UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)


þ		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE QUARTERLY PERIOD ENDED ~~June~~September 30, 2011


o		TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIOD FROM to TO

Commission file number 1-02199

ALLIS-CHALMERS ENERGY INC.

(Exact name of registrant as specified in its charter)

DELAWARE		27-~~33212~~3321250
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)
11125 Equity Drive, Suite 200, HOUSTON, TEXAS		77041
10613 W Sam Houston Parkway, Suite 600, HOUSTON, TEXAS		77064
(Address of principal executive offices)		(Zip Code)

(713) 856-4222

(713) 856-4222

Registrant’s telephone number, including area code

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (Section 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act:


Large accelerated filer o		Accelerated filer þ		Non-accelerated filer o (Do not check if a smaller reporting company)		Smaller reporting company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date. As of ~~August~~November 2618, 2011, ~~all of~~ the 1,000 issued and outstanding shares of Allis-Chalmers Energy Inc. ~~are~~ were held by Archer Limited.

Allis-Chalmers Energy Inc. meets the conditions set forth in general instruction H(1)(a) and (b) of Form 10-Q and is therefore filing this Form 10-Q with the reduced disclosure format.

ALLIS-CHALMERS ENERGY INC.

FORM 10-Q

For the Quarterly Period Ended ~~June~~September 30, 2011

TABLE OF CONTENTS

ITEM


PART I
ITEM
1. Financial Statements		3
Consolidated Condensed Balance Sheets as of September 30, 2011 (Successor Company) and December 31, 2010 (Predecessor Company)		3
Consolidated Condensed Statements of Operations for the three and seven months ended September 30, 2011 (Successor Company), two months ended February 28, 2011, three and nine months ended September 30, 2010 (Predecessor Company)		4
Consolidated Condensed Statement of Stockholders’ Equity as of September 30, 2011 (Successor Company), February 28, 2011 and December 31, 2010 (Predecessor Company)		5
Consolidated Condensed Statements of Cash Flows for the seven months ended September 30, 2011 (Successor Company), two months ended February 28, 2011 and nine months ended September 30, 2010 (Predecessor Company)		6
Notes to Unaudited Consolidated Condensed Financial Statements		7
2. Management’s Discussion and Analysis of Financial Condition and Results of Operations		31
4. Controls and Procedures		40
PART II
1. Legal Proceedings		41
6. Exhibits		41
Signatures		41
EX-31.1
EX-31.2
EX-32.1
EX-101 INSTANCE DOCUMENT
EX-101 SCHEMA DOCUMENT
EX-101 CALCULATION LINKBASE DOCUMENT
EX-101 LABELS LINKBASE DOCUMENT
EX-101 PRESENTATION LINKBASE DOCUMENT
EX-101 DEFINITION LINKBASE DOCUMENT

PART I
1. Financial Statements
Consolidated Condensed Balance Sheets as of June 30, 2011 (Successor Company) and December 31,2010 (Predecessor Company)			3
Consolidated Condensed Statements of Operations for the three and four months ended June 30, 2011 (Successor Company), two months ended February 28, 2011, three and six months ended June 30, 2010 (Predecessor Company)			4
Consolidated Condensed Statement of Stockholders’ Equity as of June 30, 2011(Successor Company), February 28, 2011 and December 31, 2010 (Predecessor Company)			5
Consolidated Condensed Statements of Cash Flows for the four months ended June 30, 2011 (Successor Company), two months ended February 28, 2011 and six months ended June 30, 2010 (Predecessor Company)			6
Notes to Unaudited Consolidated Condensed Financial Statements			7
2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			31
4. Controls and Procedures			40
PART II
6. Exhibits			41
Signatures			41
EX-31.1
EX-31.2
EX-32.1
EX-101 INSTANCE DOCUMENT
EX-101 SCHEMA DOCUMENT
EX-101 CALCULATION LINKBASE DOCUMENT
EX-101 LABELS LINKBASE DOCUMENT
EX-101 PRESENTATION LINKBASE DOCUMENT
EX-101 DEFINITION LINKBASE DOCUMENT

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

ALLIS-CHALMERS ENERGY INC.

CONSOLIDATED CONDENSED BALANCE SHEETS

(In thousands, except for share and per share amounts)

	Successor			~~Predecessor~~	Predecessor
	June 30,			December 31,
	September 30,				December 31,
	2011			~~2010~~	2010
	(unaudited)
	(Unaudited)
Assets
Cash and cash equivalents	$	1310,~~416~~191		$	~~20,940~~$	20,940
Restricted cash		3,784			—
Trade receivables, net		173,742				144,960
Trade receivables, net		174,380			144,960
Inventories		56,357				42,140
Inventories		50,026			42,140
Prepaid expenses and other		15,019				9,273
Deferred income tax asset		1,104			81
Total current assets		255,309				217,313
Prepaid expenses and other		18,734			9,192
Property and equipment, net		670,785				723,234
Total current assets		261,444			217,313
Goodwill		267,428				46,333
Property and equipment, net		675,581			723,234
Other intangible assets, net		91,957				33,899
Goodwill		267,428			46,333
Debt issuance costs, net		—				7,405
Other intangible assets, net		94,890			33,899
Deferred income tax asset		—				1,969
Debt issuance costs, net		—			7,405
Other assets		6,188				8,116
Deferred income tax asset		—			1,969
Total assets	$	1,291,667			$	1,038,269
Other assets		5,251			8,116
Liabilities and Stockholders’ Equity
Total assets	$	1,304,594		$	1,038,269
Current maturities of long-term debt	$	6,915			$	15,215
Liabilities and Stockholders’ Equity
Trade accounts payable		53,395				46,042
Current maturities of long-term debt	$	6,892		$	15,215
Accrued salaries, benefits and payroll taxes		32,879				32,790
Trade accounts payable		60,760			46,042
Accrued interest		3,525				15,524
Accrued salaries, benefits and payroll taxes		35,525			32,790
Accrued expenses		35,476				30,676
Accrued interest		15,199			15,524
Total current liabilities		132,190				140,247
Accrued expenses		41,912			30,676
Deferred income tax liability		17,054				8,240
Total current liabilities		160,288			140,247
Long-term debt, net of current maturities		454,693				478,225
Deferred income tax liability		16,989			8,240
Payable to parent		91,322				—
Long-term debt, net of current maturities		454,689			478,225
Other long-term liabilities		3				233
Payable to parent		74,403			—
Total liabilities		695,262				626,945
Other long-term liabilities		32			233
Commitments and Contingencies
Total liabilities		706,401			626,945
Stockholders’ Equity
Commitments and Contingencies
Preferred stock, $0.01 par value (0 shares authorized, 0 issued and outstanding at September 30, 2011 and 25,000,000 shares authorized, 36,393 issued and outstanding at December 31, 2010)		—				34,183
Stockholders’ Equity
Common stock, $0.01 par value (1,000 shares authorized, 1,000 issued and outstanding at September 30, 2011 and 200,000,000 authorized, 73,722,347 issued and outstanding at December 31, 2010)		—				737
Preferred stock, $0.01 par value (0 shares authorized, 0 issued and outstanding at June 30, 2011 and 25,000,000 authorized, 36,393 issued and outstanding at December 31, 2010)		—			34,183
Capital in excess of par value		600,885				429,924
Common stock, $0.01 par value (1,000 shares authorized, 1,000 issued and outstanding at June 30, 2011 and 200,000,000 authorized, 73,722,347 issued and outstanding at December 31, 2010)		—			737
Accumulated deficit		(4,480	)			(53,520	)
Capital in excess of par value		600,885			429,924
Total stockholders’ equity		596,405				411,324
Accumulated deficit		(2,692	)		(53,520	)
Total liabilities and stockholders’ equity	$	1,291,667			$	1,038,269
Total stockholders’ equity		598,193			411,324
Total liabilities and stockholders’ equity	$	1,304,594		$	1,038,269

The accompanying Notes are an integral part of the Consolidated Condensed Financial Statements.

ALLIS-CHALMERS ENERGY INC.

CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS (In thousands) (Unaudited)

(Unaudited)


	Successor						Predecessor
	Three Months			Seven Months			Two Months			Three Months			Nine Months
	Ended			Ended			Ended			Ended			Ended
	September 30,			September 30,			February 28,			September 30,			September 30,
	2011			2011			2011			2010			2010
Revenues	$	222,408		$	513,272		$	126,885		$	174,288		$	473,302

Operating costs and expenses:
Direct costs		164,729			378,493			97,130			127,622			356,060
Depreciation		24,785			55,131			15,026			21,094			61,799
Selling, general and administrative		18,600			38,777			23,752			12,772			36,949
Impairment of intangible assets		—			5,100			—			—			—
Amortization		2,933			8,743			811			1,255			3,567

Total operating costs and expenses		211,047			486,244			136,719			162,743			458,375


Income (loss) from operations		11,361			27,028			(9,834	)		11,545			14,927


Other income (expense):
Interest expense		(9,327	)		(23,140	)		(7,854	)		(11,881	)		(33,986	)
Interest income		9			20			5			45			499
Other		(431	)		(452	)		122			(661	)		(2,479	)

Total other expense		(9,749	)		(23,572	)		(7,727	)		(12,497	)		(35,966	)


Income (loss) before income taxes		1,612			3,456			(17,561	)		(952	)		(21,039	)

Income tax benefit (expense)		(3,400	)		(7,936	)		(1,736	)		(1,614	)		3,563


Net loss		(1,788	)		(4,480	)		(19,297	)		(2,566	)		(17,476	)

Preferred stock dividend		—			—			(375	)		(637	)		(1,911	)


Net loss attributed to common stockholders	$	(1,788	)	$	(4,480	)	$	(19,672	)	$	(3,203	)	$	(19,387	)

	Successor						Predecessor
	Three Months			Four Months			Two Months			Three Months			Six Months
	Ended			Ended			Ended			Ended			Ended
	June 30,			June 30,			February 28,			June 30,			June 30,
	2011			2011			2011			2010			2010
Revenues	$	220,138		$	290,864		$	126,885		$	158,644		$	299,014
Operating costs and expenses:
Direct costs		162,628			213,764			97,130			120,723			228,438
Depreciation		23,030			30,346			15,026			20,517			40,705
Selling, general and administrative		15,386			20,177			23,752			12,114			24,177
Impairment of intangible assets		—			5,100			—			—			—
Amortization		4,357			5,810			811			1,156			2,312
Total operating costs and expenses		205,401			275,197			136,719			154,510			295,632
Income (loss) from operations		14,737			15,667			(9,834	)		4,134			3,382
Other income (expense):
Interest expense		(10,067	)		(13,813	)		(7,854	)		(11,149	)		(22,105	)
Interest income		8			11			5			299			454
Other		(34	)		(21	)		122			(303	)		(1,818	)
Total other expense		(10,093	)		(13,823	)		(7,727	)		(11,153	)		(23,469	)
Income (loss) before income taxes		4,644			1,844			(17,561	)		(7,019	)		(20,087	)
Income tax benefit (expense)		(2,955	)		(4,536	)		(1,736	)		1,640			5,177
Net income (loss)		1,689			(2,692	)		(19,297	)		(5,379	)		(14,910	)
Preferred stock dividend		—			—			(375	)		(637	)		(1,274	)
Net income (loss) attributed to common stockholders	$	1,689		$	(2,692	)	$	(19,672	)	$	(6,016	)	$	(16,184	)

The accompanying Notes are an integral part of the Consolidated Condensed Financial Statements.

ALLIS-CHALMERS ENERGY INC.

