|
|
|
|
|
|
|
|
Subtotal
|
|
|
373,153 |
|
|
|
466,089 |
|
|
|
514,486 |
|
|
Less current maturities
|
|
|
283,194 |
|
|
|
312,414 |
|
|
|
235,137 |
|
|
|
|
|
|
|
|
|
|
|
Total Long-term debt
|
|
$ |
89,959 |
|
|
$ |
153,675 |
|
|
$ |
279,349 |
|
|
|
|
|
|
|
|
|
|
|
As of March 31, 2005, principal payments required to
amortize the debt are summarized below:
|
|
|
|
|
Year Ending March 31, |
|
|
|
|
|
2006
|
|
$ |
283,194 |
|
2007
|
|
|
79,845 |
|
2008
|
|
|
10,114 |
|
|
|
|
|
|
|
$ |
373,153 |
|
|
|
|
|
The Company has two non-cancelable operating leases for
compressor equipment, which expire on November 30, 2005.
The company also leases compressor equipment on various
cancelable leases. Future minimum lease payments payable under
non-cancelable operating lease are due as follows:
|
|
|
|
|
Year Ending March 31, |
|
|
|
|
|
2006
|
|
$ |
144,000 |
|
|
|
|
|
Rental expense for all operating leases totaled $186,936,
$912,594, and $472,272 for the three months ended March 31,
2005 and the years ended December 31, 2004 and 2003,
respectively.
F-106
W.T. ENTERPRISES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
|
|
Note 6: |
Stockholders Equity |
At March 31, 2005, December 31, 2004 and 2003, the
number of authorized and issued common stock and related par
value and dividends paid are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
March 31, | |
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Common stock authorized
|
|
|
100 |
|
|
|
100 |
|
|
|
100 |
|
Common stock issued
|
|
|
100 |
|
|
|
100 |
|
|
|
100 |
|
Common stock outstanding
|
|
|
100 |
|
|
|
100 |
|
|
|
100 |
|
Common stock, per share par value
|
|
$ |
10 |
|
|
$ |
10 |
|
|
$ |
10 |
|
Cash dividends paid on common stock
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Note 7: |
Dependence on Key Customers |
For the three months ended March 31, 2005 and for the years
ended December 31, 2004 and December 31, 2003 the
Companys revenues were almost entirely attributable to one
customer. As of March 31, 2005 approximately 85% of the
Companys accounts receivable were attributable to this one
customer.
|
|
Note 8: |
Subsequent Events |
The Companys management is currently negotiating the sale
of substantially all the Companys assets. The anticipated
sales date is June 30, 2005. The estimated sales price of
the assets is substantially in excess of their book value. Upon
consummation of the sale, the Company will exercise options to
purchase equipment, currently under operating leases, for
$550,000 and then include this equipment in the assets the
Company sells.
Subsequent to March 31, 2005 the Company purchased
approximately $240,000 of equipment, which was 100% financed
through short-term bank loans.
F-107
W.T. ENTERPRISES, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
|
|
Note 9: |
Income Tax Matters |
Net deferred tax liabilities as of March 31, 2005,
December 31, 2004 and 2003 consist of the following
components:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
March 31, | |
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Deferred Tax Liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Property and equipment
|
|
$ |
136,593 |
|
|
$ |
132,577 |
|
|
$ |
78,565 |
|
|
Cash basis receivables
|
|
|
95,394 |
|
|
|
101,340 |
|
|
|
96,261 |
|
|
Prepaid expenses
|
|
|
2,047 |
|
|
|
2,261 |
|
|
|
2,281 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
234,034 |
|
|
|
236,178 |
|
|
|
177,107 |
|
|
|
|
|
|
|
|
|
|
|
Deferred Tax Assets:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net operating loss carryforward
|
|
|
|
|
|
|
|
|
|
|
31,099 |
|
|
Cash basis accounts payable and accrued expenses
|
|
|
28,797 |
|
|
|
31,397 |
|
|
|
34,018 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
28,797 |
|
|
|
31,397 |
|
|
|
65,117 |
|
|
|
|
|
|
|
|
|
|
|
Net deferred tax liabilities
|
|
$ |
205,237 |
|
|
$ |
204,781 |
|
|
$ |
111,990 |
|
|
|
|
|
|
|
|
|
|
|
Realization of deferred tax assets is dependent upon sufficient
future taxable income during the period that deductible
temporary differences and carryforwards are expected to be
available to reduce taxable income.
As of March 31, 2005 and December 31, 2004 and 2003,
the deferred tax amounts mentioned above have been classified on
the accompanying balance sheets as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
March 31, | |
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Current liabilities
|
|
$ |
68,644 |
|
|
$ |
72,204 |
|
|
$ |
33,425 |
|
Noncurrent liabilities
|
|
|
136,593 |
|
|
|
132,577 |
|
|
|
78,566 |
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
205,237 |
|
|
$ |
204,781 |
|
|
$ |
111,991 |
|
|
|
|
|
|
|
|
|
|
|
The provision for income taxes charged to operation for the
three months ended March 31, 2005 and the years ended
December 31, 2004 and 2003 consists of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
March 31, | |
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Current tax expense
|
|
$ |
45,169 |
|
|
$ |
51,469 |
|
|
$ |
|
|
Deferred tax expense
|
|
|
457 |
|
|
|
92,790 |
|
|
|
37,121 |
|
Benefit of operating loss carryforward
|
|
|
|
|
|
|
(31,099 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
45,626 |
|
|
$ |
113,160 |
|
|
$ |
37,121 |
|
|
|
|
|
|
|
|
|
|
|
For the three months ended March 31, 2005 and the years
ended December 31, 2004 and 2003 the difference between the
expected tax expense that would result from applying domestic
federal statutory rates to pretax income and the provision for
income tax expense is due mainly to the lower average graduated
tax rate expected to apply to the estimated taxable income in
the years the temporary differences reverse as well as the
accrual of state income taxes.
F-108
W.T. ENTERPRISES, INC.
BALANCE SHEET
June 30, 2005
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
ASSETS |
Current Assets
|
|
|
|
|
|
|
|
|
|
Cash
|
|
$ |
153,254.16 |
|
|
|
|
|
|
Trade Receivables
|
|
|
422,900.00 |
|
|
|
|
|
|
Trade Receivables-WIP
|
|
|
111,225.00 |
|
|
|
|
|
|
Loans to Shareholder
|
|
|
6,242.36 |
|
|
|
|
|
|
Prepaid Expense
|
|
|
19,120.50 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Assets
|
|
|
|
|
|
$ |
712,742.02 |
|
Property and Equipment
|
|
|
|
|
|
|
|
|
|
Transportation Equipment
|
|
|
178,238.71 |
|
|
|
|
|
|
Machinery & Equipment
|
|
|
2,140,792.13 |
|
|
|
|
|
|
Office Furniture & Equipment
|
|
|
7,131.34 |
|
|
|
|
|
|
Accumulated Depreciation
|
|
|
(829,395.00 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Property and Equipment
|
|
|
|
|
|
|
1,496,767.18 |
|
|
|
|
|
|
|
|
|
|
|
Total Assets
|
|
|
|
|
|
$ |
2,209,509.20 |
|
|
|
|
|
|
|
|
LIABILITIES AND EQUITY |
Current Liabilities
|
|
|
|
|
|
|
|
|
|
Accounts Payable
|
|
$ |
85,265.16 |
|
|
|
|
|
|
Accrued Expenses
|
|
|
114,569.38 |
|
|
|
|
|
|
Income Tax Payable
|
|
|
80,329.09 |
|
|
|
|
|
|
Deferred Income Taxes
|
|
|
71,781.00 |
|
|
|
|
|
|
Notes Payable
|
|
|
246,301.98 |
|
|
|
|
|
|
Current Portion of L.T. Debt
|
|
|
206,298.26 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
|
|
|
$ |
804,544.87 |
|
Deferred Income Tax
|
|
|
|
|
|
|
158,816.00 |
|
Long-Term Debt, Net of Current Portion
|
|
|
|
|
|
|
16,014.91 |
|
Stockholders Equity
|
|
|
|
|
|
|
|
|
|
Common Stock, $10 Par Value
|
|
|
1,000.00 |
|
|
|
|
|
|
Retained Earnings
|
|
|
1,229,133.42 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders Equity
|
|
|
|
|
|
|
1,230,133.42 |
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities & Stockholders Equity
|
|
|
|
|
|
$ |
2,209,509.20 |
|
|
|
|
|
|
|
|
F-109
W.T. ENTERPRISES, INC.
STATEMENT OF INCOME AND RETAINED EARNINGS
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended | |
|
|
|
Six Months Ended | |
|
|
|
|
Jun. 30, 2005 | |
|
Pct | |
|
Jun. 30, 2004 | |
|
Pct | |
|
|
| |
|
| |
|
| |
|
| |
Revenue
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Service Revenue
|
|
$ |
1,949,131.25 |
|
|
|
100.00 |
|
|
$ |
1,839,365.00 |
|
|
|
100.00 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Revenue
|
|
|
1,949,131.25 |
|
|
|
100.00 |
|
|
|
1,839,365.00 |
|
|
|
100.00 |
|
Cost of Revenue
|
|
|
1,257,348.70 |
|
|
|
64.51 |
|
|
|
1,421,254.04 |
|
|
|
77.27 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross Profit
|
|
|
691,782.55 |
|
|
|
35.49 |
|
|
|
418,110.96 |
|
|
|
22.73 |
|
Operating Expenses
|
|
|
328,061.99 |
|
|
|
16.83 |
|
|
|
269,719.48 |
|
|
|
14.66 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income From Operations
|
|
|
363,720.56 |
|
|
|
18.66 |
|
|
|
148,391.48 |
|
|
|
8.07 |
|
Other Income (Expense)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest Income
|
|
|
168.77 |
|
|
|
0.01 |
|
|
|
343.36 |
|
|
|
0.02 |
|
|
Interest Expense
|
|
|
(16,139.41 |
) |
|
|
(0.83 |
) |
|
|
(24,819.02 |
) |
|
|
(1.35 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Other Income (Expense)
|
|
|
(15,970.64 |
) |
|
|
(0.82 |
) |
|
|
(24,475.66 |
) |
|
|
(1.33 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income Before Taxes
|
|
|
347,749.92 |
|
|
|
17.84 |
|
|
|
123,915.82 |
|
|
|
6.74 |
|
Income Taxes
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Income Tax
|
|
|
78,710.75 |
|
|
|
4.04 |
|
|
|
|
|
|
|
|
|
|
Deferred Income Taxes
|
|
|
25,816.00 |
|
|
|
1.32 |
|
|
|
23,830.00 |
|
|
|
1.30 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
104,526.75 |
|
|
|
5.36 |
|
|
|
23,830.00 |
|
|
|
1.30 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income
|
|
|
243,223.17 |
|
|
|
12.48 |
|
|
|
100,085.82 |
|
|
|
5.44 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Beginning Retained Earnings
|
|
|
985,910.25 |
|
|
|
|
|
|
|
558,852.46 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Ending Retained Earnings
|
|
$ |
1,229,133.42 |
|
|
|
|
|
|
$ |
658,938.28 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-110
W.T. ENTERPRISES, INC.
SCHEDULE OF COST OF REVENUE & OPERATING EXPENSES
For the Period Ended June 30, 2005 and 2004
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended | |
|
|
|
Six Months Ended | |
|
|
|
|
Jun. 30, 2005 | |
|
Pct | |
|
Jun. 30, 2004 | |
|
Pct | |
|
|
| |
|
| |
|
| |
|
| |
Cost of Revenue
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contract Air
|
|
|
191,500.00 |
|
|
|
9.83 |
|
|
|
352,300.00 |
|
|
|
19.15 |
|
|
Freight & Trucking
|
|
|
11,529.98 |
|
|
|
0.59 |
|
|
|
13,788.47 |
|
|
|
0.75 |
|
|
Auto Expense
|
|
|
57,800.36 |
|
|
|
2.97 |
|
|
|
57,554.74 |
|
|
|
3.13 |
|
|
Depreciation
|
|
|
148,285.00 |
|
|
|
7.61 |
|
|
|
110,875.00 |
|
|
|
6.03 |
|
|
Fuel
|
|
|
0.00 |
|
|
|
0.00 |
|
|
|
12,906.32 |
|
|
|
0.70 |
|
|
Insurance
|
|
|
27,634.49 |
|
|
|
1.42 |
|
|
|
21,697.12 |
|
|
|
1.18 |
|
|
Laundry/ Uniforms
|
|
|
1,365.96 |
|
|
|
0.07 |
|
|
|
5,223.46 |
|
|
|
0.28 |
|
|
Maintenance & Repairs
|
|
|
95,822.66 |
|
|
|
4.92 |
|
|
|
73,610.05 |
|
|
|
4.00 |
|
|
Equipment Rental
|
|
|
141,320.17 |
|
|
|
7.25 |
|
|
|
175,289.72 |
|
|
|
9.53 |
|
|
Subcontracting Other
|
|
|
2,942.50 |
|
|
|
0.15 |
|
|
|
1,800.00 |
|
|
|
0.10 |
|
|
Supplies
|
|
|
104,745.30 |
|
|
|
5.37 |
|
|
|
139,860.66 |
|
|
|
7.60 |
|
|
Taxes
|
|
|
34,631.08 |
|
|
|
1.78 |
|
|
|
33,779.21 |
|
|
|
1.84 |
|
|
Travel
|
|
|
2,666.50 |
|
|
|
0.14 |
|
|
|
0.00 |
|
|
|
22.97 |
|
|
Wages
|
|
|
437,054.70 |
|
|
|
22.42 |
|
|
|
422,569.29 |
|
|
|
22.97 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Cost of Revenue
|
|
$ |
1,257,348.70 |
|
|
|
64.51 |
|
|
$ |
1,421,254.04 |
|
|
|
77.27 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Expenses
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Advertising & Promotional
|
|
|
0.00 |
|
|
|
0.00 |
|
|
|
454.56 |
|
|
|
0.02 |
|
|
Bank Charges
|
|
|
0.00 |
|
|
|
0.00 |
|
|
|
632.62 |
|
|
|
0.03 |
|
|
Contract Labor
|
|
|
0.00 |
|
|
|
0.00 |
|
|
|
924.00 |
|
|
|
0.05 |
|
|
Car & Truck Expense
|
|
|
3,400.29 |
|
|
|
0.17 |
|
|
|
0.00 |
|
|
|
0.05 |
|
|
Contributions
|
|
|
2,250.00 |
|
|
|
0.12 |
|
|
|
1,000.00 |
|
|
|
0.05 |
|
|
Depreciation
|
|
|
3,635.00 |
|
|
|
0.19 |
|
|
|
3,341.00 |
|
|
|
0.18 |
|
|
Dues & Subscriptions
|
|
|
71.70 |
|
|
|
0.00 |
|
|
|
170.40 |
|
|
|
0.01 |
|
|
Insurance
|
|
|
21,057.11 |
|
|
|
1.08 |
|
|
|
20,040.54 |
|
|
|
1.09 |
|
|
Laundry & Uniforms
|
|
|
1,748.23 |
|
|
|
0.09 |
|
|
|
0.00 |
|
|
|
1.09 |
|
|
Life Insurance
|
|
|
288.00 |
|
|
|
0.01 |
|
|
|
269.00 |
|
|
|
0.01 |
|
|
Medical Reimbursement
|
|
|
0.00 |
|
|
|
0.00 |
|
|
|
3,621.06 |
|
|
|
0.20 |
|
|
Meals & Entertainment
|
|
|
7,604.96 |
|
|
|
0.39 |
|
|
|
1,441.28 |
|
|
|
0.08 |
|
|
Office Expense
|
|
|
936.47 |
|
|
|
0.05 |
|
|
|
1,510.61 |
|
|
|
0.08 |
|
|
Professional fees
|
|
|
5,171.03 |
|
|
|
0.27 |
|
|
|
1,054.00 |
|
|
|
0.06 |
|
|
Rent
|
|
|
6,026.48 |
|
|
|
0.31 |
|
|
|
6,938.15 |
|
|
|
0.38 |
|
|
Repairs & Maintenance
|
|
|
154.20 |
|
|
|
0.01 |
|
|
|
0.00 |
|
|
|
0.38 |
|
|
Supplies
|
|
|
497.90 |
|
|
|
0.03 |
|
|
|
40.00 |
|
|
|
0.00 |
|
|
Taxes
|
|
|
19,904.64 |
|
|
|
1.02 |
|
|
|
11,195.41 |
|
|
|
0.61 |
|
|
Travel
|
|
|
6,104.48 |
|
|
|
0.31 |
|
|
|
1,564.70 |
|
|
|
0.09 |
|
|
Utilities & Telephone
|
|
|
13,329.50 |
|
|
|
0.68 |
|
|
|
8,322.15 |
|
|
|
0.45 |
|
|
Wages
|
|
|
43,482.00 |
|
|
|
2.23 |
|
|
|
8,322.15 |
|
|
|
0.45 |
|
|
Salaries-Officers
|
|
|
192,400.00 |
|
|
|
9.87 |
|
|
|
207,200.00 |
|
|
|
11.26 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Expenses
|
|
$ |
328,061.99 |
|
|
|
16.83 |
|
|
$ |
269,719.48 |
|
|
|
14.66 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-111
W.T. ENTERPRISES, INC.
STATEMENT OF CASH FLOWS
For the Period Ended June 30, 2005 and 2004
(unaudited)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6 Months Ended | |
|
6 Months Ended | |
|
|
Jun. 30, 2005 | |
|
Jun. 30, 2004 | |
|
|
| |
|
| |
Cash Flow from Operating Activities
|
|
|
|
|
|
|
|
|
|
Net Income (Loss)
|
|
$ |
242,223.17 |
|
|
$ |
100,085.82 |
|
|
Adjustments to Reconcile Cash Flow
|
|
|
|
|
|
|
|
|
|
|
Depreciation
|
|
|
151,920.00 |
|
|
|
114,216.00 |
|
|
|
Deferred Income Tax
|
|
|
25,816.00 |
|
|
|
23,830.00 |
|
|
Decrease (Increase) in Current Assets
|
|
|
|
|
|
|
|
|
|
|
Trade Receivables
|
|
|
(4,610.00 |
) |
|
|
56,721.00 |
|
|
|
Trade Receivable WIP
|
|
|
(9,825.00 |
) |
|
|
(30,025.00 |
) |
|
|
Loans to Shareholder
|
|
|
3,432.23 |
|
|
|
2,959.58 |
|
|
|
Prepaid Expense
|
|
|
(7,527.57 |
) |
|
|
(321.51 |
) |
|
|
Prepaid Income Taxes
|
|
|
0.00 |
|
|
|
894.00 |
|
|
Increase (Decrease) in Current Liabilities
|
|
|
|
|
|
|
|
|
|
|
Accounts Payable
|
|
|
(32,662.73 |
) |
|
|
(19,411.84 |
) |
|
|
Accrued Expenses
|
|
|
65,522.20 |
|
|
|
2,781.13 |
|
|
|
Credit Cards Payable
|
|
|
66,650.50 |
|
|
|
10,690.02 |
|
|
|
|
|
|
|
|
|
|
|
Total Adjustments
|
|
|
258,714.63 |
|
|
|
162,333.38 |
|
|
|
|
|
|
|
|
|
|
|
Cash Provided (Used) by Operations
|
|
|
501,937.80 |
|
|
|
262,419.20 |
|
Cash Flow From Investing Activities
|
|
|
|
|
|
|
|
|
|
Sales (Purchases) of Assets
|
|
|
|
|
|
|
|
|
|
|
Machinery & Equipment
|
|
|
(314,139.87 |
) |
|
|
(397,016.47 |
) |
|
|
|
|
|
|
|
|
|
|
Cash Provided (Used) by Investing
|
|
|
(314,139.87 |
) |
|
|
(397,016.47 |
) |
Cash Flow From Financing Activities
|
|
|
|
|
|
|
|
|
|
Cash (Used) or provided by:
|
|
|
|
|
|
|
|
|
|
|
Short-Term Debt
|
|
|
159,537.27 |
|
|
|
42,475.87 |
|
|
|
Long-Term Debt
|
|
|
(243,775.81 |
) |
|
|
137,312.81 |
|
|
|
|
|
|
|
|
|
|
|
Cash Provided (Used) by Financing
|
|
|
(84,238.54 |
) |
|
|
179,788.68 |
|
|
|
|
|
|
|
|
|
|
|
Net Increase (Decrease) in Cash
|
|
|
103,559.39 |
|
|
|
45,191.41 |
|
|
|
|
Cash at Beginning of Period
|
|
|
49,694.77 |
|
|
|
39,821.42 |
|
|
|
|
|
|
|
|
|
|
|
Cash at End of Period
|
|
$ |
153,254.16 |
|
|
$ |
85,012.83 |
|
|
|
|
|
|
|
|
See accompanying accountants compilation report
F-112
INDEPENDENT AUDITORS REPORT
To the Shareholder
Specialty Rental Tools, Inc.
Broussard, Louisiana
We have audited the accompanying balance sheets of Specialty
Rental Tools, Inc. (the Company) as of
December 31, 2005, 2004 and 2003, and the related
statements of income, shareholders equity and cash flows
for the years then ended. These financial statements are the
responsibility of the Companys management. Our
responsibility is to express an opinion on these financial
statements based on our audits.
We conducted our audits in accordance with auditing standards
generally accepted in the United States of America. Those
standards require that we plan and perform the audits to obtain
reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in
the financial statements. An audit also includes assessing the
accounting principles used and significant estimates made by
management, as well as evaluating the overall financial
statement presentation. We believe that our audits provide a
reasonable basis for our opinion.
As discussed in Note J to the financial statements, the
accompanying financial statements have been restated.
In our opinion, the financial statements referred to above
present fairly, in all material respects, the financial position
of Specialty Rental Tools, Inc. as of December 31, 2005,
2004 and 2003, and the results of its operations and its cash
flows for the years then ended, in conformity with accounting
principles generally accepted in the United States of America.
Our audits were conducted for the purpose of forming an opinion
on the basic financial statements taken as a whole.
Schedule I is presented for purposes of additional analysis
and is not a required part of the basic financial statements.
Such information has been subjected to the auditing procedures
applied in the audits of the basic financial statements and, in
our opinion, is fairly stated in all material respects in
relation to the basic financial statements taken as a whole.
/s/ UHY Mann Frankfort Stein & Lipp CPAs, LLP
Houston, Texas
March 10, 2006, except for Note J, as to which the date is
July 14, 2006.
F-113
SPECIALTY RENTAL TOOLS, INC.
BALANCE SHEETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
(Restated) | |
|
|
|
|
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Assets
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
17,476,515 |
|
|
$ |
11,038,970 |
|
|
$ |
9,097,762 |
|
Trade receivables, net
|
|
|
7,253,603 |
|
|
|
5,437,713 |
|
|
|
3,206,942 |
|
Inventory
|
|
|
347,978 |
|
|
|
256,888 |
|
|
|
181,368 |
|
Prepaid expenses and other
|
|
|
63,266 |
|
|
|
82,256 |
|
|
|
66,910 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Assets
|
|
|
25,141,362 |
|
|
|
16,815,827 |
|
|
|
12,552,982 |
|
Property and Equipment, net
|
|
|
19,045,776 |
|
|
|
12,285,735 |
|
|
|
9,103,656 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets
|
|
$ |
44,187,138 |
|
|
$ |
29,101,562 |
|
|
$ |
21,656,638 |
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND SHAREHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
Current Liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$ |
1,379,752 |
|
|
$ |
1,217,857 |
|
|
$ |
1,280,641 |
|
Accrued liabilities
|
|
|
608,797 |
|
|
|
291,195 |
|
|
|
260,650 |
|
Current portion of notes payable
|
|
|
3,084,046 |
|
|
|
1,488,466 |
|
|
|
1,021,530 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
5,072,595 |
|
|
|
2,997,518 |
|
|
|
2,562,821 |
|
Notes Payable, less current portion
|
|
|
429,184 |
|
|
|
1,566,536 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities
|
|
|
5,501,779 |
|
|
|
4,564,054 |
|
|
|
2,562,821 |
|
Commitments and Contingencies
|
|
|
|
|
|
|
|
|
|
|
|
|
Shareholders Equity
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock
|
|
|
155,655 |
|
|
|
155,655 |
|
|
|
155,655 |
|
Treasury stock, at cost
|
|
|
(736,000 |
) |
|
|
(736,000 |
) |
|
|
(736,000 |
) |
Retained earnings
|
|
|
39,265,704 |
|
|
|
25,117,853 |
|
|
|
19,674,162 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Shareholders Equity
|
|
|
38,685,359 |
|
|
|
24,537,508 |
|
|
|
19,093,817 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities and Shareholders Equity
|
|
$ |
44,187,138 |
|
|
$ |
29,101,562 |
|
|
$ |
21,656,638 |
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to financial statements.
F-114
SPECIALTY RENTAL TOOLS, INC.
STATEMENTS OF INCOME
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
(Restated) | |
|
|
|
|
Revenues, Net
|
|
$ |
32,708,504 |
|
|
$ |
19,345,433 |
|
|
$ |
17,662,475 |
|
Expenses
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales
|
|
|
5,103,071 |
|
|
|
2,954,085 |
|
|
|
3,166,356 |
|
General and administrative
|
|
|
7,232,127 |
|
|
|
5,218,634 |
|
|
|
4,857,507 |
|
Depreciation
|
|
|
3,447,210 |
|
|
|
2,434,682 |
|
|
|
2,543,332 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Expenses
|
|
|
15,782,408 |
|
|
|
10,607,401 |
|
|
|
10,567,195 |
|
|
|
|
|
|
|
|
|
|
|
Income from Operations
|
|
|
16,926,096 |
|
|
|
8,738,032 |
|
|
|
7,095,280 |
|
Other Income (Expense)
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
136,597 |
|
|
|
46,173 |
|
|
|
66,282 |
|
Interest expense
|
|
|
(184,856 |
) |
|
|
(11,987 |
) |
|
|
(58,442 |
) |
Other, net
|
|
|
72,515 |
|
|
|
(76,917 |
) |
|
|
(95,327 |
) |
|
|
|
|
|
|
|
|
|
|
|
Total Other Income (Expense)
|
|
|
24,256 |
|
|
|
(42,731 |
) |
|
|
(87,487 |
) |
|
|
|
|
|
|
|
|
|
|
|
Net Income
|
|
$ |
16,950,352 |
|
|
$ |
8,695,301 |
|
|
$ |
7,007,793 |
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to financial statements.
F-115
SPECIALTY RENTAL TOOLS, INC.