CONSOLIDATED CONDENSED STATEMENT OF STOCKHOLDERS’ EQUITY

(In thousands, except share amounts)

(~~unaudited~~Unaudited)

									Capital in			Retained			Total
	Preferred Stock				Common Stock				Excess of			Earnings			Stockholders’
	Shares		Amount		Shares		Amount		Par Value			(Deficit)			Equity
Predecessor
Balances, December 31, 2010		36,393	$	34,183		73,722,347	$	737	$	429,924		$	(53,520	)	$	411,324
Net loss		—		—		—		—		—			(19,297	)		(19,297	)
Preferred stock dividend		—		—		—		—		—			(375	)		(375	)
Issuance of common stock:
Issuance under stock plans, net of tax		—		—		650,727		7		(1,828	)		—			(1,821	)
Stock-based compensation		—		—		—		—		6,084			—			6,084
Balances, February 28, 2011		36,393	$	34,183		74,373,074	$	744	$	434,180		$	(73,192	)	$	395,915
Successor
Capitalization at merger		—	$	—		1,000	$	—	$	600,885		$	—		$	600,885
Capitalization at Merger		—	$	—		1,000	$	—	$	600,885		$	—		$	600,885
Net loss		—		—		—		—		—			(24,~~692~~480	)		(24,~~692~~480	)
Balances, June 30, 2011		—	$	—		1,000	$	—	$	600,885		$	(2,692	)	$	598,193
Balances, September 30, 2011		—	$	—		1,000	$	—	$	600,885		$	(4,480	)	$	596,405

The accompanying Notes are an integral part of the Consolidated Condensed Financial Statements.

ALLIS-CHALMERS ENERGY INC.

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS ~~(In thousands)~~

(~~unaudited~~In thousands)

	Successor			Predecessor
	Four Months			Two Months			Six Months
	Ended			Ended			Ended
	June 30,			February 28,			June 30,
	2011			2011			2010
Cash Flows from Operating Activities:
Net loss	$	(2,692	)	$	(19,297	)	$	(14,910	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization		36,156			15,837			43,017
Amortization of deferred issuance costs		—			366			1,106
Debt premium amortization		(1,050	)		—			—
Stock-based compensation		—			6,084			3,001
Impairment of intangible assets		5,100			—			—
Allowance for bad debts		—			195			—
Deferred income taxes		(939	)		140			(10,821	)
Loss on investment		—			—			1,466
Equity in loss of unconsolidated affiliates		—			—			260
Loss on sale of property and equipment		171			416			807
Changes in operating assets and liabilities, net of acquisitions:
Increase in trade receivable		(14,908	)		(15,944	)		(25,845	)
Increase in inventories		(6,076	)		(1,810	)		(2,392	)
Decrease (increase) in prepaid expenses and other assets		(10,154	)		550			8,838
Decrease (increase) in other assets		(256	)		674			799
Increase in trade accounts payable		1,764			12,954			10,753
(Decrease) increase in accrued interest		3,568			(3,893	)		148
Increase in accrued expenses		2,943			8,555			3,801
Decrease in other liabilities		(60	)		(141	)		(466	)
(Decrease) increase in accrued salaries, benefits and payroll taxes		4,414			(1,679	)		1,945
Net cash provided by operating activities		17,981			3,007			21,507
Cash Flows from Investing Activities:
Decrease (increase) in restricted cash		357			(4,141	)		—
Purchases of investment interests		—			(1,177	)		—
Proceeds from sale of investments		—			—			368
Purchases of property and equipment		(25,572	)		(22,758	)		(30,989	)
Deposits on asset commitments		(46	)		82			(10,096	)
Proceeds from sale of property and equipment		1,880			1,009			2,616
Net cash used in investing activities		(23,381	)		(26,985	)		(38,101	)
Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt		—			—			4,000
Payments on long-term debt		(5,772	)		(7,819	)		(9,446	)
Net borrowings (repayments) on lines of credit		—			(36,500	)		—
Proceeds from parent		2,953			71,450
Payment of preferred stock dividend		—			(637	)		(1,274	)
Exercise of options and restricted stock awards, net of tax		—			(1,821	)		—
Debt issuance costs		—			—			(189	)
Net cash (used) provided by financing activities		(2,819	)		24,673			(6,909	)
Net increase (decrease) in cash and cash equivalents		(8,219	)		695			(23,503	)
Cash and cash equivalents at beginning of period		21,635			20,940			41,072
Cash and cash equivalents at end of period	$	13,416		$	21,635		$	17,569
Supplemental information:
Interest paid (net of capitalized interest)	$	9,259		$	10,991		$	20,467
Income taxes paid (refunds)	$	2,865		$	(580	)	$	57

(Unaudited)


	Successor			Predecessor
	Seven Months			Two Months			Nine Months
	Ended			Ended			Ended
	September 30,			February 28,			September 30,
	2011			2011			2010
Cash Flows from Operating Activities:
Net loss	$	(4,480	)	$	(19,297	)	$	(17,476	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization		63,874			15,837			65,366
Amortization of deferred issuance costs		—			366			1,661
Debt premium amortization		(1,900	)		—			—
Stock-based compensation		—			6,084			4,374
Impairment of intangible assets		5,100			—			—
Allowance for bad debts		75			195			43
Deferred income taxes		229			140			(12,016	)
Loss on investment		—			—			1,466
Equity in loss (income) of unconsolidated affiliates		(258	)		—			409
Loss on debt extinguishment		351			—			—
Loss on sale of property and equipment		509			416			150
Changes in operating assets and liabilities, net of acquisitions:
Increase in trade receivable		(14,345	)		(15,944	)		(30,361	)
Increase in inventories		(12,407	)		(1,810	)		(2,697	)
Decrease (increase) in prepaid expenses and other assets		(6,443	)		550			8,024
Decrease (increase) in other assets		(756	)		674			1,265
(Decrease) increase in trade accounts payable		(5,601	)		12,954			8,380
Decrease in accrued interest		(8,106	)		(3,893	)		(8,904	)
(Decrease) increase in accrued expenses		(3,493	)		8,555			5,488
Decrease in other liabilities		(89	)		(141	)		(690	)
(Decrease) increase in accrued salaries, benefits and payroll taxes		1,768			(1,679	)		2,401

Net cash provided by operating activities		14,028			3,007			26,883


Cash Flows from Investing Activities:
Decrease (increase) in restricted cash		4,141			(4,141	)		—
Purchases of investment interests		—			(1,177	)		—
Business acquisition, net of cash acquired		—			—			(18,237	)
Proceeds from sale of investments		—			—			368
Purchases of property and equipment		(48,125	)		(22,758	)		(50,893	)
Deposits on asset commitments		(225	)		82			(12,967	)
Proceeds from sale of property and equipment		4,106			1,009			5,284

Net cash used in investing activities		(40,103	)		(26,985	)		(76,445	)


Cash Flows from Financing Activities:
Proceeds from issuance of long-term debt		64			—			4,000
Payments on long-term debt		(135,305	)		(7,819	)		(14,588	)
Net borrowings (repayments) on lines of credit		130,000			(36,500	)		36,500
Proceeds from parent		19,872			71,450
Payment of preferred stock dividend		—			(637	)		(1,911	)
Exercise of options and restricted stock awards, net of tax		—			(1,821	)		—
Debt issuance costs		—			—			(189	)

Net cash provided by financing activities		14,631			24,673			23,812


Net increase (decrease) in cash and cash equivalents		(11,444	)		695			(25,750	)
Cash and cash equivalents at beginning of period		21,635			20,940			41,072

Cash and cash equivalents at end of period	$	10,191		$	21,635		$	15,322


Supplemental information:
Interest paid (net of capitalized interest)	$	28,263		$	10,991		$	40,680
Income taxes paid (refunds)	$	10,529		$	(580	)	$	667

The accompanying Notes are an integral part of the Consolidated Condensed Financial Statements.

ALLIS-CHALMERS ENERGY INC. ~~NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS~~

NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 1 — NATURE OF BUSINESS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Nature of Operations

Allis-Chalmers Energy Inc. and subsidiaries (“Allis-Chalmers”, “we”, “our” or “us”) is a multi-faceted oilfield service company that provides services and equipment to oil and natural gas exploration and production companies throughout the United States including Texas, Louisiana, Pennsylvania, Arkansas, West Virginia, Oklahoma, Colorado, offshore in the Gulf of Mexico, and internationally, primarily in Argentina, Brazil, Bolivia and Mexico. We operate in two sectors of the oil and natural gas service industry: Well Services and Drilling 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 and rates per day for equipment and tools that we rent to our customers. 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

On February 23, 2011, Allis-Chalmers Energy Inc., a Delaware corporation, completed its merger (the “Merger”) with and into Wellco Sub Company (“Wellco”), a Delaware corporation and wholly owned subsidiary of Seawell Limited (“Seawell”), with Wellco continuing as the surviving entity under the name Allis-Chalmers Energy Inc. The Merger was effected pursuant to the Agreement and Plan of Merger, dated as of August 10, 2010, by and among Allis-Chalmers, Seawell and Wellco, as amended by the Amendment Agreement, dated as of October 10, 2010, by and among Allis-Chalmers, Seawell and Wellco (as so amended, the “Merger Agreement”). Following the Merger, Seawell began operating under the name Archer Limited (“Archer” or “Parent”). As of the Merger date, our assets and liabilities have been adjusted to their fair values (see Note 2) based on the purchase price resulting in changes to depreciation, amortization and interest in the successor period; therefore, the financial information for the period subsequent to the Merger is not fully comparable. The financial statements and accompanying footnotes have been separated with a black line to present pre-merger activity as the “Predecessor” company and post-merger activity as the “Successor” company. “Predecessor” refers to the operations of Allis-Chalmers prior to the consummation of the Merger and “Successor” refers to the operations of Allis-Chalmers subsequent to the Merger. The Merger date for accounting purposes has been designated as March 1, 2011.

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 statement of the interim periods. These unaudited consolidated condensed financial statements should be read in conjunction with our restated audited consolidated financial statements included in Amendment No. 1 to our Annual Report on Form 10-K for the year ended December 31, 2010 filed with the SEC on September 1, 2011 (the “Form 10-K/A”). The results of operations for the interim periods are not necessarily indicative of the results of operations to be expected for the full year.

The preparation of financial statements in conformity with accounting principles generally accepted in the United States 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; stock-based compensation; 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 or as our operating environment changes.

ALLIS-CHALMERS ENERGY INC. ~~NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS~~

NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 1 — NATURE OF BUSINESS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Continued)

Financial Instruments

Financial instruments consist of cash and cash equivalents, ~~restricted cash,~~ accounts receivable and payable, and debt. The carrying value of cash and cash equivalents, ~~restricted cash~~ and accounts receivable and payable approximate fair value due to their short-term nature. ~~Restricted cash relates to deposits at a financial institution to secure $3.8 million of outstanding letters of credit.~~ We believe the fair values and the carrying value of our debt, excluding the senior notes, would not be materially different due to the instruments’ interest rates approximating market rates for similar borrowings at ~~June~~September 30, 2011. Our senior notes, in the approximate aggregate amount of $~~446~~318.63 million, trade “over the counter” in limited amounts and on an infrequent basis. In connection with the Merger, the recorded fair value of our senior notes was increased by $19.3 million based on the traded value at Merger date. The price at which our senior notes trade is based on many factors such as the level of interest rates, the economic environment, the outlook for the oilfield services industry and the perceived credit risk.

Recent Accounting Pronouncements

We consider all newly issued but not yet adopted accounting pronouncements applicable to our operations and the preparation of our consolidated condensed financial statements. We do not believe that any issued accounting pronouncements not yet adopted by us will have a material impact on our consolidated condensed financial statements.