STATEMENTS OF SHAREHOLDERS EQUITY
YEARS ENDED DECEMBER 31, 2005, 2004 AND 2003
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common Stock | |
|
|
|
|
|
|
|
|
| |
|
Treasury | |
|
Retained | |
|
|
|
|
Shares | |
|
Amount | |
|
Stock | |
|
Earnings | |
|
Total | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
Balance, January 1, 2003
|
|
|
225 |
|
|
$ |
155,655 |
|
|
$ |
(736,000 |
) |
|
$ |
25,467,954 |
|
|
$ |
24,887,609 |
|
Net income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,007,793 |
|
|
|
7,007,793 |
|
Distributions
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(12,801,585 |
) |
|
|
(12,801,585 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, December 31, 2003
|
|
|
225 |
|
|
|
155,655 |
|
|
|
(736,000 |
) |
|
|
19,674,162 |
|
|
|
19,093,817 |
|
Net income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
8,695,301 |
|
|
|
8,695,301 |
|
Distributions
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(3,251,610 |
) |
|
|
(3,251,610 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, December 31, 2004
|
|
|
225 |
|
|
|
155,655 |
|
|
|
(736,000 |
) |
|
|
25,117,853 |
|
|
|
24,537,508 |
|
Net income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
16,950,352 |
|
|
|
16,950,352 |
|
Distributions
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(2,802,501 |
) |
|
|
(2,802,501 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance, December 31, 2005 (Restated)
|
|
|
225 |
|
|
$ |
155,655 |
|
|
$ |
(736,000 |
) |
|
$ |
39,265,704 |
|
|
$ |
38,685,359 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to financial statements.
F-116
SPECIALTY RENTAL TOOLS, INC.
STATEMENTS OF CASH FLOWS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
(Restated) | |
|
|
|
|
Cash Flows from Operating Activities
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
16,950,352 |
|
|
$ |
8,695,301 |
|
|
$ |
7,007,793 |
|
Adjustments to reconcile net income to net cash provided by
operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation
|
|
|
3,447,210 |
|
|
|
2,434,682 |
|
|
|
2,543,332 |
|
|
Gain on sale of assets
|
|
|
(1,865,949 |
) |
|
|
(1,098,488 |
) |
|
|
(332,431 |
) |
Changes in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Receivables
|
|
|
(1,815,890 |
) |
|
|
(2,230,771 |
) |
|
|
777,986 |
|
|
Inventory
|
|
|
(91,090 |
) |
|
|
(75,520 |
) |
|
|
78,267 |
|
|
Prepaid expenses and other
|
|
|
18,990 |
|
|
|
(15,346 |
) |
|
|
(14,604 |
) |
|
Accounts payable
|
|
|
161,895 |
|
|
|
(62,784 |
) |
|
|
43,879 |
|
|
Accrued liabilities
|
|
|
317,602 |
|
|
|
30,545 |
|
|
|
10,519 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operating activities
|
|
|
17,123,120 |
|
|
|
7,677,619 |
|
|
|
10,114,741 |
|
Cash Flows from Investing Activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchase of property and equipment
|
|
|
(11,429,761 |
) |
|
|
(5,796,433 |
) |
|
|
(921,949 |
) |
|
Proceeds from sale of property and equipment
|
|
|
3,135,857 |
|
|
|
1,334,493 |
|
|
|
1,088,038 |
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by (used in) investing activities
|
|
|
(8,293,904 |
) |
|
|
(4,461,940 |
) |
|
|
166,089 |
|
Cash Flows from Financing Activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributions to shareholder
|
|
|
(2,802,501 |
) |
|
|
(3,251,610 |
) |
|
|
(12,801,585 |
) |
|
Proceeds from notes payable
|
|
|
3,000,000 |
|
|
|
3,000,000 |
|
|
|
|
|
|
Repayment of notes payable
|
|
|
(2,589,170 |
) |
|
|
(1,022,861 |
) |
|
|
(1,493,440 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in financing activities
|
|
|
(2,391,671 |
) |
|
|
(1,274,471 |
) |
|
|
(14,295,025 |
) |
|
|
|
|
|
|
|
|
|
|
Net Increase (Decrease) in Cash and Cash Equivalents
|
|
|
6,437,545 |
|
|
|
1,941,208 |
|
|
|
(4,014,195 |
) |
Cash and cash equivalents Beginning of year
|
|
|
11,038,970 |
|
|
|
9,097,762 |
|
|
|
13,111,957 |
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents End of year
|
|
$ |
17,476,515 |
|
|
$ |
11,038,970 |
|
|
$ |
9,097,762 |
|
|
|
|
|
|
|
|
|
|
|
Supplemental Cash Flow Information
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for interest
|
|
$ |
184,856 |
|
|
$ |
11,987 |
|
|
$ |
58,442 |
|
|
|
|
|
|
|
|
|
|
|
See accompanying notes to financial statements.
F-117
SPECIALTY RENTAL TOOLS, INC.
NOTES TO FINANCIAL STATEMENTS
DECEMBER 31, 2005, 2004 AND 2003
Note A Nature of Operations
Specialty Rental Tools, Inc. (the Company) leases
drill pipe, tubing, handling equipment, pressure control
equipment, drill collars and other oilfield equipment to both
major and independent petroleum exploration and production
companies for use in drilling, completion and work-over
operations. The Company is located in Broussard, Louisiana, and
leases equipment to companies throughout the Gulf Coast Region.
The Company was incorporated in the State of Louisiana in
December 1978.
Note B Summary of Significant Accounting
Policies
Use of Estimates: The preparation of financial statements
in conformity with accounting principles generally accepted in
the United States of America requires management to make
estimates and assumptions that affect the amounts reported in
the financial statements and accompanying notes. Actual results
could differ from those estimates.
Revenue Recognition: Rental equipment is leased to
customers at per day and per job contractual rates. Net revenues
are determined by deducting sales discounts from gross sales.
Payments from customers for the cost of oilfield rental
equipment that is damaged or lost-in-hole are reflected as
revenues with the carrying value of the related equipment
charged to cost of sales.
Cash and Cash Equivalents: The Company considers all
highly liquid investments with an original maturity of three
months or less at the time of purchase to be cash equivalents.
Accounts Receivable: The Company uses the allowance
method to account for uncollectible accounts receivable. The
Company establishes an allowance for doubtful accounts based on
factors surrounding credit risk of debtors, historical factors
and other related information. The allowance for doubtful
accounts was $55,994, $35,087 and $38,266 at December 31,
2005, 2004 and 2003, respectively.
Concentrations of Credit and Other Risks: Financial
instruments which potentially subject the Company to
concentrations of credit risk consist principally of cash and
accounts receivables. The Company maintains its cash in bank
deposits with a financial institution. These accounts exceed
federally insured limits. Deposits in the United States are
guaranteed by the Federal Deposit Insurance Corporation
(FDIC) up to $100,000. The Company monitors the
financial condition of the financial institution and has not
experienced any losses on such accounts.
The Company is not party to any financial instruments which
would have off-balance sheet credit or interest rate risk.
Inventory: Inventory consists primarily of supplies and
materials used to repair and maintain rental equipment.
Inventory is valued using the first-in, first-out method and
stated at the lower of cost or market.
Property and Equipment: Property and equipment are stated
at cost. Depreciation of property and equipment is computed
using the straight-line method over the estimated useful lives
of the assets, ranging from 5 to 39 years. Expenditures for
major renewals and betterments, which extend the original
F-118
SPECIALTY RENTAL TOOLS, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
estimated economic useful lives of applicable assets, are
capitalized. Expenditures for normal repairs and maintenance are
charged to expense as incurred and are often billed back to
customers as allowed by rental contracts. The costs and related
accumulated depreciation of assets sold or retired are removed
from the accounts, and any gain or loss thereon is reflected in
operations.
The Company periodically evaluates the recoverability of the
carrying value of its property and equipment whenever events or
changes in circumstances indicate that the carrying amount of
the asset may not be recoverable.
Income Taxes: The Companys shareholder has elected
to be taxed as a small business corporation under the provisions
of Subchapter S of the Internal Revenue Code. Accordingly,
federal income tax is the responsibility of the individual
shareholder, and no provision for federal income tax is included
in the accompanying financial statements.
Advertising: The Companys policy is to expense
advertising costs as incurred and amounted to approximately
$254,000, $196,000 and $245,000 for years ended
December 31, 2005, 2004 and 2003, respectively.
Major Customers: For the year ended December 31,
2005, 51% of the Companys revenues were generated from two
unrelated customers, and trade receivables from those customers
totaled $2,869,316 at December 31, 2005. For the year ended
December 31, 2004, 43% of the Companys revenues were
generated from one unrelated customer, and trade receivables
from this customer were $2,665,365 at December 31, 2004.
For the year ended December 31, 2003, 50% of the
Companys revenues were generated from two unrelated
customers.
Note C Property and Equipment
Property and equipment consists of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Estimated | |
|
December 31, | |
|
|
Useful | |
|
| |
|
|
Lives | |
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
| |
Rental equipment
|
|
|
7 - 10 years |
|
|
$ |
37,346,425 |
|
|
$ |
27,390,801 |
|
|
$ |
23,338,565 |
|
Automobiles
|
|
|
5 years |
|
|
|
508,535 |
|
|
|
410,094 |
|
|
|
330,734 |
|
Furniture and fixtures
|
|
|
5 - 7 years |
|
|
|
12,369 |
|
|
|
12,369 |
|
|
|
1,835 |
|
Leasehold improvements
|
|
|
15 - 39 years |
|
|
|
161,091 |
|
|
|
161,091 |
|
|
|
105,426 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
38,028,420 |
|
|
|
27,974,355 |
|
|
|
23,776,560 |
|
Less: accumulated depreciation
|
|
|
|
|
|
|
(18,982,644 |
) |
|
|
(15,688,620 |
) |
|
|
(14,672,904 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
19,045,776 |
|
|
$ |
12,285,735 |
|
|
$ |
9,103,656 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-119
SPECIALTY RENTAL TOOLS, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
Note D Notes Payable
Notes payable consist of the following:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Note payable to bank (1)
|
|
$ |
|
|
|
$ |
|
|
|
$ |
1,021,530 |
|
Note payable to bank (2)
|
|
|
1,531,520 |
|
|
|
3,000,000 |
|
|
|
|
|
Note payable to bank (3)
|
|
|
1,907,252 |
|
|
|
|
|
|
|
|
|
Note payable to GMAC (4)
|
|
|
34,869 |
|
|
|
55,002 |
|
|
|
|
|
Note payable to Ford Credit (5)
|
|
|
39,589 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,513,230 |
|
|
|
3,055,002 |
|
|
|
1,021,530 |
|
Less: current portion
|
|
|
3,084,046 |
|
|
|
1,488,466 |
|
|
|
1,021,530 |
|
|
|
|
|
|
|
|
|
|
|
Total notes payable long-term
|
|
$ |
429,184 |
|
|
$ |
1,566,536 |
|
|
$ |
|
|
|
|
|
|
|
|
|
|
|
|
Future maturities of long-term debt as of December 31, 2005
are as follows:
|
|
|
|
|
Year Ending December 31, |
|
|
|
|
|
2006
|
|
$ |
3,084,046 |
|
2007
|
|
|
421,199 |
|
2008
|
|
|
7,985 |
|
|
|
|
|
|
|
$ |
3,513,230 |
|
|
|
|
|
In August 2002, the Company raised $3,000,000 under a note
payable agreement from Iberia Bank, a financial institution in
Louisiana. The note bore interest at a rate of prime less 1% and
was payable in installments over 24 months. The Company
repaid the note in August 2004.
In December 2004, the Company raised $3,000,000 under a note
payable agreement from Iberia Bank, a financial institution in
Louisiana. The note bears interest at a rate of 4.2% per annum
and is being repaid through monthly principal and interest
payments totaling $130,617. Under the terms of the note payable
agreement, the note was due in December 2006. The Company repaid
the note in January 2006.
In February 2005, the Company raised $3,000,000 under a note
payable agreement from Iberia Bank, a financial institution in
Louisiana. The note bears interest at a rate of 4.2% per annum
and is being repaid through monthly principal and interest
payments totaling $130,818. Under the terms of the note payable
agreement, the note was due in March 2007. The Company repaid
the note in January 2006.
F-120
SPECIALTY RENTAL TOOLS, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
In October 2004, the Company financed the purchase of a vehicle
through a $56,333 note payable agreement with GMAC. The note is
non-interest bearing and is being repaid through monthly
principal payments of $1,565. The note is due in November 2007.
|
|
|
(5) Note Payable to
Ford Credit |
In June 2005, the Company financed the purchase of a vehicle
through a $47,398 note payable agreement with Ford Credit. The
note bears interest at a rate of 0.9% per annum and is being
repaid through monthly principal and interest payments totaling
$1,335. The note is due in June 2008.
Note E Shareholders Equity
Common Stock: The Company is authorized to issue 10,000
shares of common stock that has no par value. As of
December 31, 2005, 2004 and 2003, the Company had 2,500
shares issued and 225 common shares outstanding.
Treasury Stock: The Company has repurchased common stock
as treasury stock. As of December 31, 2005, 2004 and 2003,
the Company owned 2,275 shares of treasury stock.
Note F Profit Sharing Plan
The Company sponsors a profit sharing plan (the
Plan) which covers all eligible employees. Company
contributions to the Plan are discretionary. The Plan vests one
hundred percent (100%) after six or more years of continuing
service. During the years ended December 31, 2005, 2004 and
2003, the Company made contributions of approximately $175,000,
$163,000 and $155,000 respectively, to the Plan.
Note G Related Party Transactions
The Company paid the shareholder $648,000, $288,000 and $144,000
for the years ended December 31, 2005, 2004 and 2003,
respectively, for rent expense on the Companys operating
facilities in Broussard, Louisiana.
Note H Non-Cash Investing and Financing
Activities
The following non-cash transaction took place during the year
ended December 31, 2005:
|
|
|
|
|
The Company acquired an automobile for $47,398, which was funded
through a note payable instrument. |
The following non-cash transaction took place during the year
ended December 31, 2004:
|
|
|
|
|
The Company acquired an automobile for $56,333, which was funded
through a note payable instrument. |
Note I Subsequent Events
On January 18, 2006 the Company was acquired by
Allis-Chalmers Energy, Inc. through a 100% stock purchase
agreement for $96.0 million in cash. The Companys
financial statements have not been modified as a result of this
transaction.
F-121
SPECIALTY RENTAL TOOLS, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
On January 16, 2006 the Company repaid the outstanding
balance of Note 2 and Note 3 as stated in Note D
of the financial statements.
Note J Restatement
At December 31, 2005 the Company had accrued approximately
$12,400,000 in bonuses payable to certain employees upon
acquisition of the Company by Allis-Chalmers Energy, Inc. The
employee bonuses were contingent upon the acquisition of the
Company, which was not consummated until January 18, 2006,
therefore no liability existed as of December 31, 2005.
Accordingly, the Company restated its financial statements to
reverse the accrual of approximately $12,400,000 at
December 31, 2005.
A restated balance sheet at December 31, 2005, a restated
statement of income, and restated statement of cash flows for
the year ended December 31, 2005, reflecting the above
adjustment is presented below.
F-122
SPECIALTY RENTAL TOOLS, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2005 | |
|
|
| |
|
|
As Reported | |
|
Adjustments | |
|
As Restated | |
|
|
| |
|
| |
|
| |
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CURRENT ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
17,476,515 |
|
|
$ |
|
|
|
$ |
17,476,515 |
|
|
Trade receivables, net
|
|
|
7,253,603 |
|
|
|
|
|
|
|
7,253,603 |
|
|
Inventory
|
|
|
347,978 |
|
|
|
|
|
|
|
347,978 |
|
|
Prepaid expenses and other
|
|
|
63,266 |
|
|
|
|
|
|
|
63,266 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL CURRENT ASSETS
|
|
|
25,141,362 |
|
|
|
|
|
|
|
25,141,362 |
|
|
PROPERTY AND EQUIPMENT, net
|
|
|
19,045,776 |
|
|
|
|
|
|
|
19,045,776 |
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL ASSETS
|
|
$ |
44,187,138 |
|
|
$ |
|
|
|
$ |
44,187,138 |
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND SHAREHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CURRENT LIABILITIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable
|
|
$ |
1,379,752 |
|
|
$ |
|
|
|
$ |
1,379,752 |
|
|
Accrued liabilities
|
|
|
13,008,797 |
|
|
|
(12,400,000 |
) |
|
|
608,797 |
|
|
Current portion of notes payable
|
|
|
3,084,046 |
|
|
|
|
|
|
|
3,084,046 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL CURRENT LIABILITIES
|
|
|
17,472,595 |
|
|
|
(12,400,000 |
) |
|
|
5,072,595 |
|
|
NOTES PAYABLE, less current portion
|
|
|
429,184 |
|
|
|
|
|
|
|
429,184 |
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES
|
|
|
17,901,779 |
|
|
|
(12,400,000 |
) |
|
|
5,501,779 |
|
|
COMMITMENTS AND CONTINGENCIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
SHAREHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock
|
|
|
155,655 |
|
|
|
|
|
|
|
155,655 |
|
|
Treasury stock, at cost
|
|
|
(736,000 |
) |
|
|
|
|
|
|
(736,000 |
) |
|
Retained earnings
|
|
|
26,865,704 |
|
|
|
12,400,000 |
|
|
|
39,265,704 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL SHAREHOLDERS DEFICIT
|
|
|
26,285,359 |
|
|
|
12,400,000 |
|
|
|
38,685,359 |
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES AND SHAREHOLDERS EQUITY
|
|
$ |
44,187,138 |
|
|
$ |
|
|
|
$ |
44,187,138 |
|
|
|
|
|
|
|
|
|
|
|
F-123
SPECIALTY RENTAL TOOLS, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2005 | |
|
|
| |
|
|
As Reported | |
|
Adjustments | |
|
As Restated | |
|
|
| |
|
| |
|
| |
REVENUES, NET
|
|
$ |
32,708,504 |
|
|
$ |
|
|
|
$ |
32,708,504 |
|
EXPENSES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cost of sales
|
|
|
5,103,071 |
|
|
|
|
|
|
|
5,103,071 |
|
|
General and administrative
|
|
|
19,632,127 |
|
|
|
(12,400,000 |
) |
|
|
7,232,127 |
|
|
Depreciation
|
|
|
3,447,210 |
|
|
|
|
|
|
|
3,447,210 |
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL EXPENSES
|
|
|
28,182,408 |
|
|
|
(12,400,000 |
) |
|
|
15,782,408 |
|
|
|
|
|
|
|
|
|
|
|
INCOME FROM OPERATIONS
|
|
|
4,526,096 |
|
|
|
12,400,000 |
|
|
|
16,926,096 |
|
OTHER INCOME (EXPENSE)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
136,597 |
|
|
|
|
|
|
|
136,597 |
|
|
Interest expense
|
|
|
(184,856 |
) |
|
|
|
|
|
|
(184,856 |
) |
|
Other, net
|
|
|
72,515 |
|
|
|
|
|
|
|
72,515 |
|
|
|
|
|
|
|
|
|
|
|
|
|
TOTAL OTHER INCOME (EXPENSE)
|
|
|
24,256 |
|
|
|
|
|
|
|
24,256 |
|
|
|
|
|
|
|
|
|
|
|
NET INCOME
|
|
$ |
4,550,352 |
|
|
$ |
12,400,000 |
|
|
$ |
16,950,352 |
|
|
|
|
|
|
|
|
|
|
|
F-124
SPECIALTY RENTAL TOOLS, INC.
NOTES TO FINANCIAL STATEMENTS (Continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2005 | |
|
|
| |
|
|
As Reported | |
|
Adjustments | |
|
As Restated | |
|
|
| |
|
| |
|
| |
CASH FLOWS FROM OPERATING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income
|
|
$ |
4,550,352 |
|
|
$ |
12,400,000 |
|
|
$ |
16,950,352 |
|
Adjustments to reconcile net income to net cash used in
operating activities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation
|
|
|
3,447,210 |
|
|
|
|
|
|
|
3,447,210 |
|
|
Gain on sale of assets
|
|
|
(1,865,949 |
) |
|
|
|
|
|
|
(1,865,949 |
) |
Changes in operating assets and liabilities:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Receivables
|
|
|
(1,815,890 |
) |
|
|
|
|
|
|
(1,815,890 |
) |
|
Inventory
|
|
|
(91,090 |
) |
|
|
|
|
|
|
(91,090 |
) |
|
Prepaid Expenses and other
|
|
|
18,990 |
|
|
|
|
|
|
|
18,990 |
|
|
Accounts Payable
|
|
|
161,895 |
|
|
|
|
|
|
|
161,895 |
|
|
Accrued liabilities
|
|
|
12,717,602 |
|
|
|
(12,400,000 |
) |
|
|
317,602 |
|
|
|
|
|
|
|
|
|
|
|
|
|
NET CASH PROVIDED BY OPERATING ACTIVITIES
|
|
|
17,123,120 |
|
|
|
|
|
|
|
17,123,120 |
|
|
CASH FLOWS FROM INVESTING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Purchase of property and equipment
|
|
|
(11,429,761 |
) |
|
|
|
|
|
|
(11,429,761 |
) |
|
Proceeds from sale of property and equipment
|
|
|
3,135,857 |
|
|
|
|
|
|
|
3,135,857 |
|
|
|
|
|
|
|
|
|
|
|
|
|
NET CASH USED IN INVESTING ACTIVITIES
|
|
|
(8,293,904 |
) |
|
|
|
|
|
|
(8,293,904 |
) |
|
CASH FLOWS FROM FINANCING ACTIVITIES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Distributions to shareholder
|
|
|
(2,802,501 |
) |
|
|
|
|
|
|
(2,802,501 |
) |
|
Proceeds from notes payable
|
|
|
3,000,000 |
|
|
|
|
|
|
|
3,000,000 |
|
|
Repayment of notes payable
|
|
|
(2,589,170 |
) |
|
|
|
|
|
|
(2,391,671 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
NET CASH USED IN FINANCING ACTIVITIES
|
|
|
(2,391,671 |
) |
|
|
|
|
|
|
(2,391,671 |
) |
|
|
|
|
|
|
|
|
|
|
|
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
|
|
|
6,437,545 |
|
|
|
|
|
|
|
6,437,545 |
|
|
CASH AND CASH EQUIVALENTS BEGINNING OF YEAR
|
|
|
11,038,970 |
|
|
|
|
|
|
|
11,038,970 |
|
|
|
|
|
|
|
|
|
|
|
|
CASH AND CASH EQUIVALENTS END OF YEAR
|
|
$ |
17,476,515 |
|
|
$ |
|
|
|
$ |
17,476,515 |
|
|
|
|
|
|
|
|
|
|
|
|
SUPPLEMENTAL CASH FLOW INFORMATION
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash paid for interest
|
|
$ |
186,856 |
|
|
$ |
|
|
|
$ |
186,856 |
|
|
|
|
|
|
|
|
|
|
|
F-125
SPECIALTY RENTAL TOOLS, INC.
SCHEDULE I SCHEDULE OF GENERAL AND ADMINISTRATIVE
EXPENSES
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
|
|
(Restated) | |
|
|
|
|
Salaries and wages
|
|
$ |
2,808,822 |
|
|
$ |
2,449,073 |
|
|
$ |
2,340,807 |
|
Retirement plan expenses
|
|
|
174,863 |
|
|
|
163,261 |
|
|
|
155,409 |
|
Selling expenses
|
|
|
486,323 |
|
|
|
325,595 |
|
|
|
292,420 |
|
Shop supplies
|
|
|
774,694 |
|
|
|
500,783 |
|
|
|
571,038 |
|
Shop maintenance
|
|
|
321,111 |
|
|
|
43,691 |
|
|
|
46,767 |
|
Rent
|
|
|
648,000 |
|
|
|
288,257 |
|
|
|
180,000 |
|
Insurance
|
|
|
461,198 |
|
|
|
404,886 |
|
|
|
345,318 |
|
Automobile expenses
|
|
|
242,276 |
|
|
|
161,549 |
|
|
|
145,333 |
|
Advertising
|
|
|
253,624 |
|
|
|
196,037 |
|
|
|
244,695 |
|
Taxes, licenses and other
|
|
|
565,751 |
|
|
|
377,022 |
|
|
|
415,390 |
|
Bad debt expense, net of recoveries
|
|
|
103,609 |
|
|
|
81,389 |
|
|
|
(59,220 |
) |
Office expense
|
|
|
57,424 |
|
|
|
49,648 |
|
|
|
26,814 |
|
Uniforms
|
|
|
25,555 |
|
|
|
17,971 |
|
|
|
19,800 |
|
Utilities
|
|
|
88,091 |
|
|
|
115,565 |
|
|
|
69,006 |
|
Dues and subscriptions
|
|
|
8,083 |
|
|
|
7,375 |
|
|
|
8,956 |
|
Professional fees
|
|
|
211,563 |
|
|
|
34,739 |
|
|
|
52,112 |
|
Other
|
|
|
1,140 |
|
|
|
1,793 |
|
|
|
2,862 |
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
$ |
7,232,127 |
|
|
$ |
5,218,634 |
|
|
$ |
4,857,507 |
|
|
|
|
|
|
|
|
|
|
|
F-126
INDEPENDENT AUDITORS REPORT
To the Board of Directors and Shareholders of
DLS Drilling, Logistics & Services Corporation
We have audited the accompanying consolidated balance sheets of
DLS Drilling, Logistics & Services Corporation as of
December 31, 2005 and 2004 and the related consolidated
statements of income, stockholders equity and cash flows
for each of the years in the three-year period ended
December 31, 2005. These consolidated financial statements
are the responsibility of the Companys management. Our
responsibility is to express an opinion on these consolidated
financial statements based on our audits.
We conducted our audits in accordance with auditing standards
generally accepted in the United States of America. Those
standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are
free of material misstatement. An audit includes consideration
of internal control over financial reporting as a basis for
designing audit procedures that are appropriate in the
circumstances, but not for the purpose of expressing an opinion
on the effectiveness of the Companys internal control over
financial reporting. Accordingly, we express no such opinion. An
audit also includes examining, on a test basis, evidence
supporting the amounts and disclosures in the financial
statements, assessing the accounting principles used and
significant estimates made by management, as well as evaluating
the overall financial statement presentation. We believe that
our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred
to above present fairly, in all material respects, the
consolidated financial position of DLS Drilling,
Logistics & Services Corporation as of
December 31, 2005 and 2004, and the consolidated results of
their operations, changes in stockholders equity and cash
flows for each of the years in the three-year period ended
December 31, 2005, in conformity with generally accepted
accounting principles in the United States of America.