NOTE 2 — BUSINESS COMBINATIONS

Merger with Archer

Pursuant to the Merger, each outstanding share of common stock of Allis-Chalmers was converted into the right to receive either $4.25 cash or 1.15 fully paid and nonassessable Archer common shares. The fair value of total consideration was approximately $600.9 million with approximately 95% of Allis-Chalmers stockholders electing to receive 97.1 million Archer common shares in the Merger and the remainder receiving an aggregate of approximately $18 million in cash. The following table summarizes the preliminary allocation of the purchase price to the estimated fair value of the assets at Merger (in thousands):


Current assets	$	237,873
Property and equipment		682,406
Intangible assets, including goodwill		373,227
Other long-term assets		4,949

Total assets acquired		1,298,455
Current liabilities		148,360
Long-term liabilities		549,210

Merger net assets	$	600,885

Our historical property and equipment values were decreased by $47.1 million, our ~~Senior~~senior ~~Notes~~notes were increased by $19.3 million, other assets were decreased by $13.8 million and other long-term liabilities were increased by $8.6 million. The fair value assigned to the debt was based on actively traded prices and changes in other assets and liabilities were based on third-party valuations or other market based approaches. Goodwill of $267.4 million was recognized for this acquisition and was calculated as the excess of the consideration transferred over the fair value of the net assets acquired. It includes the expected synergies and other benefits that we believe will result from the combined operations and intangible assets that do not qualify for separate recognition such as assembled workforce. Other intangible assets included approximately $91.2 million assigned to customer lists, $6.7 million to trade name, $5.6 million to patents and $2.3 million to backlogs (see note 4). Goodwill is not tax deductible. The amortizable intangibles have a weighted-average useful life of 8.9 years. The allocation of the purchase price has been based upon preliminary fair values. Estimates and assumptions are subject to change upon management’s review of the final valuation.

ALLIS-CHALMERS ENERGY INC. ~~NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS~~

NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 2 — BUSINESS COMBINATIONS (Continued)

Acquisition of AWC

On July 12, 2010, we acquired AWC Frac Valves Inc. (formerly known as American Well Control, Inc.), which orwe refer to herein as AWC, for a total consideration of approximately $19.2 million, which included approximately $17.2 million in cash and 1.0 million shares of our common stock. AWC is a leading manufacturer of premium high-pressure valves used in hydraulic fracturing in the unconventional gas shale plays. 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):


Current assets	$	7,585
Property and equipment		2,756
Intangible assets, including goodwill		11,749
Other long-term assets		2

Total assets acquired		22,092
Current liabilities		1,527
Long-term liabilities		1,401

Net assets acquired	$	19,164

AWC’s historical property and equipment values were increased by approximately $27,000 based on third-party valuations. Goodwill of $5.7 million was recognized for this acquisition and was calculated as the excess of the consideration transferred over the fair value of the net assets acquired. It includes the expected synergies and other benefits that we believe will result from the combined operations and intangible assets that do not qualify for separate recognition such as assembled workforce. Other intangible assets included approximately $5.6 million assigned to customer lists, $400,000 to trade name and $55,000 to non-competes. Goodwill is not tax deductible. The amortizable intangibles have a weighted-average useful life of 9.9 years.

NOTE 3 — STOCK-BASED COMPENSATION

Under the Merger Agreement, holders of our outstanding stock options, whether or not then exercisable or vested, ~~elected~~had the option to elect to receive, at the effective time of the Merger, either cash or fully exercisable and vested stock options to purchase Archer common shares. In addition, all restrictions on time-lapse and performance-based restricted stock awards were deemed to have lapsed and each restricted share was deemed to be an unrestricted share of our common stock. Our Incentive Stock Plans were terminated in connection with the Merger. Our net loss for the two months ended February 28, 2011 includes approximately $6.1 million of compensation costs related to share-based payments with approximately $5.4 million of this amount relating to the acceleration of stock based compensation expense associated with the Merger.

We recognize all share-based payments to employees and directors in the financial statements based on their grant-date fair values. We utilize the Black-Scholes model to determine fair value, which incorporates assumptions to value stock-based awards. 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. The risk-free interest rate is the related United States Treasury yield curve for periods within the expected term of the option at the time of grant. We estimate forfeiture rates based on our historical experience.

The following summarizes the Black-Scholes model assumptions used for the options granted in the ~~three~~nine ~~and six~~ months ended ~~June~~September 30, 2010 (no options were granted during the three and ~~six~~nine months ended ~~June~~September 30, 2011 and the three months ended September 30, 2010):

	Three Months			Six Months
	Nine Months
	Ended			~~Ended~~
	June 30,			June 30,
	September 30,
	2010			~~2010~~
Expected dividend yield		—			—
Expected price volatility		8889.5481	%		~~89.81~~	%
Risk free interest rate		1.5141	%		~~1.41~~	%
Expected life of options	5 years			~~5 years~~
Weighted average fair value of options granted at market value	$	2.7063		$	~~2.63~~

ALLIS-CHALMERS ENERGY INC. ~~NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS~~

NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 3 — STOCK-BASED COMPENSATION (Continued)

A summary of our stock option activity and related information is as follows:

				Weighted
	Shares			Average
	Under			Exercise
	Option			Price
Balance at December 31, 2010		1,751,018		$	4.74
Granted		—			—
Converted at Merger		(1,750,018	)		4.74
Exercised		(1,000	)		1.23
Outstanding at June 30, 2011		—			—
Outstanding at September 30, 2011		—			—

Restricted stock awards, or RSAs, activity during the ~~three~~nine months ended ~~June~~September 30, 2011 is as follows:

				Weighted
				Average Grant-
				Date Fair Value
	Number of Shares			Per Share
Nonvested at December 31, 2010		1,702,067		$	6.09
Granted		—			—
Vested		(1,702,067	)		6.09
Forfeited		—			—
Nonvested at June 30, 2011		—		$	—
Nonvested at September 30, 2011		—		$	—

NOTE 4 — GOODWILL AND INTANGIBLE ASSETS

Goodwill 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 asset’s estimated useful life or on a basis that reflects the pattern in which the economic benefits of the intangible assets are realized. Goodwill was $267.4 million and $46.3 million at ~~June~~September 30, 2011 and December 31, 2010, respectively.

Definite-lived intangible assets that continue to be amortized relate to our purchase of customer-related and marketing-related intangibles patents and backlogs. These intangibles have useful lives ranging from four months to twenty years. Amortization of intangible assets for the three and ~~four~~seven months ended ~~June~~September 30, 2011 and two months ended February 28, 2011 was $42.4 9 million, $5.8.7 million and $811,000, respectively, compared to $1.23 million and $2.3.6 million for the ~~three~~ three and ~~six~~nine months ended ~~June~~September 30, 2010, respectively. In connection with the Merger, a $5.1 million value was assigned to the Allis-Chalmers tradename. Following the Merger, Seawell and ~~its~~ its subsidiaries, including us, have begun operating under the name Archer. As a result, it was determined that there was no material remaining value associated with the Allis-Chalmers tradename and the results for the ~~four~~seven months ended ~~June~~September 30, 2011 includes an intangible asset ~~impairment~~ impairment charge of $5.1 million. At ~~June~~September 30, 2011, intangible assets totaled $9492.90 million, net of $5.8 .7 million of accumulated amortization. Future amortization of intangible assets at ~~June~~ September 30, 2011 is approximately $52.9 million for the remainder of 2011 and an average of approximately $11.6 million during the years ended 2012 through 2015.

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 5 — INVENTORIES

Inventories consisted of the following (in thousands):

	Successor		~~Predecessor~~	Predecessor
	June 30,		December 31,
	September 30,			December 31,
	2011		~~2010~~	2010
Manufactured
Finished goods	$	5,~~319~~086	$	~~4,238~~$	4,238
Work in process		34,~~849~~358		~~2,990~~	2,990
Raw materials		5,~~138~~667		~~3,600~~	3,600
Total manufactured		1415,~~306~~111		~~10,828~~	10,828
Rig parts and related inventory		1316,~~582~~391		~~11,565~~	11,565
Shop supplies and related inventory		1012,~~486~~030		~~9,620~~	9,620
Chemicals and drilling fluids		56,~~621~~267		~~4,814~~	4,814
Rental supplies		1,~~593~~427		~~1,761~~	1,761
Hammers		23,~~604~~101		~~2,380~~	2,380
Coiled tubing and related inventory		1,~~725~~921		~~1,046~~	1,046
Drive pipe		109		~~126~~	126
Total inventories	$	5056,~~026~~357	$	~~42,140~~$	42,140

NOTE 6- — INCOME TAXES

In accordance with generally accepted accounting principles, we estimate the full-year effective tax rate from continuing operations and apply this rate to our year-to-date income from continuing operations. In addition, we separately calculate the tax impact of unusual items, if any. The consolidated effective tax rate for the two months ended February 28, 2011, three and ~~four~~seven months ended ~~June~~September 30, 2011 was (9.9)%, 63210.69% and ~~246~~229.06%, respectively, compared to 23(169.45)% and 25 16.89% for the three and ~~six~~nine months ended ~~June~~September 30, 2010. The fluctuations in the tax rates are principally the result of valuation allowances on losses generated in the United States and variances in withholding taxes from foreign operations as a percentage of pretax income (loss).

Income (loss) before income taxes which was subject to United States and non-United States income taxes was as follow (in thousands):

	Successor					~~Predecessor~~	Predecessor
	Three Months			Four Months		Two Months				Three Months				Six Months
	Three Months Ended			Seven Months Ended			Two Months Ended				Three Months Ended				Nine Months Ended
	Ended			Ended		Ended				Ended				Ended
	September 30,			September 30,			February 28,				September 30,				September 30,
	June 30,			June 30,		February 28,				June 30,				June 30,
	2011			2011			2011				2010				2010
	2011			2011		2011				2010				2010
United States	$	(732	)	$	386		$	(17,544	)		$	(4,666	)		$	(36,059	)
United States	$	4,422		$	1,118	$	(17,544	)		$	(13,414	)		$	(31,393	)
Outside United States		2,344			3,070			(17	)			3,714				15,020
Outside United States		222			726		(17	)			6,395				11,306
	$	1,612		$	3,456		$	(17,561	)		$	( 952	)		$	(21,039	)
	$	4,644		$	1,844	$	(17,561	)		$	( 7,019	)		$	( 20,087	)

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 6- — INCOME TAXES (Continued)

The income tax provision consists of the following (in thousands):

	Successor						~~Predecessor~~	Predecessor
	Three Months			Four Months			Two Months				Three Months				Six Months
	Three Months Ended			Seven Months Ended				Two Months Ended				Three Months Ended				Nine Months Ended
	Ended			Ended			Ended				Ended				Ended
	September 30,			September 30,				February 28,				September 30,				September 30,
	June 30,			June 30,			February 28,				June 30,				June 30,
	2011			2011				2011				2010				2010
	2011			2011			2011				2010				2010
Income tax expense (benefit):
Income tax expense (benefit):
United States	$	184		$	424			$	233			$	(810	)		$	(11,323	)
United States	$	183		$	240		$	233			$	(4,408	)		$	(10,513	)
Outside United States		3,216			7,512				1,503				2,424				7,760
Outside United States		2,772			4,296			1,503				2,768				5,336
	$	3,400		$	7,936			$	1,736			$	1,614			$	(3,563	)
	$	2,955		$	4,536		$	1,736			$	(1,640	)		$	(5,177	)
The following table reconciles the statutory tax rates to our actual tax rate:
	Successor							Predecessor
	Three Months Ended			Seven Months Ended				Two Months Ended				Three Months Ended				Nine Months Ended
	September 30,			September 30,				February 28,				September 30,				September 30,
	2011			2011				2011				2010				2010
United States statutory federal income tax rate		35.0	%		35.0	%			35.0	%			35.0	%			35.0	%
United States State income taxes, net of federal benefit		1.2			1.2				0.7				2.2				2.2
Non-United States income taxed at different rates		19.2			31.8				0.3				64.5				10.4
Valuation allowance, permanent differences and other		155.5			161.6				(45.9	)			(271.2	)			(30.7	)
Effective tax rate		210.9	%		229.6	%			(9.9	)%			(169.5	)%			16.9	%

~~The~~NOTE ~~following~~7 ~~table~~— ~~reconciles the statutory tax rates to our actual tax rate:~~DEBT

	Successor						Predecessor
	Three Months			Four Months			Two Months			Three Months			Six Months
	Ended			Ended			Ended			Ended			Ended
	June 30,			June 30,			February 28,			June 30,			June 30,
	2011			2011			2011			2010			2010
United States Statutory federal income tax rate		35.0	%		35.0	%		35.0	%		35.0	%		35.0	%
United States State income taxes, net of federal benefit		1.2			1.2			0.7			2.2			2.2
Non-United States income taxed at different rates		10.9			42.7			0.3			12.5			7.8
Valuation allowance, permanent differences and other		16.5			167.1			(45.9	)		(26.3	)		(19.2	)
Effective tax rate		63.6	%		246.0	%		(9.9	)%		23.4	%		25.8	%

NOTE 7- DEBT

Our long-term debt consisted of the following (in thousands):

	Successor		~~Predecessor~~	Predecessor
	June 30,		December 31,
	September 30,			December 31,
	2011		~~2010~~	2010
Senior notes	$	~~446~~318,~~647~~331	$	~~430,238~~$	430,238
Revolving line of credit		—130,000		~~36,500~~	36,500
Bank term loans		1413,~~934~~216		~~25,723~~	25,723
Insurance premium financing notes		—		979
Other debt		61			979
Total debt		461,~~581~~608		~~493,440~~	493,440
Less: current maturities of long-term debt		6,~~892~~915		~~15,215~~	15,215
Long-term debt	$	454,~~689~~693	$	~~478,225~~$	478,225

Senior notes, bank loans and line of credit agreements

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 7 — DEBT (Continued)

control provisions in the indentures governing the senior notes and as a result of the Merger, holders had the right to require us to purchase, all or a portion of such holders’ Notes. We Accordingly we purchased $1.8 million aggregate principal of our 9.0% senior notes for a total consideration of $1,010 per $1,000 principal amount. In July 2011, pursuant to the terms of the senior notes indenture, we redeemed $125.0 million aggregate principal of our 9.0% senior notes for a total consideration of $1,023 per $1,000 principal amount. In connection with this redemption we have drawn $130.0 million on our Parent’s $1.2 billion Multicurrency Term and Revolving Facility. The $1.2 billion facility is divided into tranches with $350.0 million having a final maturity date of December 31, 2011 and the remainder having a final maturity date of November 11, 2015. The interest rate is based on LIBOR plus a margin.

In January 2007, we closed on a private offering, to qualified institutional buyers pursuant to Rule 144A under the Securities Act of 1933, of $250.0 million principal amount of 8.5% senior notes due 2017. The proceeds of the senior notes offering, together with a portion of the proceeds of our concurrent common stock offering, were used to repay the debt outstanding under our $300.0 million bridge loan facility which we incurred to finance our acquisition of substantially all the assets of Oil & Gas Rental Services, Inc. On June 29, 2009, we closed on a tender offer in which we purchased $44.2 million aggregate principal of our 8.5% senior notes for a total consideration of $600 per $1,000 principal amount. In connection with the Merger and based on actively traded prices of our senior notes, we increased the fair value of the 8.5% senior notes to $1,070 per $1,000 principal amount. In May 2011, pursuant to the terms of change of control provisions in the indentures governing the senior notes and as a result of the Merger, we purchased $92,000 aggregate principal of our 8.5% senior notes for a total consideration of $1,010 per $1,000 principal amount.

We had a $90.0 million revolving line of credit with a final maturity date of April 26, 2012 pursuant to a revolving credit agreement that contained customary events of default and financial covenants and limited our ability to incur additional indebtedness, make capital expenditures, pay dividends or make other distributions, create liens and sell assets. Effective December 31, 2009, we amended the leverage and interest coverage ratio covenants of the revolving credit agreement. This amendment relaxed the required financial ratios for the quarter ended December 31, 2009 and for each of the quarters in 2010. Our obligations under the amended and restated credit agreement are secured by substantially all of our assets located in the United States. We were in compliance with all debt covenants as of December 31, 2010. As of December 31, 2010, we had $36.5 million of borrowings outstanding and $4.1 million in outstanding letters of credit under our revolving credit facility. The weighted-average interest rate was 7.8% at December 31, 2010. The revolving line of credit was repaid and terminated in connection with the Merger.

As part of our acquisition of DLS, we assumed various bank loans with floating interest rates based on LIBOR plus a margin and terms ranging from 2 to 5 years. The weighted average interest rate on these loans was 2.0% as of December 31, 2010. The outstanding amount due under these bank loans as of ~~June~~September 30, 2011 and December 31, 2010 was $0 and $350,000, respectively.

On February 15, 2008, through our DLS subsidiary in Argentina, we entered into a $25.0 million import finance facility with a bank. Borrowings under this facility were used to fund a portion of the purchase price of the new drilling and service rigs ordered for our Drilling Services segment. The loan is repayable over four years in equal semi-annual installments beginning one year after each disbursement with the final principal payment due not later than March 15, 2013. The import finance facility is unsecured and contains customary events of default and financial covenants and limits DLS’ ability to incur additional indebtedness, make capital expenditures, create liens and sell assets. We were in compliance with all debt covenants as of ~~June~~September 30, 2011 and December 31, 2010. The bank loan rates are based on LIBOR plus a margin. The weighted average interest ~~rate~~ rate was 45.2% at ~~June~~September 30, 2011 and 4.2% at December 31, 2010. The outstanding amount under the import finance facility as of ~~June~~September 30, 2011 and December 31, 2010 was $119.58 million and $14.4 million, respectively.

As part of our acquisition of BCH, we assumed a $23.6 million term loan credit facility with a bank. The credit agreement was dated June 2007 and contained customary events of default and financial covenants which were based on BCH’s stand-alone financial statements. The facility was repayable in quarterly principal installments plus interest and was to mature in August 2012. Obligations under the facility were secured by substantially all of the BCH assets. The bank waived certain financial ratio covenants for the December 31, 2010 measurement period and we classified the entire outstanding balance of the loan in the current portion of long-term debt. The interest rates were based on LIBOR plus a margin and the interest rate was 3.5% at December 31, 2010. The outstanding amount of the loan as of December 31, 2010 was $7.0 million. The term loan credit facility was paid in full in connection with the Merger.

On February 9, 2010, through our DLS subsidiary, we entered into a $4.0 million term loan facility. The loan is repayable in semi-annual installments beginning April 14, 2011 and bears interest at 8.5% per annum. The final maturity date is April 14, 2014 and the loan is unsecured. The outstanding amount under the term loan facility as of June 30, 2011 and December 31, 2010 was $3.4 million and $4.0 million, respectively

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 7 — DEBT (Continued)

~~Notes~~On ~~payable~~February 9, 2010, through our DLS subsidiary, we entered into a $4.0 million term loan facility. The loan is repayable in semi-annual installments beginning April 14, 2011 and bears interest at 8.5% per annum. The final maturity date is April 14, 2014 and the loan is unsecured. The outstanding amount under the term loan facility as of September 30, 2011 and December 31, 2010 was $3.4 million and $4.0 million, respectively.

InOther ~~2010, we obtained insurance premium financings in the aggregate amount of $2.9 million with a~~Debt fixed weighted-average interest rate of 4.8%. Under terms of the agreements, amounts outstanding are paid over eight and 11 month repayment schedules. The outstanding balance of these notes was approximately $0 and $1.0 million at June 30, 2011 and December 31, 2010, respectively.

In 2010, we obtained insurance premium financings in the aggregate amount of $2.9 million with a fixed weighted-average interest rate of 4.8%. Under terms of the agreements, amounts outstanding are paid over eight and 11 month repayment schedules. The outstanding balance of these notes was approximately $0 and $1.0 million at September 30, 2011 and December 31, 2010, respectively. We also have amounts outstanding under a capital lease that will expire in 2013. As of September 30, 2011, the amount outstanding under the capital lease was $61,000.

NOTE 8 — STOCKHOLDERS’ EQUITY

During the two months ended February 28, 2011, we had option exercises and certain vesting in restricted stock grants which resulted in the issuance of 933,083 shares of our common stock. We retained 282,356 shares from employees in connection with the settlement of tax obligations arising from the vesting of restricted stock grants. We recognized approximately $6.1 million of compensation expense related to share-based payments during the two months ended February 28, 2011 that was recorded as capital in excess of par value (see Note 3).

Pursuant to the Merger, each share of our convertible preferred stock was converted to common stock and each outstanding share of common stock of Allis-Chalmers was converted into the right to receive either $4.25 cash or 1.15 fully paid and nonassessable Archer common shares. Holders of our outstanding stock options, whether or not then exercisable or vested, elected to receive, at the effective time of the ~~merger~~Merger, either cash or fully exercisable and vested stock options to purchase Archer common shares. In addition, all restrictions on time-lapse and performance-based restricted stock awards were deemed to have lapsed and each restricted share was deemed to be an unrestricted share of our common stock. Subsequent to the Merger, we have 1,000 shares authorized all of which have been issued to Archer Limited at a par value of $0.01 per share.

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION

Set forth on the following pages are the condensed consolidating financial statements of (i) Allis-Chalmers Energy Inc., (ii) its subsidiaries that are guarantors of the senior notes and ~~revolving~~ ~~credit facility and~~ (iii) the subsidiaries that are not guarantors of the senior notes ~~and~~ ~~revolving credit facility~~ (in thousands):

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING BALANCE SHEETS ~~June~~September 30, 2011 (Successor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary		Subsidiary			Consolidating			Consolidated
	(Guarantor)			Guarantors		Non-Guarantors			Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	96,~~286~~810	$	43,~~130~~381		$	—		$	1310,~~416~~191
Restricted cash		—			3,784		—			—			3,784
Trade receivables, net		—			105,720		100,358			(32,336	)		173,742
Trade receivables, net		—			102,949		103,193			(31,762	)		174,380
Inventories		—			29,662		26,695			—			56,357
Inventories		—			26,981		23,045			—			50,026
Intercompany receivables		—			105,122		—			(105,122	)		—
Intercompany receivables		—			87,640		—			(87,640	)		—
Note receivable from affiliate		18,862			—		—			(18,862	)		—
Note receivable from affiliate		21,085			—		—			(21,085	)		—
Prepaid expenses and other		12			5,306		9,701			—			15,019
Prepaid expenses and other		12			5,638		14,188			—			19,838
Total current assets		18,874			252,620		140,135			(156,320	)		255,309
Total current assets		21,097			236,278		144,556			(140,487	)		261,444
Property and equipment, net		—			396,804		273,981			—			670,785
Property and equipment, net		—			406,223		269,358			—			675,581
Goodwill		—			179,697		87,731			—			267,428
Other intangible assets, net		—			5755,~~540~~948		3736,~~350~~009			—			9491,~~890~~957
Note receivable from affiliates		1,500			—		—			(1,500	)		—
Investments in affiliates		1,~~170~~177,~~166~~161			—		—			(1,~~170~~177,~~166~~161	)		—
Other assets		—			45,~~869~~328		~~382~~860			—			56,~~251~~188
Total assets	$	1,~~192~~197,~~763~~535		$	~~884~~890,~~607~~397	$	~~539~~538,~~377~~716		$	(1,~~312~~334,~~153~~981	)	$	1,~~304~~291,~~594~~667
Liabilities and Stockholders’ Equity
Current maturities of long-term debt	$	—		$	—	$	6,~~892~~915		$	—		$	6,~~892~~915
Trade accounts payable		—			2120,~~814~~991		7064,~~708~~740			(3132,~~762~~336	)		6053,~~760~~395
Accrued salaries, benefits and payroll taxes		—			5,~~465~~548		3027,~~060~~331			—			3532,~~525~~879
Accrued interest		153,~~020~~296			—		~~179~~229			—			153,~~199~~525
Accrued expenses		~~570~~265			1615,~~882~~720		2419,~~460~~491			—			4135,~~912~~476
Intercompany payables		57,~~930~~916			—		2947,~~710~~206			(87105,~~640~~122	)		—
Note payable to affiliate		—			—		2118,~~085~~862			(2118,~~085~~862	)		—
Total current liabilities		7361,~~520~~477			4442,~~161~~259		~~183~~184,~~094~~774			(~~140~~156,~~487~~320	)		~~160~~132,~~288~~190
Long-term debt, net of current maturities		~~446~~448,~~647~~331			—		86,~~042~~362			—			454,~~689~~693
Note payable to affiliate		—			—		1,500			(1,500	)		—
Payable to parent		7491,~~403~~322			—		—			—			7491,~~403~~322
Other long-term liabilities		—			—		17,~~021~~057			—			17,~~021~~057
Total liabilities		~~594~~601,~~570~~130			4442,~~161~~259		209,~~657~~693			(~~141~~157,~~987~~820	)		~~706~~695,~~401~~262
Commitments and Contingencies
Stockholders’ Equity
Common stock		—			3,527		42,963			(46,490	)		—
Capital in excess of par value		600,885			823,395		290,090			(1,113,485	)		600,885
Retained earnings (deficit)		(24,~~692~~480	)		1321,~~524~~216		(34,~~333~~030	)		(1017,~~191~~186	)		(24,~~692~~480	)
Total stockholders’ equity		~~598~~596,~~193~~405			~~840~~848,~~446~~138		329,~~720~~023			(1,~~170~~177,~~166~~161	)		~~598~~596,~~193~~405
Total liabilities and stockholders’ equity	$	1,~~192~~197,~~763~~535		$	~~884~~890,~~607~~397	$	~~539~~538,~~377~~716		$	(1,~~312~~334,~~153~~981	)	$	1,~~304~~291,~~594~~667