Buenos Aires, Argentina
March 2, 2006, except in respect of Note 22 for which the
date is June 9, 2006.
Sibille
/s/ Ariel S. Eisenstein
Partner
F-127
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
CONSOLIDATED BALANCE SHEETS
Amounts expressed in thousands of US Dollars
|
|
|
|
|
|
|
|
|
|
|
|
December 31, | |
|
December 31, | |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
ASSETS |
Current Assets
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents (Note 4)
|
|
|
731 |
|
|
|
1,496 |
|
|
Accounts receivable (Note 5)
|
|
|
26,826 |
|
|
|
19,970 |
|
|
Parts and supplies (Note 6)
|
|
|
16,640 |
|
|
|
16,110 |
|
|
Prepaid expenses and other current assets (Note 7)
|
|
|
4,069 |
|
|
|
4,713 |
|
|
Assets of discontinued operations (Note 22)
|
|
|
7,276 |
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Assets
|
|
|
55,542 |
|
|
|
42,289 |
|
|
|
|
|
|
|
|
Non-Current Assets
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net (Note 8)
|
|
|
110,510 |
|
|
|
97,799 |
|
|
Assets of discontinued operations
|
|
|
|
|
|
|
12,659 |
|
|
Investments
|
|
|
2 |
|
|
|
2 |
|
|
|
|
|
|
|
|
Total Non-Current Assets
|
|
|
110,512 |
|
|
|
110,460 |
|
|
|
|
|
|
|
|
TOTAL
|
|
|
166,054 |
|
|
|
152,749 |
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY |
|
Current Liabilities
|
|
|
|
|
|
|
|
|
|
Trade accounts payable and accrued expenses (Note 9)
|
|
|
13,522 |
|
|
|
12,209 |
|
|
Short-term debt (Note 10)
|
|
|
8,690 |
|
|
|
19,430 |
|
|
Payroll and accrued taxes (Note 11)
|
|
|
7,976 |
|
|
|
6,948 |
|
|
Other liabilities (Note 12)
|
|
|
9,188 |
|
|
|
1,816 |
|
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
39,376 |
|
|
|
40,403 |
|
|
|
|
|
|
|
|
Non-Current Liabilities
|
|
|
|
|
|
|
|
|
|
Other liabilities (Note 12)
|
|
|
782 |
|
|
|
14,167 |
|
|
Long-term debt (Note 13)
|
|
|
29,640 |
|
|
|
12,846 |
|
|
Deferred income tax liability (Note 14)
|
|
|
696 |
|
|
|
526 |
|
|
|
|
|
|
|
|
Total Non-Current Liabilities
|
|
|
31,118 |
|
|
|
27,539 |
|
|
|
|
|
|
|
|
TOTAL LIABILITIES
|
|
|
70,494 |
|
|
|
67,942 |
|
|
|
|
|
|
|
|
Stockholders Equity
|
|
|
|
|
|
|
|
|
|
Common stock (Note 3)
|
|
|
42,963 |
|
|
|
42,963 |
|
|
Additional paid-in capital (Note 3)
|
|
|
31,606 |
|
|
|
27,466 |
|
|
Retained earnings
|
|
|
20,991 |
|
|
|
14,378 |
|
|
|
|
|
|
|
|
TOTAL STOCKHOLDERS EQUITY
|
|
|
95,560 |
|
|
|
84,807 |
|
|
|
|
|
|
|
|
TOTAL
|
|
|
166,054 |
|
|
|
152,749 |
|
|
|
|
|
|
|
|
See the accompanying notes to the consolidated financial
statements
F-128
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
CONSOLIDATED STATEMENTS OF INCOME
Amounts expressed in thousands of US Dollars
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Sales and Other Operating Revenues (Note 15)
|
|
|
129,849 |
|
|
|
112,272 |
|
|
|
96,084 |
|
Operating Costs and Expenses (Note 16)
|
|
|
(113,351 |
) |
|
|
(98,366 |
) |
|
|
(83,727 |
) |
|
|
|
|
|
|
|
|
|
|
Gross Profit
|
|
|
16,498 |
|
|
|
13,906 |
|
|
|
12,357 |
|
General and Administrative Expenses
|
|
|
(3,933 |
) |
|
|
(3,430 |
) |
|
|
(3,140 |
) |
|
|
|
|
|
|
|
|
|
|
Operating Income
|
|
|
12,565 |
|
|
|
10,476 |
|
|
|
9,217 |
|
Net Financial Expenses (Note 16)
|
|
|
(5,394 |
) |
|
|
(4,585 |
) |
|
|
(4,030 |
) |
Other Income (Expenses) (Note 16)
|
|
|
7,127 |
|
|
|
1,000 |
|
|
|
(166 |
) |
|
|
|
|
|
|
|
|
|
|
Income from Continuing Operations Before Income Tax
|
|
|
14,298 |
|
|
|
6,891 |
|
|
|
5,021 |
|
Income Tax (Note 14)
|
|
|
(3,547 |
) |
|
|
(3,030 |
) |
|
|
(3,907 |
) |
|
|
|
|
|
|
|
|
|
|
Income from Continuing Operations
|
|
|
10,751 |
|
|
|
3,861 |
|
|
|
1,114 |
|
Loss on Discounted Operations, net of Income Tax Benefit of
$2,228, $705, and $0, respectively (Note 22)
|
|
|
(4,138 |
) |
|
|
(1,309 |
) |
|
|
0 |
|
|
|
|
|
|
|
|
|
|
|
Net Income
|
|
|
6,613 |
|
|
|
2,552 |
|
|
|
1,114 |
|
|
|
|
|
|
|
|
|
|
|
See the accompanying notes to the consolidated financial
statements
F-129
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
CONSOLIDATED STATEMENTS OF STOCKHOLDERS EQUITY
Amounts expressed in thousands of US Dollars
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated | |
|
|
|
|
|
|
Common Stock | |
|
|
|
other | |
|
|
|
|
|
|
| |
|
Paid-in | |
|
comprehensive | |
|
Retained | |
|
|
Description |
|
Shares | |
|
Amount | |
|
Capital | |
|
income | |
|
Earnings | |
|
Total | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
2003
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Opening Balance
|
|
|
42,963,374 |
|
|
|
42,963 |
|
|
|
27,466 |
|
|
|
|
|
|
|
10,712 |
|
|
|
81,141 |
|
Net income for fiscal year 2003
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,114 |
|
|
|
1,114 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2003
|
|
|
42,963,374 |
|
|
|
42,963 |
|
|
|
27,466 |
|
|
|
|
|
|
|
11,826 |
|
|
|
82,255 |
|
|
2004
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income for fiscal year 2004
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,552 |
|
|
|
2,552 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2004
|
|
|
42,963,374 |
|
|
|
42,963 |
|
|
|
27,466 |
|
|
|
|
|
|
|
14,378 |
|
|
|
84,807 |
|
|
2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contribution of additional paid-in-capital
|
|
|
|
|
|
|
|
|
|
|
4,140 |
|
|
|
|
|
|
|
|
|
|
|
4,140 |
|
Net income for fiscal year 2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,613 |
|
|
|
6,613 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of December 31, 2005
|
|
|
42,963,374 |
|
|
|
42,963 |
|
|
|
31,606 |
|
|
|
|
|
|
|
20,991 |
|
|
|
95,560 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See the accompanying notes to the consolidated financial
statements
F-130
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
Amounts expressed in thousands of US Dollars
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Net Income
|
|
|
6,613 |
|
|
|
2,552 |
|
|
|
1,114 |
|
Adjustments to reconcile net income to net cash provided by
operating activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Deferred income tax
|
|
|
524 |
|
|
|
320 |
|
|
|
3,907 |
|
|
Depreciation, depletion and amortization
|
|
|
9,420 |
|
|
|
9,475 |
|
|
|
7,173 |
|
|
Loss on discontinued operations
|
|
|
4,138 |
|
|
|
1,309 |
|
|
|
|
|
Changes in assets and liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Increase) decrease in parts and supplies
|
|
|
(530 |
) |
|
|
91 |
|
|
|
(400 |
) |
|
Increase in accounts receivable trade
|
|
|
(6,856 |
) |
|
|
(2,041 |
) |
|
|
(6,697 |
) |
|
Decrease (increase) prepaid expenses and other current assets,
net of deferred income tax
|
|
|
290 |
|
|
|
719 |
|
|
|
(2,120 |
) |
|
Increase in trade accounts payable and accrued expenses, payroll
and accrued taxes and current other liabilities
|
|
|
4,629 |
|
|
|
6,347 |
|
|
|
4,783 |
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by operations
|
|
|
18,228 |
|
|
|
18,772 |
|
|
|
7,760 |
|
|
|
|
|
|
|
|
|
|
|
Investment activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Disposal (purchase) of investments
|
|
|
|
|
|
|
13 |
|
|
|
(10 |
) |
|
Proceeds from the sale of property, plant and equipment
|
|
|
64 |
|
|
|
160 |
|
|
|
|
|
|
Additions to property, plant and equipment
|
|
|
(22,195 |
) |
|
|
(12,184 |
) |
|
|
(12,640 |
) |
|
|
|
|
|
|
|
|
|
|
Net cash used in investment activities
|
|
|
(22,131 |
) |
|
|
(12,011 |
) |
|
|
(12,650 |
) |
|
|
|
|
|
|
|
|
|
|
Financing
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Contribution of additional paid-in capital
|
|
|
4,140 |
|
|
|
|
|
|
|
|
|
|
New long term debt
|
|
|
14,500 |
|
|
|
5,065 |
|
|
|
5,290 |
|
|
Net new short term debt
|
|
|
|
|
|
|
2,912 |
|
|
|
|
|
|
Financing from customers and other liabilities
|
|
|
(6,073 |
) |
|
|
14,166 |
|
|
|
|
|
|
Net decrease in short term debt and long-term debt
|
|
|
(8,446 |
) |
|
|
(12,894 |
) |
|
|
(733 |
) |
|
|
|
|
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
4,121 |
|
|
|
9,249 |
|
|
|
4,557 |
|
|
|
|
|
|
|
|
|
|
|
Cash flows from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in investments activities
|
|
|
(983 |
) |
|
|
(14,673 |
) |
|
|
|
|
|
Net cash used in financing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash used in discontinued operations
|
|
|
(983 |
) |
|
|
(14,673 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Decrease) increase in cash and cash equivalents
|
|
|
(765 |
) |
|
|
1,337 |
|
|
|
(333 |
) |
Cash and cash equivalents at the beginning of the year
|
|
|
1,496 |
|
|
|
159 |
|
|
|
492 |
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents at the end of the year
|
|
|
731 |
|
|
|
1,496 |
|
|
|
159 |
|
|
|
|
|
|
|
|
|
|
|
Income tax paid
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest paid
|
|
|
920 |
|
|
|
1,873 |
|
|
|
467 |
|
See the accompanying notes to the consolidated financial
statements
F-131
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS
Amounts expressed in thousands of US Dollars
Note 1. The Company
DLS Drilling, Logistics & Services Corporation
(DLS or, including its subsidiaries and branch, the
Company), incorporated under the laws of the British
Virgin Islands in September 1993, is involved in drilling and
oil field services.
In addition, the Company made certain investments in oil and
natural gas exploration activities (see Note 22).
DLSs shareholders are Bridas International Holdings Ltd.,
Bridas Central Company Ltd. and Associated Petroleum Investors
Limited, which hold 40%, 40% and 20%, respectively of DLSs
capital stock.
The Company has conducted and continues to conduct significant
transactions with related parties as explained in Note 17.
Note 2. Significant accounting
policies and presentation
The consolidated financial statements of DLS are prepared in
accordance with accounting principles generally accepted in the
United States of America (US GAAP). The financial
statements presented herein were prepared on a consistent basis
applying the significant accounting policies described in this
note. Certain reclassifications have been made to prior
presentations to be consistent with the current period
classification. Also, these financial statements reflect certain
reclassifications to present the oil and gas operations on a
discontinued operations basis as a consequence of the
transaction described in Note 22.
The management of the Company has made a number of estimates and
assumptions relating to the reporting of assets, liabilities,
revenues and expenses to prepare these financial statements in
conformity with US GAAP. Actual results may differ in some cases
from those estimates. These estimates include, but are not
limited to, the allowance for uncollectible accounts,
recoverability of the investment in long-term assets and the
fair value of the Companys investment in unproved oil and
gas properties.
|
|
|
2.2. Basis of
presentation |
The consolidated financial statements include the financial
statements of DLS Drilling, Logistics & Services Corporation
and its subsidiary and branch. All intercompany balances and
transactions have been eliminated in these consolidated
financial statements.
DLS had the following subsidiary and branch:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock | |
|
|
Company |
|
Main Activity | |
|
Ownership | |
|
Voting Rights | |
|
|
| |
|
| |
|
| |
DLS Argentina Ltd. (1)
|
|
|
Oil Field Services |
|
|
|
99.99 |
% |
|
|
99.99 |
% |
DLS Bolivia Branch
|
|
|
Oil Field Services |
|
|
|
100.00 |
% |
|
|
|
|
|
|
(1) |
DLS Argentina Ltd. has a branch in Argentina (DLS Argentina
Limited Sucursal Argentina). |
F-132
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 2. Significant accounting
policies and presentation (continued)
|
|
|
2.3. Cash and cash
equivalents |
Cash and cash equivalents include checking account deposits,
time deposits with original maturities of three months or less
and cash on hand. For the purposes of the consolidated
statements of cash flows the company considers all highly liquid
instruments with original maturities of three months or less to
be cash equivalents.
Inventories of materials, supplies, spare parts, drilling fluids
and others are stated at purchase cost. Goods in transit on
which ownership has passed to the Company are valued at purchase
cost. These values do not exceed those prevailing in the market.
|
|
|
2.5. Property, plant and
equipment |
Property, plant and equipment are carried at cost. Major
renewals and improvements are capitalized and depreciated over
the respective assets remaining useful life. Maintenance
and repair costs are charged to expense as incurred. When assets
are sold or retired, the remaining costs and related accumulated
depreciation are removed from the accounts and any resulting
gain or loss is included in results of operations. Interest is
capitalized on construction-in-progress, if any, at the interest
rate on debt incurred for construction or at the weighted
average cost of debt outstanding during the period of
construction.
Depreciation is provided using the working days method for
drilling rigs and the straight-line method based upon expected
useful lives of the rest of the items determined for each class
of asset. Estimated useful lives of the assets are as follows:
|
|
|
|
|
Drilling rigs
|
|
|
5840 working days |
|
Rig equipment
|
|
|
5 years |
|
Workover rigs
|
|
|
16 years |
|
Pulling rigs
|
|
|
10 years |
|
Trucks and transportation equipment
|
|
|
4 years |
|
Buildings
|
|
|
10 years |
|
Trailers and facilities
|
|
|
4 years |
|
Other
|
|
|
3 to 5 years |
|
Net property, plant and equipment does not exceed recoverable
values based on estimates of future operations. The Company
adopted Statement of Financial Accounting Standard Nr.144,
Accounting for the Impairment or Disposal of Long-Lived
Assets, issued by the Financial Accounting Standards Board
(FASB) in August 2001. This standard addresses the
accounting for the recognition and measurement of impairment
losses for long-lived assets (including oil and gas properties
accounted for under the
F-133
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 2. Significant accounting
policies and presentation (continued)
successful efforts method of accounting and certain amortizable
intangibles to be held and used or disposed of, see
Note 22).
The Company performs a review for impairment when circumstances
suggest there is a need for such a review. The Company groups
and evaluates other property, plant and equipment for impairment
based on the ability to identify separate cash flows generated
therefrom.
|
|
|
2.6. Foreign currency
remeasurement |
The Company has designated the U.S. dollar as the functional
currency for its operations because it contracts with customers,
purchases equipment and finances capital using the U.S. dollar.
Certain monetary assets and liabilities denominated in
currencies other than the U.S. dollar are remeasured at period
end historical exchange rates and all foreign currency monetary,
gains or losses are reflected in each years results of
operations and are included in Financial Expenses, net on the
Statement of Income. (See Note 16).
The Company recognizes revenue as services are performed based
upon contracted dayrates and the number of operating days during
the year. Revenue from turnkey contracts is based on percentage
of completion of the services at each balance sheet date.
Mobilization fees received and costs incurred in connection with
a customer contract to mobilize a rig from one geographic area
to another are deferred and recognized on a straight-line basis
over the term of such contract. Costs incurred to mobilize a rig
without a contract are expensed as incurred.
|
|
|
2.8. Compensated absences
and additional salaries |
The Company accrues the liability for future compensation to
employees for vacations and annual additional salaries (13th
month payment) vested during the year.
|
|
|
2.9. Concentration of
credit risk |
Financial instruments that potentially subject the Company to
concentrations of credit risk consist principally of cash and
cash equivalents and trade receivables. The Company places its
cash and cash equivalents in other high quality financial
instruments. The Company limits the amount of credit exposure to
any one financial institution. The Companys customer base
consists primarily of major integrated international oil
companies, as well as smaller independent oil and gas producers.
Management believes the credit quality of its customers is
generally high. The Company provides allowances for potential
credit losses when necessary.
|
|
|
2.10. Conditions affecting
ongoing operations |
The Companys current business and operations are
substantially dependent upon conditions in the oil and gas
industry and, specifically, the exploration and production
expenditures of oil and gas
F-134
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 2. Significant accounting
policies and presentation (continued)
companies. The demand for contract drilling and related services
is influenced by oil and gas prices, expectations about future
prices, the cost of producing and delivering oil and gas,
government regulations and local and international political and
economic conditions. There can be no assurance that current
levels of exploration and production expenditures of oil and gas
companies will be maintained or that demand for the
Companys services will reflect the level of such
activities.
The Company accounts for income taxes under the provisions of
Statement of Financial Accounting Standards Nr. 109 (SFAS
109), Accounting for Income Tax. Under the
asset and liability method of SFAS 109, deferred tax assets and
liabilities are recognized for the estimated future tax
consequences attributable to differences between the financial
statement carrying amounts of existing assets and liabilities
and their respective tax bases. Deferred tax assets and
liabilities are measured using enacted tax rates in effect for
the year in which those temporary differences are expected to be
recovered or settled. Under SFAS 109, the effect on deferred tax
assets and liabilities of a change in tax rates is recognized in
income for the period that includes the enactment date.
The consolidated entity domiciled in Argentina is subject to
Argentine income tax at a nominal rate of 35% except for the
activities carried out in the province of Tierra del Fuego,
which are exempt. The entity domiciled in Bolivia is subject to
Bolivian income tax at a nominal rate of 25%. Income earned by
DLS is not subject to taxation.
Note 3. Stockholders
equity
At December 31, 2005, 2004 and 2003, the authorized share
capital of DLS was USD 70,000, of which USD 42,963 had been
issued and was outstanding, represented by 42,963,374 shares.
Each share has a par value of one U.S. Dollar and is entitled to
one vote. The shares are identical in all respects. During 2005,
the Company received contribution of additional paid in capital
in the aggregate amount of USD 4,140. This contribution of
additional paid in capital was made by the shareholders in the
same proportion to their ownership interest. No additional
common shares were issued.
Note 4. Cash and cash
equivalents
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Cash on hand and in banks
|
|
|
331 |
|
|
|
1,496 |
|
Time deposits
|
|
|
400 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
731 |
|
|
|
1,496 |
|
|
|
|
|
|
|
|
F-135
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 5. Accounts receivable
|
|
|
|
|
|
|
|
|
|
|
December 31 |
|
|
|
|
|
2005 |
|
2004 |
|
|
|
|
|
Trade
|
|
|
26,826 |
|
|
|
19,970 |
|
|
|
|
|
|
|
|
|
|
|
|
|
26,826 |
|
|
|
19,970 |
|
|
|
|
|
|
|
|
|
|
No allowance for potential credit loss was deemed necessary as
of December 31, 2005 and 2004 based on an evaluation of
outstanding customer balances at each date.
Note 6. Parts and supplies
|
|
|
|
|
|
|
|
|
Drilling fluids
|
|
|
1,741 |
|
|
|
1,541 |
|
Materials, supplies, spare parts and others
|
|
|
13,916 |
|
|
|
13,165 |
|
Goods in transit
|
|
|
983 |
|
|
|
1,404 |
|
|
|
|
|
|
|
|
|
|
|
|
|
16,640 |
|
|
|
16,110 |
|
|
|
|
|
|
|
|
|
|
Note 7. Prepaid expenses and
other current assets
|
|
|
|
|
|
|
|
|
Prepaid taxes
|
|
|
2,073 |
|
|
|
1,857 |
|
Minimum presumed income tax
|
|
|
|
|
|
|
791 |
|
Deferred tax asset
|
|
|
309 |
|
|
|
663 |
|
Prepaid expenses
|
|
|
1,036 |
|
|
|
1,402 |
|
Deferred mobilization costs
|
|
|
651 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4,069 |
|
|
|
4,713 |
|
|
|
|
|
|
|
|
|
|
Note 8. Property, plant and
equipment
|
|
|
|
|
|
|
|
|
|
Drilling activities:
|
|
|
|
|
|
|
|
|
|
Drilling rigs
|
|
|
91,585 |
|
|
|
81,227 |
|
|
Rig equipment
|
|
|
17,372 |
|
|
|
15,594 |
|
|
Workover rigs
|
|
|
15,549 |
|
|
|
11,622 |
|
|
Rig held for future use(1)
|
|
|
10,752 |
|
|
|
10,752 |
|
|
Pulling rigs
|
|
|
7,324 |
|
|
|
6,459 |
|
|
Trucks and transportation equipment
|
|
|
3,559 |
|
|
|
3,456 |
|
|
Buildings
|
|
|
2,826 |
|
|
|
2,073 |
|
|
Trailers and facilities
|
|
|
1,359 |
|
|
|
1,258 |
|
|
Other
|
|
|
8,599 |
|
|
|
7,241 |
|
|
|
|
|
|
|
|
|
|
|
|
|
158,925 |
|
|
|
139,682 |
|
Accumulated depreciation
|
|
|
(48,415 |
) |
|
|
(41,883 |
) |
|
|
|
|
|
|
|
|
|
Net property, plant and equipment
|
|
|
110,510 |
|
|
|
97,799 |
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Carried at cost, which is lower than estimated fair market value. |
F-136
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 9. Trade accounts payable
and accrued expenses
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Trade creditors
|
|
|
11,724 |
|
|
|
10,999 |
|
Accrued expenses
|
|
|
1,798 |
|
|
|
1,210 |
|
|
|
|
|
|
|
|
|
|
|
13,522 |
|
|
|
12,209 |
|
|
|
|
|
|
|
|
Note 10. Short-term debt
|
|
|
|
|
|
|
|
|
Short term debt
|
|
|
|
|
|
|
1,006 |
|
Portion of long term debt maturing within one year
|
|
|
8,690 |
|
|
|
18,424 |
|
|
|
|
|
|
|
|
|
|
|
8,690 |
|
|
|
19,430 |
|
|
|
|
|
|
|
|
Short term debt for USD 1,006 at December 31, 2004 accrued
interest at an average 4.35% annual rate.
Note 11. Payroll and accrued
taxes
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Payroll
|
|
|
5,203 |
|
|
|
4,149 |
|
Taxes
|
|
|
2,773 |
|
|
|
2,799 |
|
|
|
|
|
|
|
|
|
|
|
7,976 |
|
|
|
6,948 |
|
|
|
|
|
|
|
|
Note 12. Other liabilities
|
|
|
|
|
|
|
|
|
Current
|
|
|
|
|
|
|
|
|
Customer financing of rig purchases
|
|
|
1,850 |
|
|
|
1,715 |
|
Note payable
|
|
|
7,177 |
|
|
|
|
|
Other
|
|
|
161 |
|
|
|
101 |
|
|
|
|
|
|
|
|
Total
|
|
|
9,188 |
|
|
|
1,816 |
|
|
|
|
|
|
|
|
Non-Current
|
|
|
|
|
|
|
|
|
Customer financing of rig purchases
|
|
|
782 |
|
|
|
2,591 |
|
Note payable
|
|
|
|
|
|
|
11,576 |
|
|
|
|
|
|
|
|
Total
|
|
|
782 |
|
|
|
14,167 |
|
|
|
|
|
|
|
|
These liabilities are denominated in U.S. dollars, except for
USD 161 and USD 101 which were denominated in
Argentine pesos as of December 31, 2005 and 2004,
respectively. The amounts of USD 2,632 and USD 4,306
accrued interest at a 8% p.a. rate in the years ended
December 31, 2005 and 2004, respectively. The amounts of
USD 7,177 and USD 11,576 accrued interest at a
6% p.a. rate in the years ended December 31, 2005 and
2004, respectively. The remaining other
liabilities current (USD 161 and USD 101 at
each year end) did not bear interest.
F-137
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 12. Other liabilities
(continued)
Other liabilities non current as of
December 31, 2005 become due in 2007.