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS For the Three Months Ended ~~June~~September 30, 2011 (Successor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Subsidiary			Consolidating			Consolidated
	(Guarantor)			Guarantors			Non-Guarantors			Adjustments			Total
Revenues	$	—		$	9695,~~934~~677		$	~~123~~126,~~446~~794		$	(~~242~~63	)	$	~~220~~222,~~138~~408
Operating costs and expenses:
Direct costs		—			5758,~~986~~215			~~104~~106,~~884~~577			(~~242~~63	)		~~162~~164,~~628~~729
Depreciation `		—			1517,~~843~~370			7,~~187~~415			—			2324,~~030~~785
Selling, general and administrative		6567			710,~~995~~861			7,~~326~~672			—			1518,~~386~~600
Amortization		—			1,~~592~~591			21,~~765~~342			—			42,~~357~~933
Total operating costs and expenses		6567			8388,~~416~~037			~~122~~123,~~162~~006			(~~242~~63	)		~~205~~211,~~401~~047
Income (loss) from operations		(6567	)		137,~~518~~640			13,~~284~~788			—			1411,~~737~~361
Other income (expense):
Equity earnings in affiliates, net of tax		116,~~067~~995			—			—			(116,~~067~~995	)		—
Interest, net		(98,~~326~~379	)		(1	)		(~~732~~938	)		—			(109,~~059~~318	)
Other		13(337	)		~~107~~237			(~~154~~331	)		—			(34431	)
Total other expense		1,754			106			(886	)		(11,067	)		(10,093	)
Total other income (expense)		(1,721	)		236			(1,269	)		(6,995	)		(9,749	)
Net income (loss) before income taxes		(1,~~689~~788	)		137,~~624~~876			~~398~~2,519			(116,~~067~~995	)		41,~~644~~612
Provision for income taxes		—			(~~183~~184	)		(23,~~772~~216	)		—			(23,~~955~~400	)
Net income (loss)	$	(1,~~689~~788	)	$	137,~~441~~692		$	(~~2,374~~697	)	$	(116,~~067~~995	)	$	(1,~~689~~788	)

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS For the ~~Four~~Seven Months Ended ~~June~~September 30, 2011 (Successor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Subsidiary			Consolidating			Consolidated
	(Guarantor)			Guarantors			Non-Guarantors			Adjustments			Total
Revenues	$	—		$	~~130~~226,~~882~~559		$	~~160~~287,~~271~~065		$	(~~289~~352	)	$	~~290~~513,~~864~~272
Operating costs and expenses:
Direct costs		—			78137,~~879~~094			~~135~~241,~~174~~751			(~~289~~352	)		~~213~~378,~~764~~493
Depreciation		—			20,797			9,549			—			30,346
Depreciation `		—			38,167			16,964			—			55,131
Selling, general and administrative		~~100~~167			1021,~~997~~858			916,~~080~~752			—			2038,~~177~~777
Impairment of intangible assets		—			4,400			700			—			5,100
Amortization		—			23,~~123~~714			35,~~687~~029			—			58,~~810~~743
Total operating costs and expenses		~~100~~167			~~117~~205,~~196~~233			~~158~~281,~~190~~196			(~~289~~352	)		~~275~~486,~~197~~244
Income (loss) from operations		(~~100~~167	)		1321,~~686~~326			25,~~081~~869			—			1527,~~667~~028
Other income (expense):
Equity earnings in affiliates, net of tax		1017,~~191~~186			—			—			(1017,~~191~~186	)		—
Interest, net		(1221,~~801~~180	)		(23	)		(~~999~~1,937	)		—			(1323,~~802~~120	)
Other		18(319	)		80317			(~~119~~450	)		—			(21452	)
Total other expense		(2,592	)		78			(1,118	)		(10,191	)		(13,823	)
Total other income (expense)		(4,313	)		314			(2,387	)		(17,186	)		(23,572	)
Net income (loss) before income taxes		(24,~~692~~480	)		1321,~~764~~640			~~963~~3,482			(1017,~~191~~186	)		13,~~844~~456
Provision for income taxes		—			(~~240~~424	)		(47,~~296~~512	)		—			(47,~~536~~936	)
Net income (loss) attributed to common stockholders	$	(2,692	)	$	13,524		$	(3,333	)	$	(10,191	)	$	(2,692	)
Net income (loss)	$	(4,480	)	$	21,216		$	(4,030	)	$	(17,186	)	$	(4,480	)

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS For the Two Months Ended February 28, 2011 (Predecessor) (~~unaudited~~Unaudited)


	Allis-Chalmers			Subsidiary			Subsidiary			Consolidating			Consolidated
	(Guarantor)			Guarantors			Non-Guarantors			Adjustments			Total
Revenues	$	—		$	59,044		$	67,923		$	(82	)	$	126,885

Operating costs and expenses:
Direct costs		—			37,335			59,877			(82	)		97,130
Depreciation		—			10,174			4,852			—			15,026
Selling, general and administrative		5,998			15,034			2,720			—			23,752
Amortization		8			678			125			—			811

Total operating costs and expenses		6,006			63,221			67,574			(82	)		136,719

Income (loss) from operations		(6,006	)		(4,177	)		349			—			(9,834	)

Other income (expense):
Equity earnings in affiliates, net of tax		(6,057	)		—			—			6,057			—
Interest, net		(7,253	)		(8	)		(588	)		—			(7,849	)
Other		19			(232	)		335			—			122

Total other expense		(13,291	)		(240	)		(253	)		6,057			(7,727	)


Net income (loss) before income taxes		(19,297	)		(4,417	)		96			6,057			(17,561	)

Provision for income taxes		—			(233	)		(1,503	)		—			(1,736	)


Net loss		(19,297	)		(4,650	)		(1,407	)		6,057			(19,297	)

Preferred stock dividend		(375	)		—			—			—			(375	)


Net loss attributed to common stockholders	$	(19,672	)	$	(4,650	)	$	(1,407	)	$	6,057		$	(19,672	)

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOW For the ~~Four~~Seven Months Ended ~~June~~September 30, 2011 (Successor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Subsidiary			Consolidating			Consolidated
	(Guarantor)			Guarantors			Non-Guarantors			Adjustments			Total
Cash Flows from Operating Activities:
Net income (loss)	$	(24,~~692~~480	)	$	1321,~~524~~216		$	(34,~~333~~030	)	$	(1017,~~191~~186	)	$	(24,~~692~~480	)
Adjustments to reconcile net income (loss) to net cash (used) provided by operating activities:
Depreciation and amortization		—			2241,~~920~~881			1321,~~236~~993			—			3663,~~156~~874
Debt premium amortization		(1,~~050~~900	)		—			—			—			(1,~~050~~900	)
Equity earnings in affiliates		(1017,~~191~~186	)		—			—			1017,~~191~~186			—
Impairment of intangible assets		—			4,400			700			—			5,100
Deferred income taxes		—			1			(940	)		—			(939	)
Allowance for bad debts		—			75			—			—			75
Loss on sale of equipment		—			94			77			—			171
Deferred income taxes		—			—			229			—			229
Loss on debt extinguishment		351			—			—			—			351
Loss on sale of equipment		—			469			40			—			509
Equity in income of unconsolidated affiliates		—			(258	)		—			—			(258	)
Changes in operating assets and liabilities, net of acquisitions:
Increase in trade receivables		—			(13,~~342~~614	)		(1310,~~566~~731	)		—			(14,~~908~~345	)
Increase in inventories		—			(36,~~481~~162	)		(26,~~595~~245	)		—			(612,~~076~~407	)
Increase in prepaid expenses and other current assets		(16	)		(2,~~655~~322	)		(74,~~498~~115	)		—			(106,~~154~~443	)
Decrease (increase) in other assets		—			(322	)		66			—			(256	)
Increase in other assets		—			(523	)		(233	)		—			(756	)
(Decrease) increase in trade accounts payable		—			(56,~~455~~650	)		71,~~219~~049			—			1(5,~~764~~601	)
(Decrease) increase in accrued interest		3,741			—			(173	)		—			3,568
Decrease in accrued interest		(7,983	)		—			(123	)		—			(8,106	)
(Decrease) increase in accrued expenses		(345	)		(485	)		3,773			—			2,943
Decrease in accrued expenses		(650	)		(1,647	)		(1,196	)		—			(3,493	)
(Decrease) increase in accrued salaries, benefits and payroll taxes		—			(3,~~501~~418	)		75,~~915~~186			—			41,~~414~~768
Decrease in other long- term liabilities		—			—			(6089	)		—			(6089	)
Net cash (used) provided by operating activities		(1031,~~538~~854	)		2343,~~698~~447			42,~~821~~435			—			1714,~~981~~028
Cash Flows from Investing Activities:
Notes receivable from affiliates		(~~2,312~~89	)		—			—			~~2,312~~89			—
Decrease in restricted cash		—			~~357~~4,141			—			—			~~357~~4,141
Deposits on asset commitments		—			—			(46225	)		—			(46225	)
Proceeds from sale of property and equipment		—			13,~~827~~319			53787			—			14,~~880~~106
Purchases of property and equipment		—			(1727,~~479~~498	)		(820,~~093~~627	)		—			(2548,~~572~~125	)
Net cash used in investing activities		(~~2,312~~89	)		(1520,~~295~~038	)		(820,~~086~~065	)		~~2,312~~89			(2340,~~381~~103	)

ALLIS-CHALMERS ENERGY INC. ~~NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS~~

NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOW For the ~~Four~~Seven Months Ended ~~June~~September 30, 2011 (Successor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Subsidiary			Consolidating			Consolidated
	(Guarantor)			Guarantors			Non-Guarantors			Adjustments			Total
Cash Flows from Financing Activities:
Accounts receivable from affiliates		—			(1533,~~631~~113	)		—			1533,~~631~~113			—
Accounts payable to affiliates		11,~~782~~768			—			321,~~849~~345			(1533,~~631~~113	)		—
Note payable to affiliate		—			—			~~2,312~~89			(~~2,312~~89	)		—
Payments on long-term debt		(1,885	)		(350	)		(3,537	)		—			(5,772	)
Proceeds from issuance of long-term debt		—			—			64			—			64
Proceeds from Parent		2,953			—			—			—			2,953
Borrowings on lines of credit		130,000			—			—			—			130,000
Net cash (used) provided by financing activities		12,850			(15,981	)		2,624			(2,312	)		(2,819	)
Payments on long-term debt		(129,697	)		(350	)		(5,258	)		—			(135,305	)
Net change in cash and cash equivalents		—			(7,578	)		(641	)		—			(8,219	)
Proceeds from Parent		19,872			—			—			—			19,872
Net cash (used) provided by financing activities		31,943			(33,463	)		16,240			(89	)		14,631
Net change in cash and cash equivalents		—			(10,054	)		(1,390	)		—			(11,444	)
Cash and cash equivalents at beginning of year		—			16,864			4,771			—			21,635
Cash and cash equivalents at end of period	$	—		$	96,~~286~~810		$	43,~~130~~381		$	—		$	1310,~~416~~191