Note 13. Long-term debt
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
3,49 % loan agreement due 2005(1)
|
|
|
|
|
|
|
2,028 |
|
4,51% loan agreement due 2005(1)
|
|
|
|
|
|
|
4,032 |
|
10,78% loan agreement due 2005(2)
|
|
|
|
|
|
|
1,128 |
|
10,78% loan agreement due 2006(2)
|
|
|
1,110 |
|
|
|
1,106 |
|
6,31% loan agreement due 2006(1)
|
|
|
2,142 |
|
|
|
1,676 |
|
6,31% loan agreement due 2008(1)
|
|
|
2,376 |
|
|
|
1,676 |
|
5,51% loan agreement due 2009(1)
|
|
|
1,500 |
|
|
|
800 |
|
6,156% loan agreement due 2010(1)
|
|
|
700 |
|
|
|
|
|
5,67% loan agreement due 2011(1)
|
|
|
350 |
|
|
|
|
|
10,78% loan agreement due 2007(2)
|
|
|
733 |
|
|
|
746 |
|
3,49% loan agreement due 2007(1)
|
|
|
2,376 |
|
|
|
1,676 |
|
6% loan agreement due 2005(1)
|
|
|
|
|
|
|
11,236 |
|
6% loan agreement due 2006(1)
|
|
|
5,438 |
|
|
|
5,166 |
|
6% loan agreement due 2007(1)
|
|
|
7,163 |
|
|
|
|
|
6% loan agreement due 2008(1)
|
|
|
7,514 |
|
|
|
|
|
6% loan agreement due 2009(1)
|
|
|
6,928 |
|
|
|
|
|
|
|
|
|
|
|
|
Subtotal
|
|
|
38,330 |
|
|
|
31,270 |
|
Less: Long-term debt maturing within one year
|
|
|
8,690 |
|
|
|
18,424 |
|
|
|
|
|
|
|
|
|
|
|
29,640 |
|
|
|
12,846 |
|
|
|
|
|
|
|
|
|
|
|
|
(1) |
Denominated in US dollars |
|
|
(2) |
Denominated in Argentine pesos |
F-138
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 13. Long-term debt
(continued)
Future maturities of long-term debt as of December 31, 2005
were as follows:
|
|
|
|
|
2006
|
|
|
8,690 |
|
2007
|
|
|
10,272 |
|
2008
|
|
|
9,890 |
|
2009
|
|
|
8,428 |
|
2010
|
|
|
700 |
|
Thereafter
|
|
|
350 |
|
|
|
|
|
Total long term debt
|
|
|
38,330 |
|
|
|
|
|
Note 14. Income tax
The components of the income tax expense from continuing
operations for each year were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Current
|
|
|
(3,023 |
) |
|
|
(2,710 |
) |
|
|
|
|
Deferred
|
|
|
(524 |
) |
|
|
(320 |
) |
|
|
(3,907 |
) |
|
|
|
|
|
|
|
|
|
|
Total
|
|
|
(3,547 |
) |
|
|
(3,030 |
) |
|
|
(3,907 |
) |
|
|
|
|
|
|
|
|
|
|
A reconciliation between the income tax expense and income tax
from continuing operations computed by applying the statutory
rate to income from continuing operations before income taxes is
summarized as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Percent of | |
|
|
|
Percent of | |
|
|
|
Percent of | |
|
|
|
|
Pre-tax | |
|
|
|
Pre-tax | |
|
|
|
Pre-tax | |
|
|
2005 | |
|
Income | |
|
2004 | |
|
Income | |
|
2003 | |
|
Income | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Income from continuing operations before income tax
|
|
|
14,298 |
|
|
|
|
|
|
|
6,891 |
|
|
|
|
|
|
|
5,021 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Theoretical income tax (*)
|
|
|
4,941 |
|
|
|
34.6% |
|
|
|
2,358 |
|
|
|
34.2% |
|
|
|
1,722 |
|
|
|
34.3% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Non taxable income(**)
|
|
|
(2,333 |
) |
|
|
16.3% |
|
|
|
(573 |
) |
|
|
8.3% |
|
|
|
|
|
|
|
|
|
Non taxable-exempt operation
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
424 |
|
|
|
8.4% |
|
Foreign exchange remeasurement
|
|
|
939 |
|
|
|
6.6% |
|
|
|
1,245 |
|
|
|
18.1% |
|
|
|
1,761 |
|
|
|
35.1% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income tax expense
|
|
|
3,547 |
|
|
|
24.8% |
|
|
|
3,030 |
|
|
|
44.0% |
|
|
|
3,907 |
|
|
|
77.8% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(*) |
The theoretical income tax rate applied represents the weighted
average of 35% of Argentine income tax and 25% of Bolivian
income tax. |
|
|
(**) |
Taxable income generated by the Companys operations in the
Province of Tierra de Fuego are exempt from Argentine income tax. |
F-139
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 14. Income tax
(continued)
The loss on discontinued operations is presented net of the
related tax effect (see Note 22).
The tax effects of temporary differences that give rise to
significant portions of the deferred tax assets and deferred tax
liabilities at each year end are as follows:
|
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Deferred tax asset:
|
|
|
|
|
|
|
|
|
|
Exchange losses deferred for tax purposes
|
|
|
309 |
|
|
|
663 |
|
|
|
|
|
|
|
|
Total deferred tax asset
|
|
|
309 |
|
|
|
663 |
|
|
|
|
|
|
|
|
Deferred tax liability:
|
|
|
|
|
|
|
|
|
|
Depreciation of property, plant and equipment
|
|
|
696 |
|
|
|
526 |
|
|
|
|
|
|
|
|
Total deferred tax liability
|
|
|
696 |
|
|
|
526 |
|
|
|
|
|
|
|
|
Note 15. Sales and other
operating revenues
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
By type of service provided
|
|
|
|
|
|
|
|
|
|
|
|
|
Drilling
|
|
|
71,617 |
|
|
|
68,805 |
|
|
|
54,779 |
|
Workover
|
|
|
25,848 |
|
|
|
19,592 |
|
|
|
19,059 |
|
Pulling
|
|
|
13,545 |
|
|
|
9,752 |
|
|
|
16,078 |
|
Mud Services
|
|
|
18,506 |
|
|
|
13,426 |
|
|
|
5,862 |
|
Other Revenues
|
|
|
333 |
|
|
|
697 |
|
|
|
306 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
129,849 |
|
|
|
112,272 |
|
|
|
96,084 |
|
|
|
|
|
|
|
|
|
|
|
By location
|
|
|
|
|
|
|
|
|
|
|
|
|
Argentina
|
|
|
126,716 |
|
|
|
102,339 |
|
|
|
89,443 |
|
Bolivia
|
|
|
3,133 |
|
|
|
9,933 |
|
|
|
6,641 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
129,849 |
|
|
|
112,272 |
|
|
|
96,084 |
|
|
|
|
|
|
|
|
|
|
|
F-140
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 15. Sales and other
operating revenues (continued)
Sales to significant customers were as follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Pan American Energy LLC (see Notes 17 and 18)
|
|
|
71,928 |
|
|
|
57,326 |
|
|
|
47,565 |
|
Repsol YPF S.A.
|
|
|
19,741 |
|
|
|
17,454 |
|
|
|
26,631 |
|
Sales to other customers
|
|
|
38,180 |
|
|
|
37,492 |
|
|
|
21,888 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
129,849 |
|
|
|
112,272 |
|
|
|
96,084 |
|
|
|
|
|
|
|
|
|
|
|
Note 16. Detail of expenses
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Operating costs and expenses
|
|
|
|
|
|
|
|
|
|
|
|
|
Payroll and related taxes
|
|
|
39,290 |
|
|
|
29,599 |
|
|
|
23,155 |
|
Fuel, lubricants & materials
|
|
|
29,708 |
|
|
|
29,256 |
|
|
|
25,234 |
|
Third party services
|
|
|
20,898 |
|
|
|
17,264 |
|
|
|
18,961 |
|
Depreciation
|
|
|
9,420 |
|
|
|
9,475 |
|
|
|
7,173 |
|
Repairs and maintenance
|
|
|
4,506 |
|
|
|
4,064 |
|
|
|
2,857 |
|
Fleet expenses
|
|
|
3,415 |
|
|
|
2,794 |
|
|
|
1,837 |
|
Insurance
|
|
|
1,102 |
|
|
|
1,280 |
|
|
|
1,081 |
|
Other expenses
|
|
|
5,012 |
|
|
|
4,634 |
|
|
|
3,429 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
113,351 |
|
|
|
98,366 |
|
|
|
83,727 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Net Financial expenses
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expenses
|
|
|
2,713 |
|
|
|
1,836 |
|
|
|
1,462 |
|
Interest income
|
|
|
(78 |
) |
|
|
(2 |
) |
|
|
(10 |
) |
Other financing charges
|
|
|
2,287 |
|
|
|
2,478 |
|
|
|
2,085 |
|
Foreign currency losses
|
|
|
472 |
|
|
|
273 |
|
|
|
493 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
5,394 |
|
|
|
4,585 |
|
|
|
4,030 |
|
|
|
|
|
|
|
|
|
|
|
Other Income (Expenses)
|
|
|
|
|
|
|
|
|
|
|
|
|
Commissions earned (Note 17)
|
|
|
7,217 |
|
|
|
2,104 |
|
|
|
0 |
|
Other
|
|
|
(90 |
) |
|
|
(1,104 |
) |
|
|
(166 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
7,127 |
|
|
|
1,000 |
|
|
|
(166 |
) |
|
|
|
|
|
|
|
|
|
|
F-141
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 16. Detail of expenses
(continued)
Between July 2004 and December 2005, the Company earned
commissions for the assistance provided by DLS management to a
related party (see Note 17) in securing significant
contracts with certain unrelated parties. The commissions were
calculated as a percentage of the actual revenue generated by
such contracts and accrued over the term of the contracts. This
is a non-recurring income.
Note 17. Certain agreement and
transactions with related parties
DLS and Pan American Energy LLC, or PAE, a company that is
approximately 40% owned by an affiliate of the current owners of
DLS, entered into a five-year strategic agreement for the
purpose of solidifying a long-term alliance for the drilling of
oil and gas wells in the San Jorge basin (see Note 18.1).
In 2005, 2004 and 2003 Company billed PAE a net aggregate of
approximately USD 71,298 USD 57,326 and
USD 47,565 respectively in respect of drilling and related
services provided by DLS; services rendered to PAE represented
approximately 55%, 51% and 50% of DLSs revenue in those
years. Also under the strategic agreement, DLS borrowed from PAE
the amount of USD 5,545 during 2004 to purchase rigs to be
used in drilling services to this customer. This loan bears
interest at a 8% p.a. rate.
In 2005, 2004 and 2003 the Company paid an aggregate amount of
approximately USD 6,741 USD 5,771 and USD 4,439
respectively, to Tanus Argentina S.A., a related party, for
the purchase of drilling fluids (see Note 18.3).
In 2005 the Company acquired drilling rigs from
Compañía de Perforaciones Río Colorado S.A.,
a related party, for USD 15,140.
The Company received certain financing loans from a related
party, Hudson Global Strategies Limited, in the normal course of
business. The outstanding balance as of December 31, 2005,
2004 and 2003 was USD 27,043 USD 16,402 and
USD 20,773 respectively. These loans bear interest at a 6%
p.a. rate.
In 2004 the Company purchased from Barrancas Sur S.A., a related
party, a 90% interest in exploratory blocks General Lamadrid and
Juarez for oil and gas exploration.
Executive and other services such as data processing, rent and
miscellaneous administrative and technical services were entered
into by the Company with related parties. In 2005, 2004 and 2003
the Company paid to such related parties an aggregate amount of
approximately USD 1,171 USD 1,186 and USD 1,714
respectively, in respect of said items.
In 2005 and 2004, the Company earned commissions from Interoil
Services Enterprise Limited, a related party, in the amount of
USD 7,217 and USD 2,104, respectively.
F-142
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 17. Certain agreement and
transactions with related parties (continued)
The following table summarizes the outstanding balances at each
year end, arising from the transactions described above.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year ended December 31 | |
|
|
| |
|
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Accounts receivable trade
|
|
|
5,076 |
|
|
|
9,681 |
|
|
|
8,283 |
|
Trade accounts payable and accrued expenses
|
|
|
1,073 |
|
|
|
2,095 |
|
|
|
888 |
|
Short term debt
|
|
|
5,437 |
|
|
|
11,237 |
|
|
|
5,207 |
|
Long term debt
|
|
|
21,605 |
|
|
|
5,166 |
|
|
|
15,566 |
|
Other liabilities current
|
|
|
9,027 |
|
|
|
1,715 |
|
|
|
|
|
Other liabilities non current
|
|
|
782 |
|
|
|
14,167 |
|
|
|
|
|
Note 18. Commitments and
contingencies
18.1. PAE
contract
DLS and PAE, a related party, entered into a five-year strategic
agreement for the purpose of solidifying a long-term alliance
for the drilling of oil and gas wells in the San Jorge basin.
The completion and repair of all wells in the area is also part
of the agreement. The strategic agreement expires in June 2008.
PAE represented approximately 55% of DLS revenue in 2005.
PAE may terminate the agreement without cause on
60 days notice or in the case of a spin-off or merger
of DLS that is not consented to by PAE. There is no provision
allowing early termination by DLS and there are no change of
control provisions. In accordance with the strategic agreement,
DLS shall ensure the availability of at least three drilling
rigs, eight workover rigs and five pulling rigs in order to meet
PAEs drilling plans but, in turn, PAE will provide DLS a
sufficient number of drilling locations to keep all such rigs
and associated equipment working during the term of the
strategic agreement, provided that there are no material changes
in the price of oil or adverse results of the production
forecasts. The drilling rigs rates under the agreement are
subject to an efficiency factor for drilling depths up to 2,700
meters. The agreement incorporates a standard drilling time in
hours for a typical drilling prospect up to 2,700 meters.
Drilling beyond 2,700 meters or drilling prospects with
non-standard procedures are at agreed upon hourly rates plus
reimbursable materials and expenses.
|
|
|
18.2. Drilling
fluid contract |
DLS entered into a drilling service contract with Repsol-YPF.
The term of the contract is three years and comprises 50% of all
drilling and fluid services required by the customer in the
Neuquen basin where Repsol-YPF is drilling with approximately 20
rigs. DLS derives 15% of its revenues from this contract.
F-143
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 18. Commitments and
contingencies (continued)
|
|
|
18.3. Source
of drilling fluids |
DLS purchases a wide variety of drilling fluids as well as
components made by other manufacturers and suppliers for use in
its operations. The products used by DLS are manufactured by
other parties. DLS is not dependent on any single source of
supply for any of its raw materials; however, DLS has a
long-term agreement with Tanus, a supplier of chemical
specialties used in mud service, from which DLS agreed to
purchase through 2009 the chemicals it uses to provide mud
services. DLS may terminate these agreement without cause on six
months notice.
The Company is routinely involved in other litigation, claims
and disputes incidental to its business, related to its labor
agreements, which at times involves claims, some of which would
not be covered by insurance. In the opinion of management, none
of the existing litigation will have a material adverse effect
on the Companys financial position, results of operations
or cash flows.
Note 19. Leases
The Company leases space used for the executive offices of the
branch in Argentina of DLS Argentina Limited. This lease is for
an initial three-year term expiring in 2007. It has been
classified as an operating lease. The approximate minimum annual
rental commitment estimated at December 31, 2005 is
USD 70 for each of the next three years. The total rental
expense associated with this lease for the years ended
December 31, 2005, 2004 and 2003 was USD 63
USD 72 and USD 59, respectively.
Note 20. Fair value of financial
instruments
The following table presents the carrying amounts and estimated
fair values of the Companys financial instruments at
December 31, 2005. The fair value of a financial instrument
is the amount at which the instrument could be exchanged in a
current transaction between willing parties.
|
|
|
|
|
|
|
|
|
|
|
Carrying | |
|
Fair | |
|
|
amount | |
|
value | |
|
|
| |
|
| |
Cash and cash equivalents
|
|
|
731 |
|
|
|
731 |
|
Accounts receivable
|
|
|
26,826 |
|
|
|
26,826 |
|
Accounts payable
|
|
|
13,522 |
|
|
|
13,522 |
|
Short-term debt
|
|
|
8,690 |
|
|
|
8,690 |
|
Long-term debt
|
|
|
29,640 |
|
|
|
29,640 |
|
Other liabilities
|
|
|
9,970 |
|
|
|
9,970 |
|
F-144
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 20. Fair value of financial
instruments (continued)
The following methods and assumptions were used to estimate the
fair value of each class of financial instruments:
|
|
|
|
|
Cash and cash equivalents, trade accounts receivable, other
assets, short term debt, trade accounts payable, accrued
expenses: The carrying amounts approximate fair value because of
the short maturity of these instruments. |
|
|
|
Long-term debt: The fair value of the Companys long-term
debt is estimated by discounting the future cash flows of each
instrument at rates currently offered to the Company for similar
debt instruments of comparable maturities by the Companys
bankers. |
Note 21. New accounting
pronouncements
SFAS No. 151, Inventory Costs, was issued by the Financial
Accounting Standards Board (FASB) in November 2004. This
statement amends Accounting Research Bulletin No. 43, to
clarify that abnormal amounts of idle facility expense, freight,
handling costs, and wasted materials should be recognized as
current-period charges, and it also requires that allocation of
fixed production overheads be based on the normal capacity of
the related production facilities. The provisions of this
statement will be effective for inventory costs incurred during
fiscal years beginning after June 15, 2005. The provisions
of this statement are applied prospectively. The Company expects
that the adoption of this statement will not have a material
impact on its financial position or results of operations in the
future.
FASB issued in December 2004 SFAS No. 153, Exchanges of
Non-monetary Assets, An Amendment of APB Opinion No. 29.
This statement addresses the measurement of exchanges of
non-monetary assets and eliminates the exception from fair value
measurement for non-monetary exchanges of similar productive
assets and replaces it with an exception for exchanges that do
not have commercial substance. SFAS No. 153 is effective
for non-monetary asset exchanges occurring in fiscal periods
beginning after June 15, 2005. The provisions of this
statement are applied prospectively. The Company expects that
the adoption of this statement will not have a material impact
on its financial position or results of operations in the future.
In May 2005, FASB issued the SFAS No. 154, Accounting
Changes and Error Corrections. This statement replaces APB
Opinion No. 20, Accounting Changes, and FASB Statement
No. 3, Reporting Accounting Change in Interim Financial
Statements, and changes the requirements for the accounting and
reporting of a change in an accounting principle. The adoption
of this statement did not have any effect on the Companys
consolidated financial statements.
On April 4, 2005, FASB adopted Staff Position FSP FAS 19-1
that amends SFAS No. 19 Financial Accounting and Reporting
by Oil and Gas Producing Companies, to permit the continued
capitalization of exploratory well costs beyond one year if
(a) the well found a sufficient quantity of reserves to
justify its completion as a producing well and (b) the
entity is making sufficient progress assessing the reserves and
the economic and operating viability of the project. The
guidance in the FSP is required to be applied prospectively as
from the third quarter of 2005. The adoption of this FSP did not
have any impact on the Companys 2005 results of operations.
F-145
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 21. New accounting
pronouncements (continued)
In September 2005, the Emerging Issue Task Force
(EITF) concluded in
Issue 04-13,
Accounting for Purchases and Sales of Inventory with the Same
Counterparty, that two or more exchange transactions involving
inventory with the same counterparty that are entered into in
contemplation of one another should be combined for purposes of
evaluating the effect of APB Opinion 29, Accounting for
Non-monetary Transactions. Additionally, the EITF reached a
consensus that a non-monetary exchange where an entity transfers
finished goods inventory in exchange for the receipt of raw
materials or work-in-progress inventory within the same line of
business should generally be recognized by the entity at fair
value. The consensus in this issue should be applied to
transactions completed in reporting periods beginning after
March 15, 2006, whether pursuant to arrangements that were
in place at the date of initial application of the consensus or
arrangements executed subsequent to that date. The Company
expects that the adoption of this EITF will not have a material
impact on its financial position or results of operations in the
future.
Note 22. Discontinued
operations
On June 30, 2004, the Company purchased a 90% interest in
exploratory blocks General Lamadrid and Juarez for oil and gas
exploration. The purchase price was USD 13,694. The Company
allocated USD 13,279 to unproved properties and
USD 415 to construction work in progress. Subsequent
exploration expenditures were capitalized in 2005 and 2004 in
the amount of USD 983 and USD 979 respectively, and
dry hole expense of USD 1,420 and USD 382 was
incurred, respectively. The Company recorded an impairment
charge of the unproved properties in the amount of
USD 4,946 and USD 1,632 in the years ended
December 31, 2005 and 2004, respectively. In March 2006,
the Company entered into an agreement to sell its interest in
the exploratory block to Barrancas Sur S.A. and received
proceeds equal to the book value of the oil and gas properties
as of the date of sale. The assets related to these
oil & gas activities are presented as Assets of
discontinued operations on the consolidated balance sheet,
while the related expenses are presented as Loss from
discontinued operations (net of income tax) on the
consolidated statements of income.
In connection with its oil & gas exploratory assets,
the Company follows the successful efforts method of accounting.
Costs of property acquisitions, successful exploratory wells and
support equipment and facilities are capitalized. Costs of
capitalized oil and gas properties would be amortized using the
units of production method. As of December 31, 2005, the
Company did not generate any sales of oil or gas and all
activities to date have been exploratory in nature. Unsuccessful
exploratory wells are expensed when determined to be
non-productive. Overhead and all exploration cost other than
exploratory drilling are charged against income as incurred.
|
|
|
|
|
|
|
|
|
|
|
December 31 | |
|
|
| |
Assets of discontinued operations |
|
2005 | |
|
2004 | |
|
|
| |
|
| |
Oil and gas unproved properties
|
|
|
6,701 |
|
|
|
11,647 |
|
Oil and gas construction work in progress
|
|
|
575 |
|
|
|
1,012 |
|
|
|
|
|
|
|
|
|
|
|
7,276 |
|
|
|
12,659 |
|
|
|
|
|
|
|
|
F-146
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE CONSOLIDATED FINANCIAL
STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 22. Discontinued operations
(continued)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31 | |
|
|
| |
Loss on discontinued operations |
|
2005 | |
|
2004 | |
|
2003 | |
|
|
| |
|
| |
|
| |
Dry hole expense
|
|
|
(1,420 |
) |
|
|
(382 |
) |
|
|
|
|
Impairment charges on unproved properties
|
|
|
(4,946 |
) |
|
|
(1,632 |
) |
|
|
|
|
Income tax benefits on discontinued operations
|
|
|
2,228 |
|
|
|
705 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,138 |
) |
|
|
(1,309 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
F-147
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
UNAUDITED INTERIM CONSOLIDATED BALANCE SHEETS
Amounts expressed in thousands of US Dollars
|
|
|
|
|
|
|
|
|
|
|
|
June 30, |
|
December 31, |
|
|
2006 |
|
2005 |
|
|
|
|
|
|
|
(Unaudited) |
|
|
ASSETS |
Current Assets
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents (Note 4)
|
|
|
492 |
|
|
|
731 |
|
|
Accounts receivable (Note 5)
|
|
|
29,244 |
|
|
|
26,826 |
|
|
Parts and supplies (Note 6)
|
|
|
16,608 |
|
|
|
16,640 |
|
|
Prepaid and other current assets (Note 7)
|
|
|
6,307 |
|
|
|
4,069 |
|
|
Assets of discontinued operations (Note 3)
|
|
|
|
|
|
|
7,276 |
|
|
|
|
|
|
|
|
|
|
Total Current Assets
|
|
|
52,651 |
|
|
|
55,542 |
|
|
|
|
|
|
|
|
|
|
Non-Current Assets
|
|
|
|
|
|
|
|
|
|
Property, plant and equipment, net (Note 8)
|
|
|
108,593 |
|
|
|
110,510 |
|
|
Investments
|
|
|
2 |
|
|
|
2 |
|
|
|
|
|
|
|
|
|
|
Total Non-Current Assets
|
|
|
108,595 |
|
|
|
110,512 |
|
|
|
|
|
|
|
|
|
|
TOTAL
|
|
|
161,246 |
|
|
|
166,054 |
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY |
|
Current Liabilities
|
|
|
|
|
|
|
|
|
|
Trade accounts payable and accrued expenses (Note 9)
|
|
|
17,270 |
|
|
|
13,522 |
|
|
Short-term debt (Note 10)
|
|
|
8,861 |
|
|
|
8,690 |
|
|
Payroll and accrued taxes (Note 11)
|
|
|
12,593 |
|
|
|
7,976 |
|
|
Other liabilities (Note 12)
|
|
|
2,105 |
|
|
|
9,188 |
|
|
|
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
40,829 |
|
|
|
39,376 |
|
|
|
|
|
|
|
|
|
|
Non-Current Liabilities
|
|
|
|
|
|
|
|
|
|
Other liabilities (Note 12)
|
|
|
|
|
|
|
782 |
|
|
Long-term debt (Note 13)
|
|
|
17,453 |
|
|
|
29,640 |
|
|
Deferred income tax liability
|
|
|
749 |
|
|
|
696 |
|
|
|
|
|
|
|
|
|
|
Total Non-Current Liabilities
|
|
|
18,202 |
|
|
|
31,118 |
|
|
|
|
|
|
|
|
|
|
TOTAL LIABILITIES
|
|
|
59,031 |
|
|
|
70,494 |
|
|
|
|
|
|
|
|
|
|
Stockholders Equity
|
|
|
|
|
|
|
|
|
|
Common stock (Note 22)
|
|
|
42,963 |
|
|
|
42,963 |
|
|
Additional paid-in capital (Note 22)
|
|
|
31,606 |
|
|
|
31,606 |
|
|
Retained earnings
|
|
|
27,646 |
|
|
|
20,991 |
|
|
|
|
|
|
|
|
|
|
TOTAL STOCKHOLDERS EQUITY
|
|
|
102,215 |
|
|
|
95,560 |
|
|
|
|
|
|
|
|
|
|
TOTAL
|
|
|
161,246 |
|
|
|
166,054 |
|
|
|
|
|
|
|
|
|
|
See the accompanying notes to the consolidated financial
statements
F-148
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
UNAUDITED INTERIM CONSOLIDATED STATEMENTS OF INCOME
Amounts expressed in thousands of US Dollars
|
|
|
|
|
|
|
|
|
|
|
Six Months | |
|
|
Ended June 30, | |
|
|
| |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Sales and Other Operating Revenues (Note 15)
|
|
|
82,019 |
|
|
|
61,085 |
|
Operating Costs and Expenses (Note 16)
|
|
|
(68,490 |
) |
|
|
(54,970 |
) |
|
|
|
|
|
|
|
Gross Profit
|
|
|
13,529 |
|
|
|
6,115 |
|
General and Administrative Expenses
|
|
|
(2,205 |
) |
|
|
(2,009 |
) |
|
|
|
|
|
|
|
Operating Income
|
|
|
11,324 |
|
|
|
4,106 |
|
Net Financial Expenses (Note 16)
|
|
|
(2,748 |
) |
|
|
(2,155 |
) |
Other (Expenses) Income (Note 16)
|
|
|
(784 |
) |
|
|
3,299 |
|
|
|
|
|
|
|
|
Income from Continuing Operations Before Income Tax
|
|
|
7,792 |
|
|
|
5,250 |
|
Income Tax (Note 14)
|
|
|
(3,512 |
) |
|
|
(2,074 |
) |
|
|
|
|
|
|
|
Income from Continuing Operations
|
|
|
4,280 |
|
|
|
3,176 |
|
Income from Discontinued Operations, net of Income Tax Benefit
of $2,375 (Note 3)
|
|
|
2,375 |
|
|
|
|
|
|
|
|
|
|
|
|
Net Income
|
|
|
6,655 |
|
|
|
3,176 |
|
|
|
|
|
|
|
|
See the accompanying notes to the consolidated financial
statements
F-149
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
UNAUDITED INTERIM CONSOLIDATED STATEMENT OF
STOCKHOLDERS EQUITY
Amounts expressed in thousands of US Dollars
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accumulated | |
|
|
|
|
|
|
Common Stock | |
|
|
|
Other | |
|
|
|
|
|
|
| |
|
Paid-in | |
|
Comprehensive | |
|
Retained | |
|
|
Description |
|
Shares | |
|
Amount | |
|
Capital | |
|
Income | |
|
Earnings | |
|
Total | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Opening balance
|
|
|
42,963,374 |
|
|
|
42,963 |
|
|
|
27,466 |
|
|
|
|
|
|
|
14,378 |
|
|
|
84,807 |
|
Net income for the six months ended June 30, 2005
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,176 |
|
|
|
3,176 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2005
|
|
|
42,963,374 |
|
|
|
42,963 |
|
|
|
27,466 |
|
|
|
|
|
|
|
17,554 |
|
|
|
87,983 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2006
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Opening balance
|
|
|
42,963,374 |
|
|
|
42,963 |
|
|
|
31,606 |
|
|
|
|
|
|
|
20,991 |
|
|
|
95,560 |
|
Net income for the six months ended June 30, 2006
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,655 |
|
|
|
6,655 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Balance as of June 30, 2006
|
|
|
42,963,374 |
|
|
|
42,963 |
|
|
|
31,606 |
|
|
|
|
|
|
|
27,646 |
|
|
|
102,215 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See the accompanying notes to the consolidated financial
statements
F-150
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
UNAUDITED INTERIM CONSOLIDATED STATEMENT OF CASH FLOWS
Amounts expressed in thousands of US Dollars
|
|
|
|
|
|
|
|
|
|
|
|
Six Months Ended | |
|
|
June 30, | |
|
|
| |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Net Income
|
|
|
6,655 |
|
|
|
3,176 |
|
Adjustments to reconcile net income to net cash provided by
operating activities
|
|
|
|
|
|
|
|
|
|
Deferred income tax
|
|
|
210 |
|
|
|
275 |
|
|
Income from discontinued operations
|
|
|
(2,375 |
) |
|
|
|
|
|
Depreciation, depletion and amortization
|
|
|
5,490 |
|
|
|
4,486 |
|
|
Net gain on the sale of property, plant and equipment
|
|
|
(34 |
) |
|
|
24 |
|
Changes in assets and liabilities
|
|
|
|
|
|
|
|
|
|
Decrease in parts and supplies
|
|
|
32 |
|
|
|
545 |
|
|
Decrease (increase) in accounts receivable trade
|
|
|
(2,418 |
) |
|
|
(1,695 |
) |
|
Increase in prepaid expenses and other current assets, net of
deferred income tax
|
|
|
(22 |
) |
|
|
(1,935 |
) |
|
Increase in trade accounts payable and accrued expenses, payroll
and accrued taxes and current other liabilities
|
|
|
502 |
|
|
|
4,175 |
|
|
|
|
|
|
|
|
Net cash provided by operations
|
|
|
8,040 |
|
|
|
9,051 |
|
|
|
|
|
|
|
|
Investment activities
|
|
|
|
|
|
|
|
|
|
Purchase of investments
|
|
|
|
|
|
|
(10 |
) |
|
Proceeds from the sale of property, plant and equipment
|
|
|
798 |
|
|
|
27 |
|
|
Additions to property, plant and equipment
|
|
|
(4,337 |
) |
|
|
(4,057 |
) |
|
|
|
|
|
|
|
Net cash used in investment activities
|
|
|
(3,539 |
) |
|
|
(4,040 |
) |
|
|
|
|
|
|
|
Financing
|
|
|
|
|
|
|
|
|
|
Net decrease in Short-term debt and Long-term debt
|
|
|
(12,016 |
) |
|
|
(5,447 |
) |
|
|
|
|
|
|
|
Net cash used in financing activities
|
|
|
(12,016 |
) |
|
|
(5,447 |
) |
|
|
|
|
|
|
|
Cash flow from discontinued operations
|
|
|
|
|
|
|
|
|
|
Net cash provided by operations
|
|
|
|
|
|
|
|
|
|
Net cash provided by investment activities
|
|
|
7,276 |
|
|
|
|
|
|
Net cash provided by financing activities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net cash provided by discontinued operations
|
|
|
7,276 |
|
|
|
|
|
|
|
|
|
|
|
|
Decrease in cash and cash equivalents
|
|
|
(239 |
) |
|
|
(436 |
) |
Cash and cash equivalents at the beginning of the period
|
|
|
731 |
|
|
|
1,496 |
|
|
|
|
|
|
|
|
Cash and cash equivalents at the end of the period
|
|
|
492 |
|
|
|
1,060 |
|
|
|
|
|
|
|
|
Income tax paid
|
|
|
|
|
|
|
|
|
Interest paid
|
|
|
2,648 |
|
|
|
1,155 |
|
See the accompanying notes to the consolidated financial
statements
F-151
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS
Amounts expressed in thousands of US Dollars
DLS Drilling, Logistics & Services Corporation
(DLS or, including its subsidiaries and branch, the
Company), incorporated under the laws of the British
Virgin Islands in September 1993, is involved in drilling and
oil field services.