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOW For the Two Months Ended February 28, 2011 (Predecessor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Subsidiary			Consolidating			Consolidated
	Allis-						Subsidiary
	(Guarantor)			Guarantors			Non-Guarantors			Adjustments			Total
	Chalmers			Subsidiary			Non-			Consolidating			Consolidated
	(Guarantor)			Guarantors			Guarantors			Adjustments			Total
Cash Flows from Operating Activities:
Net loss	$	(19,297	)	$	(4,650	)	$	(1,407	)	$	6,057		$	(19,297	)
Adjustments to reconcile net loss to net cash (used) provided by operating activities:
Depreciation and amortization		8			10,852			4,977			—			15,837
Amortization of deferred issuance costs		366			—			—			—			366
Stock based compensation		6,084			—			—			—			6,084
Equity earnings in affiliates		6,057			—			—			(6,057	)		—
Allowance for bad debts		—			195			—			—			195
Deferred income taxes		—			34			106			—			140
Loss on sale of equipment		—			352			64			—			416
Changes in operating assets and liabilities, net of acquisitions:
Increase in trade receivables		—			(3,714	)		(12,230	)		—			(15,944	)
Increase in inventories		—			(1,434	)		(376	)		—			(1,810	)
Decrease (increase) in prepaid expenses and other current assets		2,057			235			(1,742	)		—			550
Decrease in other assets		—			432			242			—			674
Increase in trade accounts payable		—			8,417			4,537			—			12,954
(Decrease) increase in accrued interest		(4,031	)		—			138			—			(3,893	)
(Decrease) increase in accrued expenses		(15	)		(1,137	)		9,707			—			8,555
Decrease in accrued salaries, benefits and payroll taxes		—			(17	)		(1,662	)		—			(1,679	)
Decrease in other long- term liabilities		—			—			(141	)		—			(141	)
Net cash (used) provided by operating activities		(8,771	)		9,565			2,213			—			3,007
Cash Flows from Investing Activities:
Notes receivable from affiliates		(114	)		—			—			114			—
Increase in restricted cash		—			(4,141	)		—			—			(4,141	)
Purchases of investment interests		—			(1,177	)		—			—			(1,177	)
Deposits on asset commitments		—			—			82			—			82
Proceeds from sale of property and equipment		—			924			85			—			1,009
Purchase of property and equipment		—			(16,931	)		(5,827	)		—			(22,758	)
Net cash used in investing activities		(114	)		(21,325	)		(5,660	)		114			(26,985	)

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOW For the Two Months Ended February 28, 2011 (Predecessor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Subsidiary			Consolidating			Consolidated
	Allis-						Subsidiary
	(Guarantor)			Guarantors			Non-Guarantors			Adjustments			Total
	Chalmers			Subsidiary			Non-			Consolidating			Consolidated
	(Guarantor)			Guarantors			Guarantors			Adjustments			Total
Cash Flows from Financing Activities:
Accounts receivable from affiliates		—			12,811			—			(12,811	)		—
Accounts payable to affiliates		(23,607	)		—			10,796			12,811			—
Note payable to affiliate		—			—			114			(114	)		—
Payments on long-term debt		—			(567	)		(7,252	)		—			(7,819	)
Net borrowings (repayments) on line of credit		(36,500	)		—			—			—			(36,500	)
Proceeds from Parent		71,450			—			—			—			71,450
Payment of preferred stock dividend		(637	)		—			—			—			(637	)
Exercise of options and restricted stock awards, net of tax		(1,821	)		—			—			—			(1,821	)
Net cash provided by financing activities		8,885			12,244			3,658			(114	)		24,673
Net change in cash and cash equivalents		—			484			211			—			695
Cash and cash equivalents at beginning of year		—			16,380			4,560			—			20,940
Cash and cash equivalents at end of period	$	—		$	16,864		$	4,771		$	—		$	21,635

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING BALANCE SHEETS
December 31, 2010 (Predecessor)

	Allis-Chalmers			Subsidiary		Subsidiary		Consolidating			Consolidated
						Subsidiary
	(Guarantor)			Guarantors		Non-Guarantors		Adjustments			Total
	Allis-Chalmers			Subsidiary		Non-		Consolidating			Consolidated
	(Guarantor)			Guarantors		Guarantors		Adjustments			Total
Assets
Cash and cash equivalents	$	—		$	16,380	$	4,560	$	—		$	20,940
Trade receivables, net		—			79,100		77,397		(11,537	)		144,960
Inventories		—			22,066		20,074		—			42,140
Intercompany receivables		—			84,766		—		(84,766	)		—
Note receivable from affiliate		18,359			—		—		(18,359	)		—
Prepaid expenses and other		2,068			3,280		3,925		—			9,273
Total current assets		20,427			205,592		105,956		(114,662	)		217,313
Property and equipment, net		—			461,187		262,047		—			723,234
Goodwill		—			28,944		17,389		—			46,333
Other intangible assets, net		414			27,278		6,207		—			33,899
Debt issuance costs, net		7,405			—		—		—			7,405
Note receivable from affiliates		1,800			—		—		(1,800	)		—
Investments in affiliates		934,274			—		—		(934,274	)		—
Other assets		—			7,390		2,695		—			10,085
Total assets	$	964,320		$	730,391	$	394,294	$	(1,050,736	)	$	1,038,269
Liabilities and Stockholders’ Equity
Current maturities of long-term debt	$	—		$	979	$	14,236	$	—		$	15,215
Trade accounts payable		—			18,634		38,945		(11,537	)		46,042
Accrued salaries, benefits and payroll taxes		—			8,983		23,807		—			32,790
Accrued interest		15,310			—		214		—			15,524
Accrued expenses		1,192			18,504		10,980		—			30,676
Intercompany payables		69,756			—		15,010		(84,766	)		—
Note payable to affiliate		—			—		18,359		(18,359	)		—
Total current liabilities		86,258			47,100		121,551		(114,662	)		140,247
Long-term debt, net of current maturities		466,738			—		11,487		—			478,225
Note payable to affiliate		—			—		1,800		(1,800	)		—
Other long-term liabilities		—			—		8,473		—			8,473
Total liabilities		552,996			47,100		143,311		(116,462	)		626,945
Commitments and contingencies
Stockholders’ Equity
Preferred Stock		34,183			—		—		—			34,183
Common stock		737			3,527		42,963		(46,490	)		737
Capital in excess of par value		429,924			589,676		137,439		(727,115	)		429,924
Retained earnings (deficit)		(53,520	)		90,088		70,581		(160,669	)		(53,520	)
Total stockholders’ equity		411,324			683,291		250,983		(934,274	)		411,324
Total liabilities and stock holders’ equity	$	964,320		$	730,391	$	394,294	$	(1,050,736	)	$	1,038,269

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS For the Three Months Ended ~~June~~September 30, 2010 (Predecessor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Subsidiary			Consolidating			Consolidated
							Subsidiary
	(Guarantor)			Guarantors			Non-Guarantors			Adjustments			Total
	Allis-Chalmers			Subsidiary			Non-			Consolidating			Consolidated
Revenues	$	—		$	62,760		$	96,337		$	(453	)	$	158,644
	(Guarantor)			Guarantors			Guarantors			Adjustments			Total
Revenues	$	—		$	78,034		$	96,325		$	(71	)	$	174,288
Operating costs and expenses
Direct costs		—			4247,~~300~~152			7880,~~876~~541			(~~453~~71	)		~~120~~127,~~723~~622
Depreciation		—			14,198			6,319			—			20,517
Selling, general and administrative		1,176			7,677			3,919			—			12,772
Selling, general and administrative		1,365			7,156			3,593			—			12,114
Depreciation and amortization		12			15,547			6,790			—			22,349
Amortization		11			959			186			—			1,156
Total operating costs and expenses		1,188			70,376			91,250			(71	)		162,743
Total operating costs and expenses		1,376			64,613			88,974			(453	)		154,510
Income (loss) from operations		(1,188	)		7,658			5,075			—			11,545
Income (loss) from operations		(1,376	)		(1,853	)		7,363			—			4,134
Other income (expense):
Equity earnings in affiliates, net of tax		69,~~396~~376			—			—			(69,~~396~~376	)		—
Interest, net		(10,~~415~~769	)		~~141~~(505	)		(~~576~~562	)		—			(1011,~~850~~836	)
Other		1615			(~~254~~166	)		(65510	)		—			(~~303~~661	)
Total other income (expense)		(4,003	)		(113	)		(641	)		(6,396	)		(11,153	)
Total other expense		(1,378	)		(671	)		(1,072	)		(9,376	)		(12,497	)
Net income (loss) before income taxes		(52,~~379~~566	)		(16,~~966~~987	)		64,~~722~~003			(69,~~396~~376	)		(~~7,019~~952	)
Provision for income taxes		—			~~4,408~~811			(2,~~768~~425	)		—			(1,~~640~~614	)
Net income (loss)		(52,~~379~~566	)		27,~~442~~798			31,~~954~~578			(69,~~396~~376	)		(52,~~379~~566	)
Preferred stock dividend		(637	)		—			—			—			(637	)
Net income (loss) attributed to common stockholders	$	(63,~~016~~203	)	$	27,~~442~~798		$	31,~~954~~578		$	(69,~~396~~376	)	$	(63,~~016~~203	)

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS For the ~~Six~~Nine Months Ended ~~June~~September 30, 2010 (Predecessor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Subsidiary			Consolidating			Consolidated
							Subsidiary
	(Guarantor)			Guarantors			Non-Guarantors			Adjustments			Total
	Allis-Chalmers			Subsidiary			Non-			Consolidating			Consolidated
Revenues	$	—		$	114,642		$	185,700		$	(1,328	)	$	299,014
	(Guarantor)			Guarantors			Guarantors			Adjustments			Total
Revenues	$	—		$	192,676		$	282,025		$	(1,399	)	$	473,302
Operating costs and expenses
Direct costs		—			77124,~~376~~528			~~152~~232,~~390~~931			(1,~~328~~399	)		~~228~~356,~~438~~060
Depreciation		—			28,316			12,389			—			40,705
Selling, general and administrative		3,708			22,033			11,208			—			36,949
Selling, general and administrative		2,532			14,356			7,289			—			24,177
Depreciation and amortization		35			45,779			19,552			—			65,366
Amortization		23			1,916			373			—			2,312
Total operating costs and expenses		3,743			192,340			263,691			(1,399	)		458,375
Total operating costs and expenses		2,555			121,964			172,441			(1,328	)		295,632
Income (loss) from operations		(3,743	)		336			18,334			—			14,927
Income (loss) from operations		(2,555	)		(7,322	)		13,259			—			3,382
Other income (expense):
Equity earnings in affiliates, net of tax		817,~~267~~643			—			—			(817,~~267~~643	)		—
Interest, net		(2031,~~652~~421	)		~~214~~(291	)		(1,~~213~~775	)		—			(2133,~~651~~487	)
Other		3045			(1,~~778~~944	)		(70580	)		—			(12,~~818~~479	)
Total other income (expense)		(12,355	)		(1,564	)		(1,283	)		(8,267	)		(23,469	)
Total other expense		(13,733	)		(2,235	)		(2,355	)		(17,643	)		(35,966	)
Net income (loss) before income taxes		(1417,~~910~~476	)		(81,~~886~~899	)		1115,~~976~~979			(817,~~267~~643	)		(2021,~~087~~039	)
Provision for income taxes		—			1011,~~512~~323			(57,~~335~~760	)		—			53,~~177~~563
Net income (loss)		(1417,~~910~~476	)		19,~~626~~424			68,~~641~~219			(817,~~267~~643	)		(1417,~~910~~476	)
Preferred stock dividend		(1,~~274~~911	)		—			—			—			(1,~~274~~911	)
Net income (loss) attributed to common stockholders	$	(1619,~~184~~387	)	$	19,~~626~~424		$	68,~~641~~219		$	(817,~~267~~643	)	$	(1619,~~184~~387	)

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOW For the ~~Six~~Nine Months Ended ~~June~~September 30, 2010 (Predecessor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Other Subsidiaries			Consolidating			Consolidated
							Other
	(Guarantor)			Guarantors			(Non-Guarantors)			Adjustments			Total
	Allis-						Subsidiaries
	Chalmers			Subsidiary			(Non-			Consolidating			Consolidated
	(Guarantor)			Guarantors			Guarantors)			Adjustments			Total
Cash Flows from Operating Activities:
Net income (loss)	$	(1417,~~910~~476	)	$	19,~~626~~424		$	68,~~641~~219		$	(817,~~267~~643	)	$	(1417,~~910~~476	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation and amortization		2335			3045,~~232~~779			1219,~~762~~552			—			4365,~~017~~366
Amortization and write-off of debt issuance costs		1,~~094~~643			1218			—			—			1,~~106~~661
Stock based compensation		3,001			—			—			—			3,001
Stock-based compensation		4,374			—			—			—			4,374
Equity earnings in affiliates		(8,267	)		—			—			8,267			—
Allowance for bad debts		—			43			—			—			43
Deferred taxes		(10,954	)		—			133			—			(10,821	)
Equity earnings in affiliates		(17,643	)		—			—			17,643			—
Loss (gain) on sale of equipment		—			965			(158	)		—			807
Deferred taxes		(11,847	)		(332	)		163			—			(12,016	)
Loss on sale of equipment		—			74			76			—			150
Loss on investment		—			1,466			—			—			1,466
Equity in losses of unconsolidated affiliates		—			~~260~~409			—			—			~~260~~409
Changes in operating assets and liabilities:
Changes in operating assets and liabilities, net of acquisitions:
(Increase) in trade receivables		—			(215,~~962~~869	)		(2214,~~883~~492	)		—			(2530,~~845~~361	)
(Increase) in inventories		—			(~~744~~867	)		(1,~~648~~830	)		—			(2,~~392~~697	)
Decrease in prepaid expenses and other current assets		—129			23,~~778~~791			64,~~060~~104			—			8,~~838~~024
Decrease in other assets		—			~~127~~549			~~672~~716			—			~~799~~1,265
Increase in trade accounts payable		—			1,285			9,468			—			10,753
(Decrease) increase in trade accounts payable		—			(4,637	)		13,017			—			8,380
(Decrease) increase in accrued interest		76(9,016	)		(1625	)		88137			—			~~148~~(8,904	)
(Decrease) increase in accrued expenses		(58	)		2,243			1,616			—			3,801
Increase in accrued expenses		258			3,430			1,800			—			5,488
(Decrease) increase in accrued salaries, benefits and payroll taxes		—			(~~195~~850	)		23,~~140~~251			—			12,~~945~~401
(Decrease) in other long- term liabilities		—			—			(466	)		—			(466	)
(Decrease) in other long-term liabilities		—			—			(690	)		—			(690	)
Net Cash Provided By (Used In) Operating Activities		(2949,~~995~~543	)		3742,~~077~~403			1434,~~425~~023			—			2126,~~507~~883
Cash Flows from Investing Activities:
Notes receivable from affiliates		3,293			—			—			(3,293	)		—
Investment in affiliates		(19,467	)		—			—			19,467			—
Deposits on asset commitments		—			(10,000	)		(96	)		—			(10,096	)
Notes receivable from affiliates		8,328			—			—			(8,328	)		—
Deposits on asset commitments		—			(12,694	)		(273	)		—			(12,967	)
Proceeds from sale of investments		—			368			—			—			368
Proceeds from sale of property and equipment		—			24,~~416~~911			~~200~~373			—			25,~~616~~284
Purchase of property and equipment		—			(18,069	)		(12,920	)		—			(30,989	)
Business acquisitions		—			(18,237	)		—			—			(18,237	)
Net Cash Provided By (Used In) Investing Activities		3,293			(25,285	)		(12,816	)		(3,293	)		(38,101	)
Purchase of property and equipment		—			(30,158	)		(20,735	)		—			(50,893	)
Net Cash Used in Investing Activities		(11,139	)		(55,810	)		(20,635	)		11,139			(76,445	)

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 9 — CONDENSED CONSOLIDATING FINANCIAL INFORMATION (Continued)

CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOW For the ~~Six~~Nine Months Ended ~~June~~September 30, 2010 (Predecessor) (~~unaudited~~Unaudited)

	Allis-Chalmers			Subsidiary			Other Subsidiaries			Consolidating			Consolidated
							Other
	(Guarantor)			Guarantors			(Non-Guarantors)			Adjustments			Total
	Allis-						Subsidiaries
	Chalmers			Subsidiary			(Non-			Consolidating			Consolidated
	(Guarantor)			Guarantors			Guarantors)			Adjustments			Total
Cash Flows from Financing Activities:
Accounts receivable from affiliates		—			(2725,~~210~~492	)		(~~955~~790	)		2826,~~165~~282			—
Accounts payable to affiliates		2826,~~165~~282			—			—			(2826,~~165~~282	)		—
Note payable to affiliate		—			—			(3,293	)		3,293			—
Notes payable to affiliates		—			—			(8,328	)		8,328			—
Proceeds from parent contributions		—			19,467			—			(19,467	)		—
Proceeds from long-term debt		—			—			4,000			—			4,000
Payments on long-term debt		—			(3,116	)		(6,330	)		—			(9,446	)
Borrowings under line of credit		36,500			—			—			—			36,500
Payment of preferred stock dividend		(1,274	)		—			—			—			(1,274	)
Payments on long-term debt		—			(4,646	)		(9,942	)		—			(14,588	)
Payment of preferred stock dividend		(1,911	)		—			—			—			(1,911	)
Debt issuance costs		(189	)		—			—			—			(189	)
Net Cash Provided By (Used In) Financing Activities		2660,~~702~~682			(3010,~~326~~671	)		(615,~~578~~060	)		3(11,~~293~~139	)		(623,~~909~~812	)
Net change in cash and cash equivalents		—			(1824,~~534~~078	)		(41,~~969~~672	)		—			(2325,~~503~~750	)
Cash and cash equivalents at beginning of period		—			31,858			9,214			—			41,072
Cash and cash equivalents at end of period	$	—		$	137,~~324~~780		$	47,~~245~~542		$	—		$	1715,~~569~~322

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 10 — SEGMENT INFORMATION

In conjunction with the Merger, we reviewed the presentation of our operating segments. Based on this review, we determined that our operational performance would be segmented and reviewed by the Drilling Services and Well Services segments. The split of our organization and aggregation of our business into two segments was based on differences in management structure and reporting, economic characteristics, customer base, asset class and contract structure. The Drilling Services segment includes our international and domestic drilling, directional drilling, underbalanced drilling, tubular services and rental services operations. The Well Services segment includes our production services and valve manufacturing operations. As a result, we realigned our financial reporting segments and now report the Drilling Services and Well Services operations as separate, distinct reporting segments. Our historical segment data previously reported for the three and ~~six~~nine months ended ~~June~~September 30, 2010 and as of December 31, 2010 have been restated to conform to the new presentation.

All of our segments provide services to the energy industry. Indirect general and administrative expenses are allocated to each segment based on estimated use. The revenues, operating income (loss), depreciation and amortization, capital expenditures and assets of each of the reporting segments are reported below (in thousands):

	Successor				~~Predecessor~~	Predecessor
	Three Months Ended		Four Months Ended		Two Months Ended				Three Months Ended			Six Months Ended
	Three Months		Seven Months			Two Months				Three Months			Nine Months
	June 30,		June 30,		February 28,				June 30,			June 30,
	Ended		Ended			Ended				Ended			Ended
	2011		2011		2011				2010			2010
	September 30,		September 30,			February 28,				September 30,			September 30,
Revenues:
	2011		2011			2011				2010			2010
Drilling Services	$	187,969	$	247,277	$	106,050			$	146,913		$	277,441
Revenues:
Well Services		32,169		43,587		20,835				11,731			21,573
Drilling Services	$	195,446	$	442,723		$	106,050			$	151,536		$	428,977
Total revenues	$	220,138	$	290,864	$	126,885			$	158,644		$	299,014
Well Services		26,962		70,549			20,835				22,752			44,325
Operating Income (Loss):
Total revenues	$	222,408	$	513,272		$	126,885			$	174,288		$	473,302
Drilling Services	$	8,084	$	8,488	$	(9,943	)		$	4,551		$	4,307
Operating Income (Loss):
Well Services		6,653		7,179		109				(417	)		(925	)
Drilling Services	$	8,206	$	16,694		$	(9,943	)		$	6,969		$	11,276
Total income (loss) from operations	$	14,737	$	15,667	$	(9,834	)		$	4,134		$	3,382
Well Services		3,155		10,334			109				4,576			3,651
Depreciation and Amortization Expense:
Total income (loss) from operations	$	11,361	$	27,028		$	(9,834	)		$	11,545		$	14,927
Drilling Services	$	24,023	$	31,777	$	13,792			$	19,393		$	38,581
Depreciation and Amortization Expense:
Well Services		3,364		4,379		2,045				2,280			4,436
Drilling Services	$	24,569	$	56,346		$	13,792			$	19,781		$	58,362
Total depreciation and amortization expense	$	27,387	$	36,156	$	15,837			$	21,673		$	43,017
Well Services		3,149		7,528			2,045				2,568			7,004
Capital Expenditures:
Total depreciation and amortization expense	$	27,718	$	63,874		$	15,837			$	22,349		$	65,366
Drilling Services	$	17,012	$	21,619	$	19,939			$	17,417		$	27,187
Capital Expenditures:
Well Services		1,493		3,953		2,819				1,814			3,802
Drilling Services	$	17,767	$	39,386		$	19,939			$	17,350		$	44,537
Total capital expenditures	$	18,505	$	25,572	$	22,758			$	19,231		$	30,989
Well Services		4,786		8,739			2,819				2,554			6,356
Revenues:
Total capital expenditures	$	22,533	$	48,125		$	22,758			$	19,904		$	50,893
United States	$	93,595	$	126,735	$	57,651			$	59,795		$	106,923
Revenues:
Argentina		106,100		137,318		57,458				76,640			149,025
United States	$	92,950	$	219,685		$	57,651			$	75,833		$	182,756
Brazil		9,306		12,004		5,250				10,502			20,002
Argentina		105,805		243,123			57,458				77,115			226,140
Other international		11,137		14,807		6,526				11,707			23,064
Brazil		12,035		24,038			5,250				10,031			30,033
Total revenues	$	220,138	$	290,864	$	126,885			$	158,644		$	299,014
Other international		11,618		26,426			6,526				11,309			34,373
Total revenues	$	222,408	$	513,272		$	126,885			$	174,288		$	473,302

ALLIS-CHALMERS ENERGY INC.
NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 10 — SEGMENT INFORMATION (Continued)

	Successor		~~Predecessor~~	Predecessor
	June 30,		December 31,
	September 30,			December 31,
	2011		~~2010~~	2010
Goodwill:
Drilling Services	$	206,441	$	~~40,639~~$	40,639
Well Services		60,987		~~5,694~~	5,694
Total goodwill	$	267,428	$	~~46,333~~$	46,333
Assets:
Drilling Services	$	1,~~145~~133,~~427~~183	$	~~940,481~~$	940,481
Well Services		~~159~~158,~~167~~484		~~97,788~~	97,788
Total assets	$	1,~~304~~291,~~594~~667	$	~~1,038,269~~$	1,038,269
Long Lived Assets:
United States	$	~~623~~611,~~198~~551	$	~~501,117~~$	501,117
Argentina		293,~~721~~848		~~167,137~~	167,137
Brazil		6569,~~456~~395		~~86,949~~	86,949
Other international		6061,~~775~~564		~~65,753~~	65,753
Total long lived assets	$	1,~~043~~036,~~150~~358	$	~~820,956~~$	820,956

NOTE 11 — LEGAL MATTERS

We are named from time to time in legal proceedings related to our activities prior to our predecessor’s 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~~ legal proceeding is remote.