In addition, the Company made certain investments in oil and
natural gas exploration activities (now discontinued, see
Note 3).
DLSs shareholders are Bridas International Holdings Ltd.,
Bridas Central Company Ltd. and Associated Petroleum Investors
Limited, which hold 40%, 40% and 20%, respectively of DLSs
capital stock. (See Note 23)
The Company has conducted and continues to conduct significant
transactions with related parties as explained in Note 17.
|
|
Note 2. |
Significant accounting policies and presentation |
The unaudited interim consolidated financial statements of DLS
are prepared in accordance with accounting principles generally
accepted in the United States of America (US GAAP).
The financial statements presented herein were prepared on a
consistent basis applying the significant accounting policies
described in this note. The balance sheet as of
December 31, 2005 presented for comparative purposes and
related notes reflect certain reclassifications to present the
oil and gas operations on a discontinued operations basis as a
consequence of the transaction described in Note 3.
In the opinion of management, the unaudited interim consolidated
financial statements included herein reflects all adjustments,
consisting only of normal recurring adjustments, which are
necessary for a fair presentation of the Companys
financial position, results of operations and cash flow for the
interim periods presented. The results of operations for the
interim periods presented herein are not necessarily indicative
of the results to be expected for a full year or any other
interim period.
The management of the Company has made a number of estimates and
assumptions relating to the reporting of assets, liabilities,
revenues and expenses to prepare these financial statements in
conformity with US GAAP. Actual results may differ in some cases
from those estimates. These estimates include, but are not
limited to, the allowance for uncollectible accounts,
recoverability of the investment in long-term assets and the
fair value of the Companys investment in unproved oil and
gas properties.
|
|
|
2.2. Basis of
presentation |
The consolidated financial statements include the financial
statements of DLS Drilling, Logistics & Services
Corporation and its subsidiary and branch. All intercompany
balances and transactions have been eliminated in these
consolidated financial statements.
F-152
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 2. Significant
accounting policies and presentation (continued)
DLS had the following subsidiary and branch:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock |
|
|
Company |
|
Main Activity |
|
Ownership |
|
Voting Rights |
|
|
|
|
|
|
|
DLS Argentina Ltd. (1)
|
|
|
Oil Field Services |
|
|
|
99.99 |
% |
|
|
99.99 |
% |
DLS Bolivia Branch
|
|
|
Oil Field Services |
|
|
|
100.00 |
% |
|
|
|
|
|
|
(1) |
DLS Argentina Ltd. has a branch in Argentina (DLS Argentina
Limited Sucursal Argentina) |
|
|
|
2.3. Cash and cash
equivalents |
Cash and cash equivalents include checking account deposits,
time deposits with original maturities of three months or less
and cash on hand. For the purposes of the unaudited interim
consolidated statements of cash flows the company considers all
highly liquid instruments with original maturities of three
months or less to be cash equivalents.
Inventories of materials, supplies, spare parts, drilling fluids
and others are stated at purchase cost. Goods in transit on
which ownership has passed to the Company are valued at purchase
cost. These values do not exceed those prevailing in the market.
|
|
|
2.5. Property, plant
and equipment |
Property, plant and equipment are carried at cost. Major
renewals and improvements are capitalized and depreciated over
the respective assets remaining useful life. Maintenance
and repair costs are charged to expense as incurred. When assets
are sold or retired, the remaining costs and related accumulated
depreciation are removed from the accounts and any resulting
gain or loss is included in results of operations. Interest is
capitalized on
construction-in-progress,
if any, at the interest rate on debt incurred for construction
or at the weighted average cost of debt outstanding during the
period of construction.
F-153
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 2. Significant
accounting policies and presentation (continued)
Depreciation is provided using the working days method for
drilling rigs and the
straight-line method
based upon expected useful lives of the rest of the items
determined for each class of asset. Estimated useful lives of
the assets are as follows:
|
|
|
|
|
Drilling rigs
|
|
|
5840 working days |
|
Rig equipment
|
|
|
5 years |
|
Workover rigs
|
|
|
16 years |
|
Pulling rigs
|
|
|
10 years |
|
Trucks and transportation equipment
|
|
|
4 years |
|
Buildings
|
|
|
10 years |
|
Trailers and facilities
|
|
|
4 years |
|
Other
|
|
|
3 to 5 years |
|
Net property, plant and equipment does not exceed recoverable
values based on estimates of future operations. The Company
adopted Statement of Financial Accounting Standard Nr.144,
Accounting for the Impairment or Disposal of Long-Lived
Assets, issued by the Financial Accounting Standards Board
(FASB) in August 2001. This standard addresses the
accounting for the recognition and measurement of impairment
losses for long-lived assets (including oil and gas properties
accounted for under the successful efforts method of accounting
and certain amortizable intangibles to be held and used or
disposed of See Note 3.)
The Company performs a review for impairment when circumstances
suggest there is a need for such a review. The Company groups
and evaluates other property, plant and equipment for impairment
based on the ability to identify separate cash flows generated
therefrom.
|
|
|
2.6. Foreign currency
remeasurement |
The Company has designated the U.S. dollar as the
functional currency for its operations because it contracts with
customers, purchases equipment and finances capital using the
U.S. dollar. Certain monetary assets and liabilities
denominated in currencies other than the U.S. dollar are
remeasured at period end historical exchange rates and all
foreign currency monetary, gains or losses are reflected in each
periods results of operations and are included under
financial expenses, net on the Unaudited Interim Consolidated
Statement of Income (See Note 16).
The Company recognizes revenue as services are performed based
upon contracted dayrates and the number of operating days during
the year. Revenue from turnkey contracts is based on percentage
of completion of the services at each balance sheet date.
Mobilization fees received and costs incurred in connection with
a customer contract to mobilize a rig from one geographic area
to another are deferred
F-154
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 2. Significant
accounting policies and presentation (continued)
and recognized on a straight-line basis over the term of such
contract. Costs incurred to mobilize a rig without a contract
are expensed as incurred.
|
|
|
2.8. Compensated
absences and additional salaries |
The Company accrues the liability for future compensation to
employees for vacations and annual additional salaries
(13th month payment) vested during the year.
|
|
|
2.9. Concentration of
credit risk |
Financial instruments that potentially subject the Company to
concentrations of credit risk consist principally of cash and
cash equivalents and trade receivables. The Company places its
cash and cash equivalents in other high quality financial
instruments. The Company limits the amount of credit exposure to
any one financial institution. The Companys customer base
consists primarily of major integrated international oil
companies, as well as smaller independent oil and gas producers.
Management believes the credit quality of its customers is
generally high. The Company provides allowances for potential
credit losses when necessary.
|
|
|
2.10. Conditions affecting
ongoing operations |
The Companys current business and operations are
substantially dependent upon conditions in the oil and gas
industry and, specifically, the exploration and production
expenditures of oil and gas companies. The demand for contract
drilling and related services is influenced by oil and gas
prices, expectations about future prices, the cost of producing
and delivering oil and gas, government regulations and local and
international political and economic conditions. There can be no
assurance that current levels of exploration and production
expenditures of oil and gas companies will be maintained or that
demand for the Companys services will reflect the level of
such activities.
The Company accounts for income taxes under the provisions of
Statement of Financial Accounting Standards Nr. 109
(SFAS 109), Accounting for Income
Tax. Under the asset and liability method of
SFAS 109, deferred tax assets and liabilities are
recognized for the estimated future tax consequences
attributable to differences between the financial statement
carrying amounts of existing assets and liabilities and their
respective tax bases. Deferred tax assets and liabilities are
measured using enacted tax rates in effect for the year in which
those temporary differences are expected to be recovered or
settled.
The consolidated entity domiciled in Argentina is subject to
Argentine income tax at a nominal rate of 35% except for the
activities carried out in the province of Tierra del Fuego,
which are exempt. The entity domiciled in Bolivia is subject to
Bolivian income tax at a nominal rate of 25%. Income earned by
DLS is not subject to taxation.
F-155
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
|
|
Note 3. |
Discontinued operations |
From mid-2004 through March 2006, the Company participated in
certain oil and gas exploration activities. On June 30,
2004, the Company purchased a 90% interest in exploratory blocks
General Lamadrid and Juarez for oil and gas exploration. The
purchase price was USD 13,694. The Company allocated
USD 13,279 to unproved properties and USD 415 to
construction work in progress. Subsequent exploration
expenditures were capitalized in 2005 and 2004 in the amount of
USD 983 and USD 979 respectively, net of dry hole
expense of USD 1,420 and USD 382, respectively. The
Company recorded an impairment charge of the unproved properties
in the amount of USD 4,946 and USD 1,632 in the years
ended December 31, 2005 and 2004, respectively.
The Company followed the successful efforts method of
accounting. Costs of property acquisitions, successful
exploratory wells and support equipment and facilities were
capitalized. Costs of capitalized oil and gas properties would
be amortized using the units of production method. The Company
did not generate any sales of oil or gas and all activities were
exploratory in nature. Unsuccessful exploratory wells were
expensed when determined to be non-productive. Overhead and all
exploration cost other than exploratory drilling were charged
against income as incurred. The Company disposed of its interest
in oil and gas exploration activities in March 2006 and received
proceeds equal to the book value of the oil and gas properties
as of the date of sale (see Note 17).
Income from discontinued operations
|
|
|
|
|
|
|
|
|
|
|
Six Months | |
|
|
ended June 30 | |
|
|
| |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Pretax income from discontinued operations
|
|
|
|
|
|
|
|
|
Gain/ Loss on sale of discontinued operations |
|
|
|
|
|
|
|
|
Income tax benefit
|
|
|
2,375 |
|
|
|
|
|
|
|
|
|
|
|
|
Income from discontinued operations
|
|
|
2,375 |
|
|
|
|
|
|
|
|
|
|
|
|
Assets of discontinued operations
|
|
|
|
|
|
|
|
|
|
|
June 30 | |
|
December 31 | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Oil and gas unproved properties
|
|
|
|
|
|
|
6,701 |
|
Oil and gas construction work in progress
|
|
|
|
|
|
|
575 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,276 |
|
|
|
|
|
|
|
|
F-156
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
|
|
Note 4. |
Cash and cash equivalents |
|
|
|
|
|
|
|
|
|
|
|
June 30 | |
|
December 31 | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Cash on hand and in banks
|
|
|
492 |
|
|
|
331 |
|
Time deposits
|
|
|
|
|
|
|
400 |
|
|
|
|
|
|
|
|
|
|
|
492 |
|
|
|
731 |
|
|
|
|
|
|
|
|
|
|
Note 5. |
Accounts receivable |
|
|
|
|
|
|
|
|
|
Trade
|
|
|
29,244 |
|
|
|
26,826 |
|
|
|
|
|
|
|
|
|
|
|
29,244 |
|
|
|
26,826 |
|
|
|
|
|
|
|
|
No allowance for potential credit losses was deemed necessary as
of June 30, 2006 and December 31, 2005 based on an
evaluation of outstanding customer balances at each date.
|
|
Note 6. |
Parts and supplies |
|
|
|
|
|
|
|
|
|
Drilling fluids
|
|
|
1,763 |
|
|
|
1,741 |
|
Materials, supplies, spare parts and others
|
|
|
13,206 |
|
|
|
13,916 |
|
Goods in transit
|
|
|
1,639 |
|
|
|
983 |
|
|
|
|
|
|
|
|
|
|
|
16,608 |
|
|
|
16,640 |
|
|
|
|
|
|
|
|
|
|
Note 7. |
Prepaid expenses and other current assets |
|
|
|
|
|
|
|
|
|
Prepaid taxes
|
|
|
1,537 |
|
|
|
2,073 |
|
Deferred tax asset
|
|
|
2,525 |
|
|
|
309 |
|
Prepaid expenses
|
|
|
2,245 |
|
|
|
1,036 |
|
Deferred mobilization costs
|
|
|
|
|
|
|
651 |
|
|
|
|
|
|
|
|
|
|
|
6,307 |
|
|
|
4,069 |
|
|
|
|
|
|
|
|
F-157
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
|
|
Note 8. |
Property, plant and equipment |
|
|
|
|
|
|
|
|
|
|
|
|
June 30, | |
|
December 31, | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Drilling activities:
|
|
|
|
|
|
|
|
|
|
Drilling rigs
|
|
|
93,515 |
|
|
|
91,585 |
|
|
Rig equipment
|
|
|
18,593 |
|
|
|
17,372 |
|
|
Workover rigs
|
|
|
16,056 |
|
|
|
15,549 |
|
|
Rig held for future use(1)
|
|
|
10,752 |
|
|
|
10,752 |
|
|
Pulling rigs
|
|
|
7,309 |
|
|
|
7,324 |
|
|
Trucks and transportation equipment
|
|
|
3,954 |
|
|
|
3,559 |
|
|
Buildings
|
|
|
2,073 |
|
|
|
2,826 |
|
|
Trailers and facilities
|
|
|
1,456 |
|
|
|
1,359 |
|
|
Other
|
|
|
8,674 |
|
|
|
8,599 |
|
|
|
|
|
|
|
|
|
|
|
162,382 |
|
|
|
158,925 |
|
Accumulated depreciation
|
|
|
(53,789 |
) |
|
|
(48,415 |
) |
|
|
|
|
|
|
|
Net property, plant and equipment
|
|
|
108,593 |
|
|
|
110,510 |
|
|
|
|
|
|
|
|
|
|
(1) |
Carried at cost, which is lower than estimated fair market value. |
|
|
Note 9. |
Trade accounts payable and accrued expenses |
|
|
|
|
|
|
|
|
|
Trade creditors
|
|
|
14,819 |
|
|
|
11,724 |
|
Accrued expenses
|
|
|
2,451 |
|
|
|
1,798 |
|
|
|
|
|
|
|
|
|
|
|
17,270 |
|
|
|
13,522 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Portion of long term debt maturing within one year
|
|
|
8,861 |
|
|
|
8,690 |
|
|
|
|
|
|
|
|
|
|
|
8,861 |
|
|
|
8,690 |
|
|
|
|
|
|
|
|
|
|
Note 11. |
Payroll and accrued taxes |
|
|
|
|
|
|
|
|
|
Payroll
|
|
|
6,904 |
|
|
|
5,203 |
|
Taxes
|
|
|
5,689 |
|
|
|
2,773 |
|
|
|
|
|
|
|
|
|
|
|
12,593 |
|
|
|
7,976 |
|
|
|
|
|
|
|
|
F-158
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
|
|
Note 12. |
Other liabilities |
|
|
|
|
|
|
|
|
|
|
|
June 30, | |
|
December 31, | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Current
|
|
|
|
|
|
|
|
|
Customer financing of rig purchases
|
|
|
1,442 |
|
|
|
1,850 |
|
Note payable
|
|
|
|
|
|
|
7,177 |
|
Other
|
|
|
663 |
|
|
|
161 |
|
|
|
|
|
|
|
|
Total
|
|
|
2,105 |
|
|
|
9,188 |
|
|
|
|
|
|
|
|
Non-Current
|
|
|
|
|
|
|
|
|
Customer financing of rig purchases
|
|
|
|
|
|
|
782 |
|
|
|
|
|
|
|
|
Total
|
|
|
|
|
|
|
782 |
|
|
|
|
|
|
|
|
These liabilities are denominated in US dollars, except for
USD 663 and USD 161 which were denominated in
Argentine pesos as of June 30, 2006 and December 31,
2005, respectively. The amounts of USD 1,442 and
USD 2,632 accrued interest at a 8% p.a. rate in the
period ended on June 30, 2006 and the year ended
December 31, 2005, respectively. The amount of
USD 7,177 accrued interest at a 6% p.a. rate and was
retired of the Company subsequent to December 31, 2005. The
remaining other liabilities current (USD 663
and USD 161 as of June 30, 2006 and December 31,
2005, respectively) did not bear interest.
F-159
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
|
|
|
|
|
|
|
|
|
|
|
June 30, | |
|
December 31, | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
10.78% loan agreement due 2006(2)
|
|
|
|
|
|
|
1,110 |
|
6.31% loan agreement due 2006(1)
|
|
|
1,313 |
|
|
|
2,142 |
|
6.31% loan agreement due 2007(1)
|
|
|
2,376 |
|
|
|
|
|
6.31% loan agreement due 2008(1)
|
|
|
2,376 |
|
|
|
2,376 |
|
5.51% loan agreement due 2009(1)
|
|
|
1,500 |
|
|
|
1,500 |
|
6.56% loan agreement due 2010(1)
|
|
|
700 |
|
|
|
700 |
|
6.56% loan agreement due 2011(1)
|
|
|
350 |
|
|
|
350 |
|
10.78% loan a agreement due 2007(2)
|
|
|
|
|
|
|
733 |
|
3.49% loan agreement due 2007(1)
|
|
|
|
|
|
|
2,376 |
|
6% loan agreement due 2006(1)
|
|
|
2,787 |
|
|
|
5,438 |
|
6% loan agreement due 2007(1)
|
|
|
4,524 |
|
|
|
7,163 |
|
6% loan agreement due 2008(1)
|
|
|
3,253 |
|
|
|
7,514 |
|
6% loan agreement due 2009(1)
|
|
|
7,135 |
|
|
|
6,928 |
|
|
|
|
|
|
|
|
Subtotal
|
|
|
26,314 |
|
|
|
38,330 |
|
Less: Long-term debt maturing within one year
|
|
|
8,861 |
|
|
|
8,690 |
|
|
|
|
|
|
|
|
|
|
|
17,453 |
|
|
|
29,640 |
|
|
|
|
|
|
|
|
|
|
(1) |
Denominated in US dollars |
|
(2) |
Denominated in Argentine pesos |
Future maturities of long-term debt as of June 30, 2006
were as follows:
|
|
|
|
|
2006 and 2nd quarter 2007
|
|
|
8,861 |
|
2007
|
|
|
2,139 |
|
2008
|
|
|
5,629 |
|
2009
|
|
|
8,635 |
|
2010
|
|
|
700 |
|
Thereafter
|
|
|
350 |
|
|
|
|
|
Total long term debt
|
|
|
26,314 |
|
|
|
|
|
F-160
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
The components of the income tax expense from continuing
operations were as follows:
|
|
|
|
|
|
|
|
|
|
|
Six months ended June 30 | |
|
|
| |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Current
|
|
|
(3,302 |
) |
|
|
(1,799 |
) |
Deferred
|
|
|
(210 |
) |
|
|
(275 |
) |
|
|
|
|
|
|
|
Total
|
|
|
(3,512 |
) |
|
|
(2,074 |
) |
|
|
|
|
|
|
|
The Companys consolidated effective income tax rate for
continuing operations for the six months ended June 30,
2006 was 45.1% as compared to 39.5% for the corresponding period
in 2005. The lower rate in 2005 was principally the result of
higher income in zero tax jurisdictions.
The results from discontinued operations are presented net of
the related tax effect (See Note 3).
A reconciliation between the income tax expense and income tax
computed by applying the statutory rate to income from
continuing operations before income taxes is summarized as
follows:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Percent of | |
|
|
|
Percent of | |
|
|
|
|
Pre-tax | |
|
|
|
Pre-tax | |
|
|
2006 | |
|
income | |
|
2005 | |
|
income | |
|
|
| |
|
| |
|
| |
|
| |
Income from continuing operations before income tax
|
|
|
7,792 |
|
|
|
100 |
% |
|
|
5,250 |
|
|
|
100 |
% |
Theoretical income tax(*)
|
|
|
2,644 |
|
|
|
33.9 |
% |
|
|
1,799 |
|
|
|
34.3 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Non taxable result exempt operation-
|
|
|
618 |
|
|
|
7.9 |
% |
|
|
(819 |
) |
|
|
-15.6 |
% |
Non taxable income(**)
|
|
|
(37 |
) |
|
|
-0.5 |
% |
|
|
(30 |
) |
|
|
-0.6 |
% |
Foreign exchange remeasurement
|
|
|
287 |
|
|
|
3.7 |
% |
|
|
1,124 |
|
|
|
21.4 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Income tax expense from continuing operations
|
|
|
3,512 |
|
|
|
45.1 |
% |
|
|
2,074 |
|
|
|
39.5 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(*) |
The theoretical income tax rate applied represents the weighted
average of 35% of Argentine income tax and 25% of Bolivian
income tax for continuing operations. |
|
(**) |
Taxable income generated by the Companys operations in the
province of Tierra del Fuego are exempt from Argentine income
tax for continuing operations. |
F-161
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
|
|
Note 15. |
Sales and other operating revenues |
|
|
|
|
|
|
|
|
|
|
|
Period ended June 30 | |
|
|
| |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
By type of service provided
|
|
|
|
|
|
|
|
|
Drilling
|
|
|
48,270 |
|
|
|
36,040 |
|
Workover
|
|
|
16,468 |
|
|
|
11,870 |
|
Pulling
|
|
|
7,565 |
|
|
|
6,331 |
|
Mud Services
|
|
|
9,629 |
|
|
|
6,759 |
|
Other Revenues
|
|
|
87 |
|
|
|
85 |
|
|
|
|
|
|
|
|
|
|
|
82,019 |
|
|
|
61,085 |
|
|
|
|
|
|
|
|
By location
|
|
|
|
|
|
|
|
|
Argentina
|
|
|
79,467 |
|
|
|
58,635 |
|
Bolivia
|
|
|
2,552 |
|
|
|
2,450 |
|
|
|
|
|
|
|
|
|
|
|
82,019 |
|
|
|
61,085 |
|
|
|
|
|
|
|
|
Sales to significant customers were as follows: |
Pan American Energy LLC (see Notes 17 and 18)
|
|
|
50,996 |
|
|
|
34,349 |
|
Repsol YPF S.A.
|
|
|
11,874 |
|
|
|
9,027 |
|
Sales to other customers
|
|
|
19,149 |
|
|
|
17,709 |
|
|
|
|
|
|
|
|
|
|
|
82,019 |
|
|
|
61,085 |
|
|
|
|
|
|
|
|
F-162
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
|
|
Note 16. |
Detail of expenses |
|
|
|
|
|
|
|
|
|
|
|
Period ended June 30 | |
|
|
| |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Operating costs and expenses
|
|
|
|
|
|
|
|
|
Payroll and related taxes
|
|
|
23,872 |
|
|
|
18,280 |
|
Fuel, lubricants & materials
|
|
|
17,800 |
|
|
|
15,607 |
|
Third party services
|
|
|
14,292 |
|
|
|
10,420 |
|
Depreciation
|
|
|
5,490 |
|
|
|
4,486 |
|
Repairs and maintenance
|
|
|
1,718 |
|
|
|
1,985 |
|
Fleet expenses
|
|
|
1,410 |
|
|
|
1,419 |
|
Insurance
|
|
|
749 |
|
|
|
697 |
|
Other expenses
|
|
|
3,159 |
|
|
|
2,076 |
|
|
|
|
|
|
|
|
|
|
|
68,490 |
|
|
|
54,970 |
|
|
|
|
|
|
|
|
Net Financial Expenses
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
1,181 |
|
|
|
1,252 |
|
Interest income
|
|
|
(6 |
) |
|
|
(1 |
) |
Other financing charges
|
|
|
1,198 |
|
|
|
903 |
|
Foreign currency losses
|
|
|
375 |
|
|
|
1 |
|
|
|
|
|
|
|
|
|
|
|
2,748 |
|
|
|
2,155 |
|
|
|
|
|
|
|
|
Other (Expenses) Income
|
|
|
|
|
|
|
|
|
Commissions earned
|
|
|
|
|
|
|
3,384 |
|
Other
|
|
|
(784 |
) |
|
|
(85 |
) |
|
|
|
(784 |
) |
|
|
3,299 |
|
|
|
|
|
|
|
|
Between July 2004 and December 2005, the Company earned
commissions for the assistance provided by DLS management to a
related party (see Note 17) in securing significant
contracts with certain unrelated parties. The commissions were
calculated as a percentage of the actual revenue generated by
such contracts and accrued over the term of the contracts. This
was a non-recurring income.
|
|
Note 17. |
Certain agreements and transactions with related parties |
DLS and Pan American Energy LLC, or PAE, a company that is
approximately 40% owned by an affiliate of the current owners of
DLS, entered into a five-year strategic agreement for the
purpose of solidifying a long-term alliance for the drilling of
oil and gas wells in the San Jorge basin (see
Note 18.1). In the periods ended June 30, 2006 and
2005 Company billed PAE a net aggregate of approximately
USD 50,996 and USD 34,349 respectively in respect of
drilling and related services provided by DLS; services rendered
to PAE represented approximately 62% and 56% of DLSs
revenue
F-163
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 17. Certain agreements
and transactions with related parties (continued)
in those periods. Also under the strategic agreement, DLS
borrowed from PAE the amount of USD 5,545 during 2004 to
purchase rigs to be used in drilling services to this customer.
This loan bears interest at a 8% p.a. rate.
In the periods ended June 30, 2006 and 2005 the Company
paid an aggregate amount of approximately USD 4,193 and
USD 3,348 respectively, to Tanus Argentina S.A., a related
party, for the purchase of drilling fluids (see Note 18.3).
In 2005 the Company acquired drilling rigs from
Compañía de Perforaciones Río Colorado S.A., a
related party, for USD 15,140.
The Company received certain financing loans from a related
party, Hudson Global Strategies Limited, in the normal course of
business. The outstanding balance as of June 30, 2006 and
as of December 31, 2005 was USD 17,700 and
USD 27,043 respectively. These loans bear interest at a 6%
p.a. rate.
In 2004 the Company purchased from Barrancas Sur S.A., a related
party, a 90% interest in exploratory blocks General Lamadrid and
Juarez for oil and gas exploration. In March 2006, the Company
entered into an agreement to sell its interest in the
exploratory block to its co-owner Barrancas Sur S.A. The
transfer was made at book value on the date of sale. In 2006 the
Company sold real property in the amount of USD 750 to a
related party.
Executive and other services such as data processing, rent and
miscellaneous administrative and technical services were entered
into by the Company with related parties. In the periods ended
June 2006 and 2005 the Company paid to such related parties an
aggregate amount of approximately USD 573 and USD 777
respectively, in respect of said items.
In the period ended June 30, 2005, the Company earned
commissions from Interoil Services Enterprise Limited, a related
party, in the amount of USD 3,384.
The following table summarizes the outstanding balances at each
period and year end, arising from the transactions described
above.
|
|
|
|
|
|
|
|
|
|
|
June 30, | |
|
December 31, | |
|
|
2006 | |
|
2005 | |
|
|
| |
|
| |
Accounts receivable trade
|
|
|
17,715 |
|
|
|
5,076 |
|
Trade accounts payable and accrued expenses
|
|
|
472 |
|
|
|
1,073 |
|
Short term debt
|
|
|
6,361 |
|
|
|
5,437 |
|
Long term debt
|
|
|
17,339 |
|
|
|
21,605 |
|
Other liabilities current
|
|
|
1,442 |
|
|
|
9,027 |
|
Other liabilities non-current
|
|
|
|
|
|
|
782 |
|
F-164
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
|
|
Note 18. |
Commitments and contingencies |
DLS and PAE, a related party, entered into a five-year strategic
agreement for the purpose of solidifying a long-term alliance
for the drilling of oil and gas wells in the San Jorge
basin. The completion and repair of all wells in the area is
also part of the agreement. The strategic agreement expires in
June 2008. PAE represented approximately 62% and 56% of
DLSs revenue in the periods ended June 30, 2006 and
2005, respectively. PAE may terminate the agreement without
cause on 60 days notice or in the case of a spin-off
or merger of DLS that is not consented to by PAE. There is no
provision allowing early termination by DLS and there are no
change of control provisions. In accordance with the strategic
agreement, DLS shall ensure the availability of at least three
drilling rigs, eight workover rigs and five pulling rigs in
order to meet PAEs drilling plans but, in turn, PAE will
provide DLS a sufficient number of drilling locations to keep
all such rigs and associated equipment working during the term
of the strategic agreement, provided that there are no material
changes in the price of oil or adverse results of the production
forecasts. The drilling rigs rates under the agreement are
subject to an efficiency factor for drilling depths up to 2,700
meters. The agreement incorporates a standard drilling time in
hours for a typical drilling prospect up to 2,700 meters.
Drilling beyond 2,700 meters or drilling prospects with
non-standard procedures are at agreed upon hourly rates plus
reimbursable materials and expenses.
|
|
|
18.2. Drilling fluid
contract |
DLS entered into a drilling service contract with Repsol-YPF.
The term of the contract is three years and comprises 50% of all
drilling and fluid services required by the customer in the
Neuquen basin where Repsol-YPF is drilling with approximately
20 rigs. DLS derived 14% and 15% of its revenues from this
contract, in the six month periods ended on June 30, 2006
and 2005, respectively.
|
|
|
18.3. Source of
drilling fluids |
DLS purchases a wide variety of drilling fluids as well as
components made by manufacturers and suppliers for use in its
operations. The products used by DLS are manufactured by other
parties. DLS is not dependent on any single source of supply for
any of its raw materials; however, DLS has a long-term agreement
with Tanus, a supplier of chemical specialties used in mud
service, from which DLS agreed to purchase through 2009 the
chemicals it uses to provide mud services. DLS may terminate
these agreement without cause on six months notice.
The Company is routinely involved in other litigation, claims
and disputes incidental to its business, related to its labor
agreements, which at times involves claims, some of which would
not be covered by insurance. In the opinion of management, none
of the existing litigation will have a material adverse effect
on the Companys financial position, results of operations
or cash flows.
F-165
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
The Company leases space used for the executive offices of the
branch in Argentina of DLS Argentina Limited. This lease is for
an initial three-year term expiring in 2007. It has been
classified as an operating lease. The approximate minimum annual
rental commitment estimated at June 30, 2006 is USD 70
for each of the next three years. The total rental expense
associated with this lease for the periods ended June 30,
2006 and 2005 was USD 36 and USD 32, respectively.
|
|
Note 20. |
Fair value of financial instruments |
The following table presents the carrying amounts and estimated
fair values of the Companys financial instruments at
June 30, 2006. The fair value of a financial instrument is
the amount at which the instrument could be exchanged in a
current transaction between willing parties.
|
|
|
|
|
|
|
|
|
|
|
Carrying | |
|
Fair | |
|
|
amount | |
|
value | |
|
|
| |
|
| |
Cash and cash equivalents
|
|
|
492 |
|
|
|
492 |
|
Accounts receivable
|
|
|
29,244 |
|
|
|
29,244 |
|
Accounts payable
|
|
|
17,270 |
|
|
|
17,270 |
|
Short-term debt
|
|
|
8,861 |
|
|
|
8,861 |
|
Long-term debt
|
|
|
17,453 |
|
|
|
17,453 |
|
Other liabilities
|
|
|
2,105 |
|
|
|
2,105 |
|
The following methods and assumptions were used to estimate the
fair value of each class of financial instruments:
|
|
|
|
|
Cash and cash equivalents, trade accounts receivable, other
assets, short term debt, trade accounts payable, accrued
expenses: The carrying amounts approximate fair value because of
the short maturity of these instruments. |
|
|
|
Long-term debt: The fair value of the Companys long-term
debt is estimated by discounting the future cash flows of each
instrument at rates currently offered to the Company for similar
debt instruments of comparable maturities by the Companys
bankers. |
|
|
Note 21. |
New accounting pronouncements |
SFAS No. 151, Inventory Costs, was issued by the
Financial Accounting Standards Board (FASB) in November
2004. This statement amends Accounting Research
Bulletin No. 43, to clarify that abnormal amounts of
idle facility expense, freight, handling costs, and wasted
materials should be recognized as current-period charges, and it
also requires that allocation of fixed production overheads be
based on the normal capacity of the related production
facilities. The provisions of this statement are effective for
inventory costs incurred during fiscal years beginning after
June 15, 2005, and applied prospectively. The adoption of
this statement did not have a material impact on its financial
position or results of operations in the future.
F-166
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 21. New accounting
pronouncements (continued)
FASB issued in December 2004 SFAS No. 153, Exchanges
of Non-monetary Assets, An Amendment of APB Opinion No. 29.
This statement addresses the measurement of exchanges of
non-monetary assets and eliminates the exception from fair value
measurement for non-monetary exchanges of similar productive
assets and replaces it with an exception for exchanges that do
not have commercial substance. SFAS No. 153 is
effective for non-monetary asset exchanges occurring in fiscal
periods beginning after June 15, 2005. The provisions of
this statement are applied prospectively. The adoption of this
statement did not have a material impact on its financial
position or results of operations in the future.
In May 2005, FASB issued the SFAS No. 154, Accounting
Changes and Error Corrections. This statement replaces APB
Opinion No. 20, Accounting Changes, and FASB Statement
No. 3, Reporting Accounting Change in Interim Financial
Statements, and changes the requirements for the accounting and
reporting of a change in an accounting principle. The adoption
of this statement did not have any effect on the Companys
consolidated financial statements.
On April 4, 2005, FASB adopted Staff Position FSP
FAS 19-1 that amends SFAS No. 19 Financial
Accounting and Reporting by Oil and Gas Producing Companies, to
permit the continued capitalization of exploratory well costs
beyond one year if (a) the well found a sufficient quantity
of reserves to justify its completion as a producing well and
(b) the entity is making sufficient progress assessing the
reserves and the economic and operating viability of the
project. The guidance in the FSP is required to be applied
prospectively as from the third quarter of 2005. The adoption of
this FSP did not have any impact on the Companys 2005
results of operations.
In September 2005, the Emerging Issue Task Force
(EITF) concluded in
Issue 04-13,
Accounting for Purchases and Sales of Inventory with the Same
Counterparty, that two or more exchange transactions involving
inventory with the same counterparty that are entered into in
contemplation of one another should be combined for purposes of
evaluating the effect of APB Opinion 29, Accounting for
Non-monetary Transactions. Additionally, the EITF reached a
consensus that a non-monetary exchange where an entity transfers
finished goods inventory in exchange for the receipt of raw
materials or
work-in-progress
inventory within the same line of business should generally be
recognized by the entity at fair value. The consensus in this
issue should be applied to transactions completed in reporting
periods beginning after March 15, 2006, whether pursuant to
arrangements that were in place at the date of initial
application of the consensus or arrangements executed subsequent
to that date. The adoption of this EITF did not have a material
impact on its financial position or results of operations in the
future.
In December 2004, the FASB issued SFAS No. 123
(revised 2004), Share-Based Payment, which addresses the
accounting for transactions in which an entity exchanges its
equity instruments for goods or services, with a primary focus
on transactions in which an entity obtains employee services in
share-based payment transactions. This Statement is a revision
to Statement 123 and supersedes APB Opinion No. 25,
Accounting for Stock Issued to Employees, and its related
implementation guidance. This Statement requires measurement of
the cost of employee services received in exchange for stock
compensation based on the grant-date fair value of the employee
stock options. Incremental
F-167
DLS DRILLING, LOGISTICS & SERVICES CORPORATION
NOTES TO THE UNAUDITED INTERIM CONSOLIDATED
FINANCIAL STATEMENTS (Continued)
Amounts expressed in thousands of US Dollars
Note 21. New accounting
pronouncements (continued)
compensation costs arising from subsequent modifications of
awards after the grant date must be recognized. The adoption of
this Statement on January 1, 2006 did not have any effect
on its financial positions or results of operations.
On February 16, the FASB issued SFAS No. 155,
Accounting for Certain Hybrid Financial Instruments, which
amends SFAS No. 133 and No. 140 and allows
financial instruments that have embedded derivatives that
otherwise would require bifurcation from the host to be
accounted for as a whole, if the holder irrevocably elects to
account for the whole instrument on a fair value basis.
Subsequent changes in the fair value of the instrument would be
recognized in earnings. The provisions of this Statement
effective for all financial instruments acquired or issued after
the beginning of an entitys first fiscal year that begins
after September 15, 2006. The adoption of this Statement is
not expected to have any material impact on the Companys
financial position or the results of its operations.
|
|
Note 22. |
Stockholders equity |
At June 30, 2006, and December 31, 2005, the
authorized share capital of DLS was USD 70,000, of which
USD 42,963 had been issued and was outstanding, represented
by 42,963,374 shares. Each share has a par value of one
U.S. Dollar and is entitled to one vote. The shares are
identical in all respects. During 2005, the Company received a
contribution of additional paid in capital in the aggregate
amount of USD 4,140. This contribution of additional paid
in capital was made by the shareholders in the same proportion
to their ownership interest. No additional common shares were
issued.
|
|
Note 23. |
Subsequent events |
On August 14, 2006, Allis Chalmers Energy Inc. completed
the acquisition of all of the outstanding capital stock of DLS.
The terms and conditions of the transaction are set forth in
the S-1
registration statement filed by Allis Chalmers Energy Inc. with
the Securities and Exchange Commission (U.S.).
F-168
UNAUDITED PRO FORMA AS ADJUSTED
CONSOLIDATED FINANCIAL INFORMATION
Introduction
Our unaudited pro forma as adjusted balance sheet as of
June 30, 2006 reflects the following transactions as if
they occurred on June 30, 2006 (in thousands):
|
|
|
|
|
Our acquisition of DLS, for the consideration described above
under DLS Business, including the assumption
of $8.6 million of DLS currently existing
indebtedness and the issuance of 2.5 million shares of our
common stock to the sellers, as adjusted for the August 2006
offering of our 9.0% senior notes and the sale of an additional
3.5 million shares of our common stock to fund a portion of
the cash component of the purchase price for this acquisition.
The following table summarizes the preliminary allocation of the
purchase price to the estimated fair value of the assets
acquired and liabilities assumed as if the acquisition occurred
on June 30, 2006 (in thousands): |
|
|
|
|
|
|
Current assets
|
|
$ |
52,651 |
|
Property and equipment
|
|
|
150,851 |
|
Other long-term assets
|
|
|
2 |
|
|
|
|
|
|
Total assets acquired
|
|
|
203,504 |
|
|
|
|
|
Current liabilities
|
|
|
31,968 |
|
Long-term debt
|
|
|
8,614 |
|
Other long term liabilities
|
|
|
27,000 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
67,582 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
135,922 |
|
|
|
|
|
|
|
|
We expect to incur approximately $4.6 million of
acquisition costs in connection with this acquisition. DLS
historical property and equipment values are expected to be
increased by approximately $42.3 million based on
third-party valuations. We do not expect any material
differences from the preliminary allocation of the purchase
price and actual purchase price allocation. |
Our unaudited pro forma as adjusted condensed consolidated
statement of operations for the six months ended June 30,
2006 reflects the following transactions as if such transactions
occurred on January 1, 2005:
|
|
|
|
|
Our acquisition of Rogers, which closed on April 3, 2006.
The following table summarizes the allocation of the purchase
price to the estimated fair value of the assets acquired and
liabilities assumed at the date of acquisition (in thousands): |
|
|
|
|
|
|
Current assets
|
|
$ |
4,520 |
|
Property and equipment
|
|
|
9,886 |
|
Intangible assets
|
|
|
1,131 |
|
|
|
|
|
|
Total assets acquired
|
|
|
15,517 |
|
|
|
|
|
Current liabilities
|
|
|
1,717 |
|
Other long term liabilities
|
|
|
100 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
1,756 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
13,700 |
|
|
|
|
|
F-169
|
|
|
We paid the purchase price with $11.3 million in cash (of
which we borrowed $5.0 million under our line of credit), a
$750,000 seller financed note and 125,285 newly issued shares of
our common stock, which had a value of $1.7 million. We
incurred approximately $341,000 of acquisition costs in
connection with the Rogers acquisition. Rogers historical
property and equipment book values were increased by
approximately $8.4 million based on third-party valuations.
Intangible assets include $981,000 assigned to patents and
$150,000 assigned to a non-compete agreement based on
third-party valuations and an employment contract. The
intangibles have a weighted-average useful life of 11 years. |
|
|
|
|
|
our acquisition of DLS for the consideration described above
under DLS Business, including the assumption
of $8.6 million of DLS currently existing
indebtedness and the issuance of 2.5 million shares of our
common stock to the sellers as the stock component of the
purchase price therefor; |
|
|
|
the sale of $95.0 million aggregate principal amount of
notes in August 2006; and |
|
|
|
our issuance of an additional 3.5 million shares of our
common stock in order to fund a portion of the cash component of
the purchase price for the pending DLS acquisition. The pro
forma treats the shares as having been issued at a price of
$14.50 per share. |
Our unaudited pro forma as adjusted condensed consolidated
statement of operations for the year ended December 31,
2005 reflects the following transactions as if such transactions
occurred on January 1, 2005:
|
|
|
|
|
Our acquisition of Delta Rental Service, Inc., which closed on
April 1, 2005. The following table summarizes the
allocation of the purchase price to the estimated fair value of
the assets acquired and liabilities assumed at the date of
acquisition (in thousands): |
|
|
|
|
|
|
Current assets
|
|
$ |
1,327 |
|
Property and equipment
|
|
|
5,529 |
|
Intangible assets
|
|
|
150 |
|
|
|
|
|
|
Total assets acquired
|
|
|
7,006 |
|
|
|
|
|
Current liabilities
|
|
|
633 |
|
Long-term debt
|
|
|
523 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
1,156 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
5,850 |
|
|
|
|
|
|
|
|
We paid the purchase price with approximately $4.5 million
in cash, newly issued shares of our common stock valued at
approximately $1.0 million and two promissory notes
totaling $350,000 in principal amount. We incurred approximately
$28,000 of acquisition costs in connection with the Delta
acquisition. Deltas historical property and equipment
values were increased by approximately $4.2 million based
on third-party valuations. The fair value of the $150,000
non-compete intangible asset was based on the related employment
contract and has a useful life of 3 years. |
F-170
|
|
|
|
|
Our acquisition of Capcoil Tubing Services, Inc., which closed
on May 2, 2005. The following table summarizes the
allocation of the purchase price to the estimated fair value of
the assets acquired and liabilities assumed at the date of
acquisition (in thousands): |
|
|
|
|
|
|
Current assets
|
|
$ |
1,706 |
|
Property and equipment
|
|
|
2,908 |
|
Other long-term assets
|
|
|
11 |
|
Intangible assets
|
|
|
1,389 |
|
Goodwill
|
|
|
184 |
|
|
|
|
|
|
Total assets acquired
|
|
|
6,198 |
|
|
|
|
|
Current liabilities
|
|
|
847 |
|
Long-term debt
|
|
|
1,851 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
2,698 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
3,500 |
|
|
|
|
|
|
|
|
We paid the purchase price with approximately $2.7 million
in cash and newly issued shares of our common stock valued at
approximately $750,000. We incurred approximately $26,000 of
acquisition costs in connection with the Capcoil acquisition.
Capcoils historical property and equipment book values
were increased by approximately $1.0 million based on
third-party valuations. Intangible assets include
$1.0 million assigned to non-compete agreements included in
employment contracts and $364,000 assigned to customer lists
based on third-party valuations. The intangibles have a
weighted-average useful life of 5 years. |
|
|
|
|
|
Our acquisition of the assets of W.T. Enterprises, Inc., which
closed on July 11, 2005. The following table summarizes the
allocation of the purchase price to the estimated fair value of
the assets acquired at the date of acquisition (in thousands): |
|
|
|
|
|
|
Property and equipment
|
|
|
4,500 |
|
Intangible assets
|
|
|
1,481 |
|
Goodwill
|
|
|
82 |
|
|
|
|
|
|
Total assets acquired
|
|
$ |
6,063 |
|
|
|
|
|
|
|
|
We paid the purchase price with borrowings under our line of
credit. We incurred approximately $63,000 of acquisition costs
in connection with the W.T. Enterprises, Inc. acquisition. W.T.
Enterprises, Inc.s historical property and equipment book
values were increased by approximately $3.0 million based
on third-party valuations. Intangible assets include $600,000
assigned to non-compete agreements and $881,000 assigned to
customer lists based on third-party valuations. The intangibles
have a weighted-average useful life of 8 years. |
|
|
|
|
|
Our acquisition of the minority interest in AirComp LLC from
M-I LLC and a
subordinated note in the principal amount of $4.8 million,
which closed on July 11, 2005. We paid the purchase price
with $7.1 million in cash from borrowings under our line of
credit and the issuance of a new $4.0 million 5%
subordinated note. |
F-171
|
|
|
|
|
Our acquisition of Specialty, which closed on January 18,
2006. The following table summarizes the allocation of the
purchase price to the estimated fair value of the assets
acquired and liabilities assumed at the date of acquisition (in
thousands): |
|
|
|
|
|
|
Accounts receivable
|
|
$ |
7,167 |
|
Other current assets
|
|
|
425 |
|
Property and equipment
|
|
|
90,540 |
|
|
|
|
|
|
Total assets acquired
|
|
|
98,132 |
|
|
|
|
|
Current liabilities
|
|
|
2,058 |
|
Long-term debt
|
|
|
74 |
|
|
|
|
|
|
Total liabilities assumed
|
|
|
2,132 |
|
|
|
|
|
|
Net assets acquired
|
|
$ |
96,000 |
|
|
|
|
|
|
|
|
We paid the purchase price with net proceeds from our issuance
of 9% senior notes in January 2006. We incurred approximately
$453,000 of acquisition costs in connection with the Specialty
acquisition. Specialtys historical property and equipment
book values were increased by approximately $71.5 million
based on third-party valuations. |
|
|
|
|
|
our issuance of $160.0 million aggregate principal amount
of 9% senior notes in January 2006; |
|
|
|
our acquisition of Rogers, which closed on April 3, 2006,
for $11.3 million in cash (of which we borrowed
$5.0 million under our debt facility), the issuance of a
$750,000 three year promissory note and the issuance of
125,285 shares of our common stock; |
|
|
|
our acquisition of DLS for the consideration described above
under DLS Business, including the assumption
of $8.6 million of DLS indebtedness and the issuance
of 2.5 million shares of our common stock to the sellers as
the stock component of the purchase price for DLS; |
|
|
|
our sale of $95.0 million aggregate principal amount of
notes in August 2006; and |
|
|
|
our issuance of an additional 3.5 million shares of our
common stock in order to fund a portion of the cash component of
the purchase price for the DLS acquisition. The pro forma treats
the shares as having been issued at a price of $14.50 per share. |
However, the pro forma as adjusted statement of operations
information presented below does not give effect to our
immaterial acquisition of Target Energy, Inc., which was
acquired effective August 1, 2005, and our acquisition of
certain casing and tubing assets from Patterson Services, Inc.
on September 1, 2005.
Adjustments for the above-listed transactions on an individual
basis are presented in the notes to the unaudited pro forma as
adjusted financial statements.
Certain information normally included in the financial
statements prepared in accordance with GAAP has been condensed
or omitted in accordance with the rules and regulations of the
SEC. The unaudited pro forma as adjusted financial statements
and accompanying notes should be read in conjunction with the
historical financial statements and related notes thereto
appearing elsewhere herein. The unaudited pro forma as adjusted
consolidated condensed financial statements do not purport to be
indicative of the results of operations or financial position
that we actually would have achieved if the transactions had
been consummated on the dates indicated, nor do they project our
results of operations or financial position for any future
period or date.
F-172
ALLIS-CHALMERS ENERGY INC. AND SUBSIDIARIES
UNAUDITED PRO FORMA CONSOLIDATED STATEMENT OF FINANCIAL
POSITION
AS OF JUNE 30, 2006
(In thousands)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Allis- | |
|
|
|
DLS | |
|
Financing | |
|
Allis- | |
|
|
Chalmers | |
|
DLS | |
|
Pro Forma | |
|
Pro Forma | |
|
Chalmers | |
|
|
Consolidated | |
|
Historical | |
|
Adjustments | |
|
Adjustments | |
|
Consolidated | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
ASSETS
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents
|
|
$ |
6,208 |
|
|
$ |
492 |
|
|
$ |
(97,772 |
)AA |
|
$ |
135,236 |
AB |
|
$ |
44,164 |
|
Trade receivables, net
|
|
|
49,114 |
|
|
|
29,244 |
|
|
|
|
|
|
|
|
|
|
|
78,358 |
|
Inventories
|
|
|
9,897 |
|
|
|
16,608 |
|
|
|
|
|
|
|
|
|
|
|
26,505 |
|
Prepaids and other
|
|
|
2,655 |
|
|
|
6,307 |
|
|
|
|
|
|
|
|
|
|
|
8,962 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Assets
|
|
|
67,874 |
|
|
|
52,651 |
|
|
|
(97,772 |
) |
|
|
135,236 |
|
|
|
157,989 |
|
Property and equipment, net
|
|
|
185,750 |
|
|
|
108,593 |
|
|
|
42,258 |
AC |
|
|
|
|
|
|
336,601 |
|
Goodwill
|
|
|
12,417 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
12,417 |
|
Other intangibles, net
|
|
|
7,131 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
7,131 |
|
Debt issuance costs, net
|
|
|
6,187 |
|
|
|
|
|
|
|
|
|
|
|
2,538 |
AD |
|
|
8,725 |
|
Other assets
|
|
|
1,327 |
|
|
|
2 |
|
|
|
|
|
|
|
|
|
|
|
1,329 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets
|
|
$ |
280,686 |
|
|
$ |
161,246 |
|
|
$ |
(55,514 |
) |
|
$ |
137,774 |
|
|
$ |
524,192 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current maturities of long-term debt
|
|
$ |
4,059 |
|
|
$ |
8,861 |
|
|
$ |
(6,361 |
)AE |
|
$ |
|
|
|
$ |
6,559 |
|
Trade accounts payable
|
|
|
9,616 |
|
|
|
17,270 |
|
|
|
|
|
|
|
|
|
|
|
26,886 |
|
Accrued employee benefits
|
|
|
2,270 |
|
|
|
12,593 |
|
|
|
|
|
|
|
|
|
|
|
14,863 |
|
Accrued interest
|
|
|
6,654 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,654 |
|
Accrued expenses
|
|
|
7,781 |
|
|
|
2,105 |
|
|
|
|
|
|
|
|
|
|
|
9,886 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Current Liabilities
|
|
|
30,380 |
|
|
|
40,829 |
|
|
|
(6,361 |
) |
|
|
|
|
|
|
64,848 |
|
Accrued postretirement benefit obligations
|
|
|
319 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
319 |
|
Long-term debt, net of current maturities
|
|
|
165,957 |
|
|
|
17,453 |
|
|
|
(11,339 |
)AE |
|
|
91,000 |
AF |
|
|
263,071 |
|
Other long-term liabilities
|
|
|
749 |
|
|
|
749 |
|
|
|
26,251 |
AG |
|
|
|
|
|
|
27,749 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total liabilities
|
|
|
197,405 |
|
|
|
59,031 |
|
|
|
8,551 |
|
|
|
91,000 |
|
|
|
355,987 |
|
|
STOCKHOLDERS EQUITY
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Common stock
|
|
|
185 |
|
|
|
42,963 |
|
|
|
(42,938 |
)AH |
|
|
35 |
AI |
|
|
245 |
|
Capital in excess of par value
|
|
|
67,261 |
|
|
|
31,606 |
|
|
|
6,519 |
AH |
|
|
46,739 |
AI |
|
|
152,125 |
|
Retained earnings
|
|
|
15,835 |
|
|
|
27,646 |
|
|
|
(27,646 |
)AH |
|
|
|
|
|
|
15,835 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders Equity
|
|
|
83,281 |
|
|
|
102,215 |
|
|
|
(64,065 |
) |
|
|
46,774 |
|
|
|
168,205 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Liabilities and Stockholders Equity
|
|
$ |
280,686 |
|
|
$ |
161,246 |
|
|
$ |
(55,514 |
) |
|
$ |
137,774 |
|
|
$ |
524,192 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See notes to unaudited pro forma consolidated financial
statements.
F-173
ALLIS-CHALMERS ENERGY INC. AND SUBSIDIARIES
UNAUDITED PRO FORMA CONSOLIDATED STATEMENT OF OPERATIONS
FOR THE SIX MONTHS ENDED JUNE 30, 2006
(In thousands, except per share data)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Allis- | |
|
|
|
Rogers | |
|
|
|
DLS | |
|
|
|
Allis- | |
|
|
Chalmers | |
|
Rogers | |
|
Purchase | |
|
DLS | |
|
Purchase | |
|
Offering | |
|
Chalmers | |
|
|
Consolidated | |
|
Historical | |
|
Adjustments | |
|
Historical | |
|
Adjustments | |
|
Adjustments | |
|
Consolidated | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
107,498 |
|
|
$ |
2,085 |
|
|
$ |
|
|
|
$ |
82,019 |
|
|
|
|
|
|
|
|
|
|
$ |
191,602 |
|
Cost of revenues
|
|
|
66,239 |
|
|
|
1,105 |
|
|
|
121 |
A |
|
|
68,490 |
|
|
|
(462 |
) B |
|
|
|
|
|
|
135,493 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
41,259 |
|
|
|
980 |
|
|
|
(121 |
) |
|
|
13,529 |
|
|
|
462 |
|
|
|
|
|
|
|
56,109 |
|
General and administrative expense
|
|
|
16,755 |
|
|
|
820 |
|
|
|
33 |
C |
|
|
2,205 |
|
|
|
|
|
|
|
158 |
D |
|
|
19,971 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from
operations
|
|
|
24,504 |
|
|
|
160 |
|
|
|
(154 |
) |
|
|
11,324 |
|
|
|
462 |
|
|
|
(158 |
) |
|
|
36,138 |
|
Other income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
|
|
|
|
2 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2 |
|
|
Interest expense
|
|
|
(7,425 |
) |
|
|
|
|
|
|
(109 |
) E |
|
|
(2,748 |
) |
|
|
913 |
F |
|
|
(3,976 |
) G |
|
|
(13,345 |
) |
|
Other
|
|
|
20 |
|
|
|
(7 |
) |
|
|
|
|
|
|
(784 |
) |
|
|
|
|
|
|
|
|
|
|
(771 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before taxes
|
|
|
17,099 |
|
|
|
155 |
|
|
|
(263 |
) |
|
|
7,792 |
|
|
|
1,375 |
|
|
|
(4,134 |
) |
|
|
22,024 |
|
Taxes
|
|
|
(3,081 |
) |
|
|
|
|
|
|
|
H |
|
|
(3,512 |
) |
|
|
303 |
I |
|
|
|
H |
|
|
(6,290 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from continuing operations
|
|
|
14,018 |
|
|
|
155 |
|
|
|
(263 |
) |
|
|
4,280 |
|
|
|
1,678 |
|
|
|
(4,134 |
) |
|
|
15,734 |
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2,375 |
|
|
|
|
|
|
|
|
|
|
|
2,375 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
14,018 |
|
|
$ |
155 |
|
|
$ |
(263 |
) |
|
$ |
6,655 |
|
|
$ |
1,678 |
|
|
$ |
(4,134 |
) |
|
$ |
18,109 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income per common share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
$ |
0.80 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.67 |
|
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
0.10 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.80 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.77 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
$ |
0.74 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.63 |
|
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.09 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.74 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.72 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares outstanding
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
17,578 |
|
|
|
|
|
|
|
63 |
J |
|
|
|
|
|
|
2,500 |
J |
|
|
3,450 |
K |
|
|
23,591 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
19,000 |
|
|
|
|
|
|
|
63 |
J |
|
|
|
|
|
|
2,500 |
J |
|
|
3,450 |
K |
|
|
25,013 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See Notes to Unaudited pro forma consolidated financial
statements.
F-174
ALLIS-CHALMERS ENERGY INC. AND SUBSIDIARIES
UNAUDITED PRO FORMA CONSOLIDATED STATEMENT OF OPERATIONS
FOR THE YEAR ENDED DECEMBER 31, 2005
(In thousands, except per share data)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Allis- | |
|
|
|
Delta | |
|
|
|
Capcoil | |
|
W.T. | |
|
W.T. ENT | |
|
MI | |
|
|
Chalmers | |
|
Delta | |
|
Purchase | |
|
Capcoil | |
|
Purchase | |
|
ENT | |
|
Purchase | |
|
Purchase | |
|
|
Consolidated | |
|
Historical | |
|
Adjustments | |
|
Historical | |
|
Adjustments | |
|
Historical | |
|
Adjustments | |
|
Adjustments | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
105,344 |
|
|
$ |
821 |
|
|
$ |
|
|
|
$ |
2,161 |
|
|
$ |
|
|
|
$ |
2,057 |
|
|
$ |
|
|
|
$ |
|
|
Cost of revenues
|
|
|
74,763 |
|
|
|
211 |
|
|
|
82 |
A |
|
|
1,458 |
|
|
|
132 |
A |
|
|
1,331 |
|
|
|
187 |
A |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
30,581 |
|
|
|
610 |
|
|
|
(82 |
) |
|
|
703 |
|
|
|
(132 |
) |
|
|
726 |
|
|
|
(187 |
) |
|
|
|
|
General and
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
administrative expense
|
|
|
17,363 |
|
|
|
985 |
|
|
|
|
|
|
|
421 |
|
|
|
28 |
L |
|
|
342 |
|
|
|
75 |
L |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
operations
|
|
|
13,218 |
|
|
|
(375 |
) |
|
|
(82 |
) |
|
|
282 |
|
|
|
(160 |
) |
|
|
384 |
|
|
|
(262 |
) |
|
|
|
|
Other income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
|
|
|
|
3 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest expense
|
|
|
(4,397 |
) |
|
|
(11 |
) |
|
|
|
|
|
|
(26 |
) |
|
|
|
|
|
|
(17 |
) |
|
|
|
|
|
|
21 |
O |
|
|
Other
|
|
|
186 |
|
|
|
116 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before taxes
|
|
|
9,007 |
|
|
|
(267 |
) |
|
|
(82 |
) |
|
|
256 |
|
|
|
(160 |
) |
|
|
367 |
|
|
|
(262 |
) |
|
|
21 |
|
Minority interest
|
|
|
(488 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
488 |
R |
Taxes
|
|
|
(1,344 |
) |
|
|
(142 |
) |
|
|
142 |
H |
|
|
(87 |
) |
|
|
87 |
H |
|
|
(111 |
) |
|
|
111 |
H |
|
|
|
H |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) from continuing operations
|
|
|
7,175 |
|
|
|
(409 |
) |
|
|
60 |
|
|
|
169 |
|
|
|
(73 |
) |
|
|
256 |
|
|
|
(151 |
) |
|
|
509 |
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) attributed to common shares
|
|
$ |
7,175 |
|
|
$ |
(409 |
) |
|
$ |
60 |
|
|
$ |
169 |
|
|
$ |
(73 |
) |
|
$ |
256 |
|
|
$ |
(151 |
) |
|
$ |
509 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income (loss) per common share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
$ |
0.48 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.48 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
$ |
0.44 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.44 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares outstanding
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
14,832 |
|
|
|
|
|
|
|
55 |
S |
|
|
|
|
|
|
62 |
S |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
16,238 |
|
|
|
|
|
|
|
55 |
S |
|
|
|
|
|
|
62 |
S |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See Notes to Unaudited pro forma consolidated financial
statements.
F-175
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Specialty | |
|
|
|
|
|
Rogers | |
|
|
|
DLS | |
|
|
|
Allis- | |
|
|
Specialty | |
|
Purchase | |
|
Debt | |
|
Rogers | |
|
Purchase | |
|
DLS | |
|
Purchase | |
|
Offering | |
|
Chalmers | |
|
|
Historical | |
|
Adjustments | |
|
Adjustments | |
|
Historical | |
|
Adjustments | |
|
Historical | |
|
Adjustments | |
|
Adjustments | |
|
Consolidated | |
|
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
|
| |
Revenues
|
|
$ |
32,709 |
|
|
$ |
|
|
|
$ |
|
|
|
$ |
8,376 |
|
|
$ |
|
|
|
$ |
129,849 |
|
|
$ |
|
|
|
$ |
|
|
|
$ |
281,317 |
|
Cost of revenues
|
|
|
8,550 |
|
|
|
5,564 |
A |
|
|
|
|
|
|
4,420 |
|
|
|
499 |
A |
|
|
113,351 |
|
|
|
637 |
B |
|
|
|
|
|
|
211,185 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Gross profit
|
|
|
24,159 |
|
|
|
(5,564 |
) |
|
|
|
|
|
|
3,956 |
|
|
|
(499 |
) |
|
|
16,498 |
|
|
|
(637 |
) |
|
|
|
|
|
|
70,132 |
|
General and administrative expense
|
|
|
7,232 |
|
|
|
(386 |
)M |
|
|
700 |
N |
|
|
2,527 |
|
|
|
138 |
L |
|
|
3,933 |
|
|
|
|
|
|
|
317 |
D |
|
|
33,675 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) from operations
|
|
|
16,927 |
|
|
|
(5,178 |
) |
|
|
(700 |
) |
|
|
1,429 |
|
|
|
(637 |
) |
|
|
12,565 |
|
|
|
(637 |
) |
|
|
(317 |
) |
|
|
36,457 |
|
Other income
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Interest income
|
|
|
136 |
|
|
|
|
|
|
|
|
|
|
|
53 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
192 |
|
|
Interest expense
|
|
|
(185 |
) |
|
|
(8,640 |
)P |
|
|
(1,363 |
)Q |
|
|
|
|
|
|
(438 |
)E |
|
|
(5,394 |
) |
|
|
2,178 |
F |
|
|
(7,950 |
) G |
|
|
(26,222 |
) |
|
Other
|
|
|
72 |
|
|
|
|
|
|
|
|
|
|
|
237 |
|
|
|
|
|
|
|
7,127 |
|
|
|
|
|
|
|
|
|
|
|
7,738 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income (loss) before taxes
|
|
|
16,950 |
|
|
|
(13,818 |
) |
|
|
(2,063 |
) |
|
|
1,719 |
|
|
|
(1,075 |
) |
|
|
14,298 |
|
|
|
1,541 |
|
|
|
(8,267 |
) |
|
|
18,165 |
|
Minority interest
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Taxes
|
|
|
|
|
|
|
|
H |
|
|
|
H |
|
|
|
|
|
|
|
H |
|
|
(3,547 |
) |
|
|
(1,997 |
)I |
|
|
|
H |
|
|
(6,888 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss) from continuing operations
|
|
|
16,950 |
|
|
|
(13,818 |
) |
|
|
(2,063 |
) |
|
|
1,719 |
|
|
|
(1,075 |
) |
|
|
10,751 |
|
|
|
(456 |
) |
|
|
(8,267 |
) |
|
|
11,277 |
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(4,138 |
) |
|
|
|
|
|
|
|
|
|
|
(4,138 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income (loss)
|
|
$ |
16,950 |
|
|
$ |
(13,818 |
) |
|
$ |
(2,063 |
) |
|
$ |
1,719 |
|
|
$ |
(1,075 |
) |
|
$ |
6,613 |
|
|
$ |
(456 |
) |
|
$ |
(8,267 |
) |
|
$ |
7,139 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pro forma net income (loss) per common share
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.54 |
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(0.20 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.34 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Continuing operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.50 |
|
Discontinued operations
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(0.18 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
0.32 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted average shares outstanding
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
125 |
J |
|
|
|
|
|
|
2,500 |
J |
|
|
3,450 |
K |
|
|
21,024 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
125 |
J |
|
|
|
|
|
|
2,500 |
J |
|
|
3,450 |
K |
|
|
22,430 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
See Notes to Unaudited pro forma consolidated financial
statements.
F-176
ALLIS-CHALMERS ENERGY INC
NOTES TO UNAUDITED PRO FORMA CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS
The following pro forma adjustments have been made to the
historical financial statements:
|
|
|
AA)
|
|
Reflects the cash needed to complete the acquisition. |
|
AB)
|
|
Reflects the cash raised from the August 2006 offering of our
9.0% senior notes and the concurrent offering, issuance and sale
of 3.5 million shares of our common stock. |
|
AC)
|
|
Reflects the step-up in the basis of the fixed assets as a
result of the acquisition to the lower of fair market value or
actual cost. |
|
AD)
|
|
Fees and expenses related to the offering, issuance and sale of
$95.0 million of senior notes in the August 2006 offering. |
|
AE)
|
|
Reflects the repayment of debt of the acquisitions prior to the
acquisition. |
|
AF)
|
|
Reflects the proceeds of the sale of $95.0 million of
senior notes in the August 2006 offering, and the repayment of a
$4.0 million subordinated note with proceeds from the
August 2006 notes offering. |
|
AG)
|
|
Reflects deferred taxes on the acquisition due to differences
between the book and tax basis of acquired assets. |
|
AH)
|
|
Reflects the elimination of DLS stockholders equity
and the issuance of 2.5 million shares in the DLS
acquisition, as the stock component of the purchase price. |
|
AI)
|
|
Reflects the additional stock issued in connection with our
concurrent offering of an additional 3.5 million shares of
common stock to fund a portion of the cash component of the
purchase price for the DLS acquisition, net of expenses. |
|
A) |
|
Reflects the increase in depreciation expense as a result of the
step-up in basis of fixed assets. |
|
B) |
|
Reflects the impact on depreciation expense as a result of the
step-up in basis of fixed assets and a longer estimated life on
DLS assets. |
|
C) |
|
Reflects the increase in amortization due to the increase in
other intangible assets in connection with the acquisition of
Rogers. |
|
D) |
|
Reflects the amortization on the financing fees related to the
offering, issuance and sale of $95.0 million of senior
notes in the August 2006 notes offering. |
|
E) |
|
Reflects the interest expense related to cash borrowed to affect
the acquisitions. In conjunction with the Rogers acquisition, we
issued a $750,000 note to the seller bearing interest at 5%
fixed and we borrowed $5.0 million under our line of
credit. We assumed an 8% interest rate for this
$5.0 million borrowing which is our current borrowing rate
under our committed line of credit. Each 0.125% of change in
this interest rate would affect interest expense by $6,250 per
annum. |
|
F) |
|
Reflects the elimination of interest expense due to historical
debt not being assumed or replaced. Approximately
$8.6 million of existing debt for DLS will remain
outstanding after |
F-177
ALLIS-CHALMERS ENERGY INC
NOTES TO UNAUDITED PRO FORMA CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
|
|
|
|
|
the acquisition. The interest rate assumed on the
$8.6 million of DLS debt was 6.21%, which was the actual
average interest rate on this debt as of June 30, 2006.
Each 0.125% change in this interest rate would affect interest
expense by $10,770 per annum. The interest expense category for
DLS historical financials also includes other bank fees
and other financial expenses of approximately $1.6 million
at June 30, 2006 and $2.7 million at December 31,
2005. |
|
G) |
|
Reflects the interest expense related to the offering, issuance
and sale of $95.0 million of senior notes in the August
2006 notes offering bearing interest at 9.0% offset by reduction
of interest on existing debt that were repaid in conjunction
with the offerings. We repaid our $4.0 million, 5%
subordinated note with a portion of the net proceeds of the
August 2006 notes offering. We also repaid the $5.0 million
of indebtedness borrowed for the Rogers acquisition under our
revolving line of credit with proceeds of the August 2006 notes
offering. |
|
H) |
|
A statutory tax rate of 35% was applied to the adjustments, but
since Allis-Chalmers has a net operating loss carryforward no
tax expense was recorded. In addition, the Allis-Chalmers net
operating loss position offset the historical tax liabilities of
acquired companies. The net operating loss carryforward, after
the historical results for Allis-Chalmers for the year ended
December 31, 2005, is approximately $15.4 million. |
|
I) |
|
Income taxes for DLS were computed at the Argentinian statutory
rate of 35%. Allis-Chalmers has no net operating losses in
Argentina to offset the tax liability. |
|
J) |
|
Reflects the issuance of shares of our common stock as part of
the acquisition price for Rogers and DLS. The Rogers
acquisition, completed April 1, 2006, included
consideration of $1,650,000 in stock which equated to 125,285
shares of our common stock. The stock component of the purchase
price for the DLS acquisition is comprised of 2.5 million
shares of our common stock. |
|
K) |
|
Reflects the issuance of shares of our common stock as a result
of our concurrent offering of an additional 3.5 million
shares of common stock to fund a portion of the cash component
of the purchase price for the DLS acquisition. The pro forma
treats the shares as having been issued at a price of $14.50 per
share. |
|
L) |
|
Reflects the increase in amortization due to the increase in
other intangible assets in connection with the acquisitions of
Capcoil, W. T. Enterprises and Rogers. |
|
M) |
|
Reflects decreased rent expense of $386,000 that will result
from the acquisition of Specialty. We entered into a new lease
for the Specialty yard with the seller. Entering into this lease
was required by the purchase agreement and was a condition to
the closing of the Specialty acquisition. |
|
N) |
|
Reflects the amortization on the financing fees related to the
$160.0 million senior notes offering in January 2006. |
|
O) |
|
To acquire M-Is 45% interest in AirComp we issued a new
note for $4.0 million to replace a note for
$4.8 million, both notes bore interest at 5.0%. |
F-178
ALLIS-CHALMERS ENERGY INC
NOTES TO UNAUDITED PRO FORMA CONSOLIDATED CONDENSED
FINANCIAL STATEMENTS (Continued)
|
|
|
P) |
|
Reflects the interest expense on the $96.0 million of the
$160.0 million of senior notes issued in January 2006 used
to complete the acquisition of Specialty. The senior notes have
a fixed interest rate of 9%. |
|
Q) |
|
Reflects the interest expense related to the proceeds of the
$160.0 million senior notes offering in January 2006 in
excess of cash needed for the Specialty acquisition. The senior
notes have a fixed interest rate of 9%. |
|
R) |
|
Reflects the elimination of the 45% minority interest position
of M-I. |
|
S) |
|
Reflects the issuance of shares of our common stock as part of
the acquisition price for Delta, and Capcoil. The Delta
acquisition included consideration of $1.0 million in our
common stock, the Capcoil acquisition included consideration of
$765,000 in common stock. |
F-179
$255,000,000
Allis-Chalmers Energy Inc.
Offer to Exchange
All Outstanding 9.0% Senior Notes due 2014
for
9.0% Senior Notes due 2014
PROSPECTUS
EXCHANGE AGENT
WELLS FARGO BANK, N.A.
By Registered or Certified Mail:
Wells Fargo Bank, N.A.
MAC N9303-121
P.O. Box 1517
Minneapolis, MN 55480-1517
Attn: Corporate Trust Operations
By Regular Mail/ Hand/ Overnight Delivery:
Wells Fargo Bank, N.A.
Sixth and Marquette
MAC N9303-121
Minneapolis, MN 55479
Attn: Corporate Trust Operations
For Assistance Call:
800-344-5128
Fax Number (for eligible institutions only):
612-667-4927
UNTIL ,
2006, ALL DEALERS THAT EFFECT TRANSACTIONS IN THESE SECURITIES,
WHETHER OR NOT PARTICIPATING IN THIS OFFERING, MAY BE REQUIRED
TO DELIVER A PROSPECTUS. THIS IS IN ADDITION TO THE
DEALERS OBLIGATION TO DELIVER A PROSPECTUS WHEN ACTING AS
UNDERWRITERS AND WITH RESPECT TO THEIR UNUSED ALLOTMENTS OR
SUBSCRIPTIONS.
,
2006
PART II
INFORMATION NOT REQUIRED IN THE PROSPECTUS
Item 20. Indemnification of Directors and
Officers.
The registrants Amended and Restated Certificate of
Incorporation (the Certificate of Incorporation) and
its by-laws provide for the indemnification by the registrant of
each director, officer and employee of the registrant to the
fullest extent permitted by the Delaware General Corporation
Law, as the same exists or may hereafter be amended.
Section 145 of the Delaware General Corporation Law
provides in relevant part that a corporation may indemnify any
person who was or is a party or is threatened to be made a party
to any threatened, pending or completed action, suit or
proceeding, whether civil, criminal, administrative or
investigative (other than an action by or in the right of the
corporation) by reason of the fact that such person is or was a
director, officer, employee or agent of the corporation, or is
or was serving at the request of the corporation as a director,
officer, employee or agent of another corporation, partnership,
joint venture, trust or other enterprise, against expenses
(including attorneys fees), judgments, fines and amounts
paid in settlement actually and reasonably incurred by such
person in connection with such action, suit or proceeding if
such person acted in good faith and in a manner such person
reasonably believed to be in or not opposed to the best
interests of the corporation, and, with respect to any criminal
action or proceeding, had no reasonable cause to believe such
persons conduct was unlawful.
In addition, Section 145 provides that a corporation may
indemnify any person who was or is a party or is threatened to
be made a party to any threatened, pending or completed action
or suit by or in the right of the corporation to procure a
judgment in its favor by reason of the fact that such person is
or was a director, officer, employee or agent of the
corporation, or is or was serving at the request of the
corporation as a director, officer, employee or agent of another
corporation, partnership, joint venture, trust or other
enterprise against expenses (including attorneys fees)
actually and reasonably incurred by such person in connection
with the defense or settlement of such action or suit if such
person acted in good faith and in a manner such person
reasonably believed to be in or not opposed to the best
interests of the corporation and except that no indemnification
shall be made in respect of any claim, issue or matter as to
which such person shall have been adjudged to be liable to the
corporation unless and only to the extent that the Delaware
Court of Chancery or the court in which such action or suit was
brought shall determine upon application that, despite the
adjudication of liability but in view of all the circumstances
of the case, such person is fairly and reasonably entitled to
indemnity for such expenses which the Delaware Court of Chancery
or such other court shall deem proper. Delaware law further
provides that nothing in the above described provisions shall be
deemed exclusive of any other rights to indemnification or
advancement of expenses to which any person may be entitled
under any bylaw, agreement, vote of stockholders or
disinterested directors or otherwise.
The registrants Certificate of Incorporation provides that
a director of the registrant shall not be liable to the
registrant or its stockholders for monetary damages for breach
of fiduciary duty as a director. Section 102(o)(7) of the
Delaware General Corporation Law provides that a provision so
limiting the personal liability of a director shall not
eliminate or limit the liability of a director for, among other
things: breach of the duty of loyalty; acts or omissions not in
good faith or which involve intentional misconduct or a knowing
violation of the law; unlawful payment of dividends; and
transactions from which the director derived an improper
personal benefit.
The registrant has entered into separate but identical indemnity
agreements (the Indemnity Agreements) with each
director of the registrant and certain officers of the
registrant (the
II-1
Indemnitees). Pursuant to the terms and conditions
of the Indemnity Agreements, the registrant indemnified each
Indemnitee against any amounts which he or she becomes legally
obligated to pay in connection with any claim against him or her
based upon any action or inaction which he or she may commit,
omit or suffer while acting in his or her capacity as a director
and/or officer of the registrant or its subsidiaries, provided,
however, that Indemnitee acted in good faith and in a manner
Indemnitee reasonably believed to be in or not opposed to the
best interests of the registrant and, with respect to any
criminal action, had no reasonable cause to believe
Indemnitees conduct was unlawful.
|
|
Item 21. |
Exhibits and Financial Statement Schedules. |
(a) Exhibits. The exhibits listed in the
accompanying Exhibit Index are filed (except where
otherwise indicated) as part of this registration statement.
(b) Financial Statement Schedules. No financial
statement schedules are included in Part II of this
registration statement because the information required to be
set forth herein is not applicable or is shown in our
consolidated financial statements or the notes thereto.
(a) Insofar as indemnification for liabilities arising
under the Securities Act may be permitted to directors, officers
and controlling persons of the registrant pursuant to the
foregoing provisions, or otherwise, the registrant has been
advised that, in the opinion of the Securities and Exchange
Commission, such indemnification is against public policy as
expressed in the Securities Act and is, therefore,
unenforceable. In the event that a claim for indemnification
against such liabilities (other than the payment by the
registrant of expenses incurred or paid by a director, officer
or controlling person of the registrant in the successful
defense of any action, suit or proceeding) is asserted by such
director, officer or controlling person in connection with the
securities being registered, the registrant will, unless, in the
opinion of its counsel, the matter has been settled by
controlling precedent, submit to a court of appropriate
jurisdiction the question whether such indemnification by it is
against public policy as expressed in the Securities Act and
will be governed by the final adjudication of such issue.
(b) The undersigned registrant hereby undertakes to respond
to requests for information that is incorporated by reference
into the prospectus pursuant to Items 4, 10(b), 11, or 13
of Form S-4,
within one business day of receipt of such request, and to send
the incorporated documents by first class mail or other equally
prompt means. This includes information contained in documents
filed subsequent to the effective date of the registration
statement through the date of responding to the request.
(c) The undersigned registrant hereby undertakes to supply
by means of a post-effective amendment all information
concerning a transaction, and the company being acquired
involved therein, that was not the subject of and included in
the registration statement when it became effective.
II-2
SIGNATURES
Pursuant to the requirements of the Securities Act of 1933, the
registrant has duly caused this amendment to be signed on its
behalf by the undersigned, thereunto duly authorized, in the
city of Houston, State of Texas, on this 8th day of
September, 2006.
|
|
|
ALLIS-CHALMERS ENERGY INC. |
|
|
|
|
|
Victor M. Perez |
|
Chief Financial Officer |
Pursuant to requirements of the Securities Act, this amendment
has been signed on September 8, 2006 by the following
persons in the capacities indicated.
|
|
|
*
Munawar
H. Hidayatallah
Chief Executive Officer and Chairman of the Board
(Principal Executive Officer) |
|
*
David
Wilde
President and Chief Operating Officer |
|
/s/ Victor M. Perez
Victor
M. Perez
Chief Financial Officer
(Principal Financial Officer) |
|
*
Bruce
Sauers
Chief Accounting Officer
(Principal Accounting Officer) |
|
Alejandro
P. Bulgheroni
Director |
|
Carlos
A. Bulgheroni
Director |
|
*
Jeffrey
R. Freedman
Director |
|
*
Victor
F. Germack
Director |
|
*
John
E. McConnaughy, Jr.
Director |
|
*
Robert
E. Nederlander
Director |
|
*
Leonard
Toboroff
Director |
|
|
|
*By: /s/ Victor M.
Perez
Victor
M. Perez
Attorney-in-fact |
|
|
II-3
Pursuant to the requirements of the Securities Act of 1933, each
of the co-registrants set forth below (the
Guarantors) has duly caused this amendment to be
signed on its behalf by the undersigned, thereunto duly
authorized, in the city of Houston, State of Texas, on this
8th day of September, 2006.
|
|
|
AIRCOMP L.L.C. |
|
ALLIS-CHALMERS GP, LLC |
|
ALLIS-CHALMERS PRODUCTION |
|
SERVICES, INC. |
|
ALLIS-CHALMERS RENTAL TOOLS, INC. |
|
ALLIS-CHALMERS TUBULAR SERVICES, INC. |
|
MOUNTAIN COMPRESSED AIR, INC. |
|
OILQUIP RENTALS, INC. |
|
ROGERS OIL TOOL SERVICES, INC. |
|
STRATA DIRECTIONAL TECHNOLOGY, INC. |
|
TARGET ENERGY, INC. |
|
|
|
|
|
Name: Theodore F. Pound III |
|
Title: Vice President and Secretary |
|
|
ALLIS-CHALMERS MANAGEMENT, LP |
|
|
By: Allis-Chalmers GP, LLC, its sole general partner |
|
|
|
|
|
Name: Theodore F. Pound III |
|
Title: Vice President and Secretary |
|
|
ALLIS-CHALMERS LP, LLC |
|
|
|
|
|
Name: Jeffrey R. Freedman |
|
Title: Vice President and Secretary |
|
|
|
|
|
|
Victor M. Perez |
|
|
|
Attorney-in-fact |
|
Pursuant to the requirements of the Securities Act, this
amendment has been signed on September 8, 2006 by the
following persons in the capacities indicated.
|
|
|
In their collective capacity as the board of directors of:
ALLIS-CHALMERS TUBULAR SERVICES, INC. |
|
*
|
|
*
|
Munawar
H. Hidayatallah,
Director |
|
Theodore
F. Pound III,
Director |
II-4
|
|
|
|
In their collective capacity as the board of directors of each
of the following Guarantors:
ALLIS-CHALMERS PRODUCTION SERVICES, INC.
ALLIS-CHALMERS RENTAL TOOLS, INC.
STRATA DIRECTIONAL TECHNOLOGY, INC.
TARGET ENERGY, INC. |
|
*
|
|
*
|
Munawar
H. Hidayatallah,
Director |
|
Theodore
F. Pound III,
Director |
|
|
*
|
|
|
|
|
|
David Wilde, |
|
|
Director |
|
|
|
|
In his capacity as the sole member of the board of directors of
each of the following Guarantors:
MOUNTAIN COMPRESSED AIR, INC.
OILQUIP RENTALS INC. |
|
|
|
|
*
|
|
|
Munawar
H. Hidayatallah
Director |
|
|
In their collective capacity as the board of directors of:
ROGERS OIL TOOL SERVICES, INC. |
|
|
*
|
|
*
|
Munawar
H. Hidayatallah,
Director |
|
Theodore
F. Pound III,
Director |
|
|
In their collective capacity as all of the managers of each of
the following Guarantors:
AIRCOMP L.L.C.
ALLIS-CHALMERS GP, LLC |
|
|
*
|
|
*
|
Munawar
H. Hidayatallah,
Manager |
|
Theodore
F. Pound III,
Manager |
|
|
*
|
|
|
David
Wilde,
Manager |
|
|
II-5
|
|
|
In their collective capacity as all of the managers of:
ALLIS-CHALMERS LP, LLC |
|
*
|
|
*
|
Jeffrey
R. Freedman,
Manager |
|
Leonard
Toboroff,
Manager |
|
In its capacity as the sole general partner of:
ALLIS-CHALMERS MANAGEMENT, LP
Allis-Chalmers GP, LLC,
sole general partner |
|
|
By: *
Theodore
F. Pound III
Vice President and Secretary |
|
|
|
|
*By: /s/ Victor M.
Perez
Victor
M. Perez
Attorney-in-fact |
|
|
II-6
EXHIBIT INDEX
|
|
|
|
|
Exhibit |
|
Description |
|
|
|
|
2 |
.1 |
|
First Amended Disclosure Statement pursuant to Section 1125
of the Bankruptcy Code, dated September 14, 1988, which
includes the First Amended and Restated Joint Plan of
Reorganization dated September 14, 1988 (incorporated by
reference to Registrants Current Report on Form 8-K
dated December 1, 1988). |
|
2 |
.2 |
|
Agreement and Plan of Merger dated as of May 9, 2001 by and
among Registrant, Allis-Chalmers Acquisition Corp. and OilQuip
Rentals, Inc. (incorporated by reference to Registrants
Current Report on Form 8-K filed May 15, 2001). |
|
2 |
.3 |
|
Stock Purchase Agreement dated February 1, 2002 by and
between Registrant and Jens H. Mortensen, Jr. (incorporated
by reference to Registrants Current Report on
Form 8-K filed February 21, 2002). |
|
2 |
.4 |
|
Shareholders Agreement dated February 1, 2002 by and among
Jens Oilfield Service, Inc., a Texas corporation, Jens H.
Mortensen, Jr., and Registrant (incorporated by reference
to Registrants Annual Report on Form 10-K for the
year ended December 31, 2001). |
|
2 |
.5 |
|
Stock Purchase Agreement dated February 1, 2002 by and
among Registrant, Energy Spectrum Partners LP, and Strata
Directional Technology, Inc. (incorporated by reference to
Registrants Annual Report on Form 10-K for the year
ended December 31, 2001). |
|
2 |
.6 |
|
Joint Venture Agreement dated June 27, 2003 by and between
Mountain Compressed Air, Inc. and M-I L.L.C. (incorporated by
reference to Registrants Current Report on Form 8-K
filed July 16, 2003). |
|
2 |
.7 |
|
Stock Purchase Agreement dated as of December 20, 2005
between the Registrant and Joe Van Matre (incorporated by
reference to the Registrants Annual Report on
Form 10-K for the year ended December 31, 2005). |
|
2 |
.8 |
|
Stock Purchase Agreement, dated as of April 27, 2006, by
and among Bridas International Holdings Ltd., Bridas Central
Company Ltd., Associated Petroleum Investors Limited, and the
Registrant. (incorporated by reference to the Registrants
Quarterly Report on Form 10-Q for the quarter ended
March 31, 2006) |
|
3 |
.1 |
|
Amended and Restated Certificate of Incorporation of Registrant
(incorporated by reference to Registrants Annual Report on
Form 10-K for the year ended December 31, 2001). |
|
3 |
.2 |
|
Certificate of Designation, Preferences and Rights of the
Series A 10% Cumulative Convertible Preferred Stock
($.01 Par Value) of Registrant (incorporated by
reference to Registrants Current Report on Form 8-K
filed February 21, 2002). |
|
3 |
.3 |
|
Amended and Restated By-laws of Registrant (incorporated by
reference to Registrants Annual Report on Form 10-K
for the year ended December 31, 2001). |
|
3 |
.4 |
|
Certificate of Amendment of Certificate of Incorporation filed
with the Delaware Secretary of State on June 9, 2004
(incorporated by reference to the Registrants Quarterly
Report on Form 10-Q for the quarter ended June 30,
2004). |
|
3 |
.5 |
|
Certificate of Amendment of Certificate of Incorporation filed
with the Delaware Secretary of State on January 5, 2005
(incorporated by reference to the Registrants Current
Report on Form 8-K filed January 11, 2005). |
|
4 |
.1 |
|
Specimen Stock Certificate of Common Stock of Registrant
(incorporated by reference to the Registrants Quarterly
Report on Form 10-Q for the quarter ended June 30,
2004). |
|
4 |
.2 |
|
Registration Rights Agreement dated as of March 31, 1999,
by and between Allis-Chalmers Corporation and the Pension
Benefit Guaranty Corporation (incorporated by reference to the
Registrants Quarterly Report on Form 10-Q for the
quarter ended June 30, 1999). |
|
4 |
.3 |
|
Option Agreement dated October 15, 2001 by and between
Registrant and Leonard Toboroff (incorporated by reference to
Registrants Quarterly Report on Form 10-Q for the
quarter ended September 30, 2001). |
|
4 |
.4 |
|
Warrant Purchase Agreement dated February 1, 2002 by and
between Allis-Chalmers Corporation and Wells Fargo Energy
Capital, Inc., including form of warrant (incorporated by
reference to the Registrants Current Report on
Form 8-K filed February 21, 2002). |
|
|
|
|
|
Exhibit |
|
Description |
|
|
|
|
4 |
.5 |
|
2003 Incentive Stock Plan (incorporated by reference to
Registrants Annual Report on Form 10-K for the year
ended December 31, 2002). |
|
4 |
.6 |
|
Form of Option Certificate issued pursuant to 2003 Incentive
Stock Plan (incorporated by reference to Registrants
Annual Report on Form 10-K for the year ended
December 31, 2002). |
|
4 |
.7 |
|
Form of warrant issued to Investors pursuant to Stock and
Warrant Purchase Agreement dated April 2, 2004 by and among
Registrant and Donald Engel, Christopher Engel, Engel Defined
Benefit Plan, RER Corp. and Leonard Toboroff (incorporated by
reference to Registrants Quarterly Report on
Form 10-Q for the quarter ended June 30, 2004). |
|
4 |
.8 |
|
Registration Rights Agreement dated April 2, 2004 by and
between Registrant and the Stockholder signatories thereto
(incorporated by reference to Registrants Quarterly Report
on Form 10-Q for the quarter ended June 30, 2004). |
|
4 |
.9 |
|
Warrant dated May 19, 2004, issued to Jeffrey R. Freedman
(incorporated by reference to the Registration Statement on
Form S-1 (Registration No. 118916) filed on
September 10, 2004). |
|
4 |
.10 |
|
Amendment to 2003 Stock Option Plan (incorporated by reference
to Quarterly Report of Form 10-Q for the quarter ended
September 30, 2005). |
|
4 |
.11 |
|
Indenture dated as of January 18, 2006 by and among the
Registrant, the Guarantors named therein and Wells Fargo Bank,
N.A., as trustee (incorporated by reference to the
Registrants Current Report on Form 8-K filed on
January 24, 2006). |
|
4 |
.12 |
|
Form of 9.0% Senior Note due 2014 (incorporated by
reference to the Registrants Current Report on
Form 8-K filed on January 24, 2006). |
|
4 |
.13 |
|
Registration Rights Agreement dated as of January 18, 2006,
by and among Allis-Chalmers Energy Inc., the Guarantor parties
thereto and the Initial Purchaser parties thereto (incorporated
by reference to the Registrants Current Report on
Form 8-K filed on January 24, 2006). |
|
4 |
.14 |
|
Registration Rights Agreement dated as of August 14, 2006,
by and among Allis-Chalmers Energy Inc., the Guarantor parties
thereto and the Initial Purchaser party thereto (incorporated by
reference to the Registrants Current Report on
Form 8-K filed on August 14, 2006). |
|
5 |
.1* |
|
Opinion of Andrews Kurth LLP regarding the legality of the
securities being registered hereby. |
|
8 |
.1* |
|
Opinion of Andrews Kurth LLP regarding material
U.S. federal income tax matters. |
|
9 |
.1 |
|
Shareholders Agreement dated February 1, 2002 by and among
Registrant and the stockholder and warrant holder signatories
thereto (incorporated by reference to Registrants Annual
Report on Form 10-K for the year ended December 31,
2001). |
|
10 |
.1 |
|
Amended and Restated Retiree Health Trust Agreement dated
September 14, 1988 by and between Registrant and Wells
Fargo Bank (incorporated by reference to Exhibit C-1 of the
First Amended and Restated Joint Plan of Reorganization dated
September 14, 1988 included in Registrants Current
Report on Form 8-K dated December 1, 1988). |
|
10 |
.2 |
|
Amended and Restated Retiree Health Trust Agreement dated
September 18, 1988 by and between Registrant and Firstar
Trust Company (incorporated by reference to Exhibit C-2 of
the First Amended and Restated Joint Plan of Reorganization
dated September 14, 1988 included in Registrants
Current Report on Form 8-K dated December 1, 1988). |
|
10 |
.3 |
|
Reorganization Trust Agreement dated September 14, 1988 by
and between Registrant and John T. Grigsby, Jr., Trustee
(incorporated by reference to Exhibit D of the First
Amended and Restated Joint Plan of Reorganization dated
September 14, 1988 included in Registrants Current
Report on Form 8-K dated December 1, 1988). |
|
10 |
.4 |
|
Product Liability Trust Agreement dated September 14, 1988
by and between Registrant and Bruce W. Strausberg, Trustee
(incorporated by reference to Exhibit E of the First
Amended and Restated Joint Plan of Reorganization dated
September 14, 1988 included in Registrants Current
Report on Form 8-K dated December 1, 1988). |
|
10 |
.5 |
|
Allis-Chalmers Savings Plan (incorporated by reference to
Registrants Annual Report on Form 10-K for the year
ended December 31, 1988). |
|
10 |
.6 |
|
Allis-Chalmers Consolidated Pension Plan (incorporated by
reference to Registrants Annual Report on Form 10-K
for the year ended December 31, 1988). |
|
|
|
|
|
Exhibit |
|
Description |
|
|
|
|
10 |
.7 |
|
Agreement dated as of March 31, 1999 by and between
Registrant and the Pension Benefit Guaranty Corporation
(incorporated by reference to Registrants Quarterly Report
on Form 10-Q for the quarter ended June 30, 1999). |
|
10 |
.8 |
|
Letter Agreement dated May 9, 2001 by and between
Registrant and the Pension Benefit Guarantee Corporation
(incorporated by reference to Registrants Quarterly Report
on Form 10-Q filed on May 15, 2002). |
|
10 |
.9 |
|
Termination Agreement dated May 9, 2001 by and among
Registrant, the Pension Benefit Guarantee Corporation and others
(incorporated by reference to Registrants Current Report
on Form 8-K filed on May 15, 2002). |
|
10 |
.10 |
|
Option Agreement dated October 15, 2001 by and between
Registrant and Leonard Toboroff (incorporated by reference to
Registrants Quarterly Report on Form 10-Q for the
quarter ended September 30, 2001). |
|
10 |
.11 |
|
Employment Agreement dated July 1, 2003 by and between
AirComp LLC and Terry Keane (incorporated by reference to
Registrants Current Report on Form 8-K filed
July 16, 2003). |
|
10 |
.12 |
|
Letter Agreement dated February 13, 2004 by and between
Registrant and Morgan Joseph & Co., Inc. (incorporated
by reference to the Registration Statement on Form S-1
(Registration No. 118916) filed on September 10, 2004). |
|
10 |
.13 |
|
Employment Agreement dated as of April 1, 2004 by and
between Registrant and Munawar H. Hidayatallah (incorporated by
reference to Registrants Quarterly Report on
Form 10-Q for the quarter ended June 30, 2004). |
|
10 |
.14 |
|
Employment Agreement dated as of April 1, 2004 by and
between Registrant and David Wilde (incorporated by reference to
Registrants Quarterly Report on Form 10-Q for the
quarter ended June 30, 2004). |
|
10 |
.15 |
|
Fifth Amendment to Credit Agreement dated as of April 6,
2004 by and between Strata Directional Technology, Inc., and
Wells Fargo Credit Inc. (incorporated by reference to
Registrants Quarterly Report on Form 10-Q for the
quarter ended June 30, 2004). |
|
10 |
.16 |
|
Third Amendment to Credit Agreement dated as of April 6,
2004 by and between Jens Oilfield Service, Inc. and Wells
Fargo Credit Inc. (incorporated by reference to
Registrants Quarterly Report on Form 10-Q for the
quarter ended June 30, 2004). |
|
10 |
.17 |
|
Letter Agreement dated June 8, 2004 by and between the
Registrant and Morgan Keegan & Company, Inc.
(incorporated by reference to the Registration Statement on
Form S-1 (Registration No. 118916) filed on
September 10, 2004). |
|
10 |
.18 |
|
Employment Agreement dated July 26, 2004 by and between the
Registrant and Victor M. Perez (incorporated by reference to the
Registration Statement on Form S-1 (Registration
No. 118916) filed on September 10, 2004). |
|
10 |
.19 |
|
Stock Purchase Agreement dated August 10, 2004
(incorporated by reference to the Registration Statement on
Form S-1 (Registration No. 118916) filed on
September 10, 2004). |
|
10 |
.20 |
|
Amendment to Stock Purchase Agreement dated August 10, 2004
(incorporated by reference to the Registration Statement on
Form S-1 (Registration No. 118916) filed on
September 10, 2004). |
|
10 |
.21 |
|
Letter Agreement relating to Stock Purchase Agreement dated
August 5, 2004 (incorporated by reference to the
Registration Statement on Form S-1 (Registration
No. 118916) filed on September 10, 2004). |
|
10 |
.22 |
|
Addendum to Stock Purchase Agreement dated September 24,
2004 (incorporated by reference to Registrants Current
Report on Form 8-K filed on September 30, 2004). |
|
10 |
.23 |
|
Employment Agreement dated October 11, 2004, by and between
the Registrant and Theodore F. Pound III (incorporated by
reference to Registrants Current Report on Form 8-K
filed on October 15, 2004). |
|
10 |
.24 |
|
Asset Purchase Agreement dated November 10, 2004 by and
among AirComp LLC, a Delaware limited liability company, Diamond
Air Drilling Services, Inc., a Texas corporation, Marquis Bit
Co., L.L.C., a New Mexico limited liability company, Greg Hawley
and Tammy Hawley, residents of Texas and Clay Wilson and Linda
Wilson, residents of New Mexico (incorporated by reference to
the Current Report on Form 8-K filed on November 15,
2004). |
|
|
|
|
|
Exhibit |
|
Description |
|
|
|
|
10 |
.25 |
|
Amended and Restated Credit Agreement dated as of
December 7, 2004, by and between AirComp LLC and Wells
Fargo Bank, NA (incorporated by reference to Registrants
Current Report on Form 8-K filed on December 13, 2004). |
|
10 |
.26 |
|
Purchase Agreement and related Agreements by and among
Allis-Chalmers Corporation, Chevron USA, Inc., Dale Redman and
others dated December 10, 2004 (incorporated by reference
to the Registrants Current Report on Form 8-K filed
on December 16, 2004). |
|
10 |
.27 |
|
Stock Purchase Agreement dated April 1, 2005 by and among
the Registrant, Thomas Whittington, Sr., Werlyn R.
Bourgeois and SAM and D, LLC (incorporated by reference to the
Registrants Current Report on Form 8-K filed on
April 5, 2005). |
|
10 |
.28 |
|
Stock Purchase Agreement effective May 1, 2005, by and
among the Registrant, Wesley J. Mahone, Mike T. Wilhite, Andrew
D. Mills and Tim Williams (incorporated by reference to the
Registrants Current Report on Form 8-K filed on
May 6, 2005). |
|
10 |
.29 |
|
Purchase Agreement dated July 11, 2005 by and among the
Registrant, Mountain Compressed Air, Inc. and M-I, L.L.C.
(incorporated by reference to the Registrants Current
Report on Form 8-K filed on July 15, 2005). |
|
10 |
.30 |
|
Asset Purchase Agreement dated July 11, 2005 by and among
AirComp LLC, W.T. Enterprises, Inc. and William M. Watts
(incorporated by reference to the Registrants Current
Report on Form 8-K filed on July 15, 2005). |
|
10 |
.31 |
|
First Amendment to Stockholder Agreement by and among the
Registrant and the Stockholders named therein (incorporated by
reference to the Registrants Current Report on
Form 8-K filed on August 5, 2005). |
|
10 |
.32 |
|
Asset Purchase Agreement by and between Patterson Services, Inc.
and Allis-Chalmers Tubular Services, Inc. (incorporated by
reference to the Registrants Current Report on
Form 8-K filed on September 8, 2005). |
|
10 |
.33 |
|
Purchase Agreement dated as of January 12, 2006 by and
among the Registrant, the Guarantors named therein and the
Initial Purchasers named therein (incorporated by reference to
the Registrants Current Report on Form 8-K filed on
January 24, 2006). |
|
10 |
.34 |
|
Purchase Agreement dated as of August 14, 2006 by and among
the Registrant, the Guarantors named therein and the Initial
Purchaser named therein (incorporated by reference to the
Registrants Current Report on Form 8-K filed on
August 14, 2006). |
|
10 |
.35 |
|
Amended and Restated Credit Agreement dated as of
January 18, 2006 by and among the Registrant, as borrower,
Royal Bank of Canada, as administrative agent and collateral
agent, RBC Capital Markets, as lead arranger and sole
bookrunner, and the lenders party thereto (incorporated by
reference to the Registrants Current Report on
Form 8-K filed on January 24, 2006). |
|
10 |
.36 |
|
Stock Purchase Agreement dated December 20, 2005, by and
between Allis-Chalmers Energy, Inc. and Joe Van Matie
(incorporated by reference to the Registrants Annual
Report on Form 10-K filed on March 22, 2006). |
|
12 |
.1*** |
|
Statement of computation of ratio of earnings to fixed charges. |
|
16 |
.1 |
|
Letter from Gordon Hughes & Banks LLP dated
October 5, 2004 to the Securities and Exchange Commission
(incorporated by reference to the Registrants Current
Report on Form 8-K filed on October 6, 2004). |
|
21 |
.1 |
|
Subsidiaries of Registrant (incorporated by reference to the
Registrants Annual Report on Form 10-K for the year
ended December 31, 2005). |
|
23 |
.1** |
|
Consent of UHY Mann Frankfort Stein & Lipp CPAs, LLP. |
|
23 |
.2** |
|
Consent of Gordon, Hughes and Banks, LLP. |
|
23 |
.3** |
|
Consent of Wright, Moore, Dehart, Dupuis & Hutchinson,
LLC. |
|
23 |
.4** |
|
Consent of Curtis Blakely & Co., PC. |
|
23 |
.5** |
|
Consent of Accounting & Consulting Group, LLP. |
|
23 |
.6** |
|
Consent of UHY Mann Frankfort Stein & Lipp CPAs, LLP. |
|
23 |
.7** |
|
Consent of Sibille (formerly Finsterbusch Pickenhayn Sibille). |
|
|
|
|
|
Exhibit |
|
Description |
|
|
|
|
23 |
.8* |
|
Consent of Andrews Kurth LLP (to be included in
Exhibit 5.1). |
|
24 |
.1*** |
|
Powers of Attorney. |
|
25 |
.1*** |
|
Form T-1 Statement of Eligibility of Wells Fargo Bank, N.A. |
|
99 |
.1*** |
|
Form of Letter of Transmittal. |
|
99 |
.2*** |
|
Form of Guidelines for Certification of Taxpayer Identification
Number on Substitute Form W-9. |
|
99 |
.3*** |
|
Form of Notice of Guaranteed Delivery. |
|
99 |
.4*** |
|
Form of Letter to Brokers, Dealers, Commercial Banks, Trust
Companies and Other Nominees. |
|
99 |
.5*** |
|
Form of Letter to Clients. |
|
99 |
.6*** |
|
Form of Exchange Agent Agreement. |
|
|
* |
To be filed by amendment. |
|
** |
Filed herewith. |
|
|
*** |
Previously filed. |
|
|
|
Compensation plan or arrangement. |