We are also involved in litigation or proceedings that have arisen in our ordinary business activities. We insure against these risks to the extent deemed prudent by our management and to the extent insurance is available, but no assurance can be given that the nature and amount of that insurance will be sufficient to fully indemnify us against liabilities arising out of pending and future legal proceedings. Many of these insurance policies contain deductibles or self-insured retentions in amounts we deem prudent and for which we are responsible for payment. If there is a claim, dispute or pending litigation in which we believe a negative outcome is probable and a loss by the Company can be reasonably estimated, we record a liability for the expected loss but at this time any such expected loss are immaterial to our financial condition and results of operations. In addition we have certain claims, disputes and pending litigation in which we do not believe a negative outcome is probable or for which the loss cannot be reasonably estimated.

Shortly following the announcement of the ~~merger~~Merger ~~agreement~~Agreement with Seawell (now Archer) in August 2010, ~~ten~~multiple ~~putative~~ stockholder class-action ~~petitions~~lawsuits ~~and complaints~~ were filed in Delaware and in Texas against various combinations of us, members of our board of directors and the Archer parties to the ~~merger agreement.~~Merger ~~Seven of the lawsuits were filed in Texas and three lawsuits were filed in Delaware~~Agreement. These lawsuits had challenged the ~~proposed~~Merger ~~merger~~ and generally ~~allege,~~alleged ~~among other things,~~ that our directors ~~have~~had breached their fiduciary duties owed to our public stockholders by approving the ~~merger~~ Merger and failing to take steps to maximize our value to our public stockholders. In ~~The~~February ~~lawsuits generally sought~~2011, ~~among other things, compensatory damages, attorneys’ and experts’ fees, declaratory and injunctive relief concerning~~ the ~~alleged~~Delaware ~~breaches~~court ofdenied ~~fiduciary duties, and injunctive relief prohibiting the defendants from consummating the merger. In February 2011, the~~ plaintiffs’ request for an injunction ~~was denied by the Delaware court~~ and the ~~merger~~Merger closed on on February 23, 2011. After Inthe ~~July 2011~~Merger, ~~plaintiffs~~the ~~and~~consolidated ~~defendants~~Delaware ~~jointly~~lawsuit ~~filed~~was adismissed ~~stipulation~~as moot and ~~order for~~several ~~the dismissal~~ of ~~all~~the Texas ~~claims~~lawsuits ashave ~~moot~~also ~~with~~been ~~the~~dismissed. Two ~~plaintiffs~~Texas ~~reserving~~lawsuits ~~only~~remain ~~their~~on ~~application~~file, ~~for attorney’s~~but ~~fees~~both ~~and~~are ~~expenses,~~entirely ~~which~~inactive ~~the Company~~ and ~~other~~we ~~defendants oppose. The proposed~~believe ~~stipulation~~both ~~and~~will ~~order~~be isdismissed ~~pending~~in ~~before~~due ~~the court~~course.

The case of Nexen Petroleum U.S.A., Inc. et al v. Allis-Chalmers Rental Services, LLC, Cameron, Hydril and Tri-City Pipe & Machine, ~~Cause~~involved ~~No. 88810~~a inblow ~~the~~out ~~15th~~on ~~Judicial~~a ~~District,~~well ~~State~~operated ofby Nexen in ~~Louisiana~~Vermilion isParish, ~~presently~~Louisiana ~~scheduled~~and ~~for~~was ~~trial~~settled in September 2011. The ~~case~~settlement ~~involves~~was afunded ~~blow~~by ~~out~~our oninsurers aand we were ~~well~~responsible ~~operated~~for byour ~~Nexen~~standard ininsurance ~~Vermilion~~deductible ~~Parish~~amount. We ~~During~~have ~~drilling~~no ~~operations,~~further ~~Nexen~~liability ~~lost~~under ~~control~~ these claims.

ALLIS-CHALMERS ENERGY INC. NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTES TO UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

NOTE 11 — LEGAL MATTERS (Continued)

of the well, activated and closed ‘blow out preventers’ rented from Allis-Chalmers Rental Services, LLC (ACRS) thereby sealing the well. Nexen then re-opened the blow out preventers to attempt an unsuccessful dynamic kill. Nexen alleges that it then again attempted to reseal the well using the blow out preventers but was unable to obtain a complete seal. The well allegedly then flowed uncontrolled for up to a day causing damage to the rig and other equipment, and the hole. The blow out preventers were manufactured by Cameron and Hydril and some of the components of the Cameron equipment were machined by Tri-City. Nexen alleges that the blow out preventers failed due to the fault of the defendants. ACRS contends that Nexen actions in specifying the equipment for the well, designing the well, and operating the well including its acts and omissions for the well control event caused any failure of the equipment rented to Nexen by ACRS. There is conflicting evidence and expert testimony affecting several aspects of this case. It is impossible to predict the outcome with any degree of certainty. ACRS and its insurers are treating this case as highly defensible and continue to vigorously contest it.

NOTE 12 — TRANSACTIONS WITH PARENT

In connection with the Merger, we received approximately $71.4 million in funding from our Parent. The proceeds were mainly used to pay off debt, debt related interest and ~~merger~~Merger related expenses. The ~~merger~~Merger related expenses were primarily for legal and professional fees and change of control provisions. The three and ~~four~~seven months ended ~~June~~September 30, 2011 includes Parent allocations of ~~interest~~ interest charges of approximately $~~969,000~~1.2 million and $12.35 million, respectively, and other administrative charges of approximately $15.89 million and $7.7 million. Parent administrative charges are allocated proportional to the average EBIT and revenue contribution. The allocation method used is considered reasonable by management and our estimated costs that would have been incurred on a ~~stand~~standalone ~~alone~~ basis would not have been materially different. The amount due to Parent was approximately $7491.43 million at ~~June~~ September 30, 2011 and balance is classified as a long-term liability. The interest rate used for allocation of interest charges was 56.32% as of ~~June~~September 30, 2011.

NOTE 13 — SUBSEQUENT EVENT

In July 2011, we purchased $125.0 million aggregate principal of our 9.0% senior notes for a total consideration of $1,023 per $1,000 principal amount. In connection with this purchase we have drawn $130.0 million on our Parent’s $550 million Multicurrency Term and Revolving Facility. The $550 million facility has a final maturity date of November 11, 2015 and interest rate is based on LIBOR plus a margin.

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

OF OPERATIONS

The following discussion and analysis should be read in conjunction with our consolidated financial statements and the notes thereto included elsewhere in this report. This report contains forward-looking statements that involve risks and uncertainties. Our actual results may differ materially from the results discussed in such forward-looking statements. Factors that might cause such differences include, but are not limited to, the general condition of the oil and natural gas drilling industry, demand for our oil and natural gas service and rental products, and competition. For more information on forward-looking statements please refer to the section entitled “Forward-Looking Statements” on page 39.

Overview of Our Business

We are a multi-faceted oilfield service company that provides services and equipment to oil and natural gas exploration and production companies, throughout the United States including Texas, Louisiana, Pennsylvania, Arkansas, West Virginia, Oklahoma, Colorado, offshore in the Gulf of Mexico and internationally primarily in Argentina, Brazil, Bolivia and Mexico. We operate in two sectors of the oil and natural gas service industry: Well Services and Drilling 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 and rates per day for equipment and tools that we rent to our customers. 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 the 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.

Our operating costs do not fluctuate in direct proportion to changes in revenues. Our operating expenses consist 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 operating income as a percentage of revenues is generally affected by our level of revenues.

Merger with Archer

On February 23, 2011, we merged with and into Wellco Sub Company, a wholly owned subsidiary of Archer, and each share of our common stock was converted into the right to receive either 1.15 Archer common shares or $4.25 in cash. In connection with the Merger, Wellco Sub Company changed its name to Allis-Chalmers Energy Inc.

We recorded approximately $14.7 million, ~~$1.6 million~~ and $2.5 million of costs related to the ~~merger~~ Merger during the two months ended February 28, 2011 and the ~~three~~seven ~~and four~~ months ended ~~June~~September 30, 2011, respectively, which are included in selling, general and administrative expense on our Consolidated Condensed Statements of Operations. Approval of the ~~merger~~Merger resulted in certain of our ~~contractual~~ contractual obligations being triggered or accelerated under the “change of control” provisions of ~~such~~ such contractual arrangements. Examples of such arrangements include stock-based compensation awards, severance and retirement plan agreements applicable to executive officers, directors and ~~certain~~ certain employees and certain other debt obligations, including our senior notes.

Results of Operations

In July 2010, we acquired all of the outstanding stock of American Well Control, Inc., or AWC, which is reported as part of our Well Services segment. We consolidated the results of this transaction from the date it was effective.

In connection with the Merger with Archer, our assets and liabilities have been adjusted to their fair values based on the purchase price resulting in changes to depreciation, amortization and interest in the successor period.

The foregoing business combinations 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~~September 30, 2011 and 2010

Our revenues for the three months ended ~~June~~September 30, 2011 were $~~220~~222.14 million, an increase of 38 27.86% compared to $~~158~~174.63 million for the three months ended ~~June~~September 30, 2010. The increase in revenues is due to the increase in revenues in both of our operating segments. Our Drilling Services segment revenues increased 2729.~~9% to $188.~~0 million for the three months ended June 30, 2011 compared to $146.9 million for the three months ended June 30, 2010 due to increased utilization and rig rates in Argentina and Bolivia and increased utilization of our equipment and improved pricing domestically. Revenues for our Well Services segment increased 174.2% to $32195.24 million for the ~~three~~ ~~months ended June 30, 2011 compared to $11.7 million for the~~ three ~~months ended June 30, 2010~~ ~~due to $9.7 million of revenues from AWC in the current period, along with an increased utilization of our equipment and improved pricing.~~

~~Our direct costs for the three months ended June 30, 2011 increased 34.7% to $162.6 million, or~~31 73.9% of revenues, compared to $120.7 million, or 76.1%, of revenues for the three months ended June 30, 2010. Our direct costs in all of our segments increased in absolute dollars in the three months ended June 30, 2011 compared to the three months ended June 30, 2010. Our Drilling Services segment revenues for the three months ended June 30, 2011 increased 27.9% from revenues for the three months ended June 30, 2010 and direct costs increased 27.8% over that same period. Our Well Services segment revenues for the three months ended June 30, 2011 increased 174.2% from revenues for the three months ended June 30, 2010, while direct costs increased 122.6% over that same period. The improvement in gross margin is due to improved utilization of equipment and pricing which was slightly offset by the impact of the acquisition of AWC. AWC provided $9.7 million of revenues during the three months ended June 30, 2011 and it also increased direct costs by $6.0 million for the same period for an effective gross margin as a percentage of revenues of 38.3%. AWC’s gross margin as a percentage of revenues is less than our overall Well Services gross margin percentage as AWC’s manufacturing operation has a higher labor component. Gross margin as a percentage of revenues for our Well Services segment for the three months ended June 30, 2011 was 39.5% compared to 25.5% for the three months ended June 30, 2010.

DepreciationTable expense increased 12.2% to $23.0 million for the three months ended June 30, 2011 from $20.5 million for the three months ended June 30, 2010. The primary increase in depreciation expense is due to our capital expenditure programs for our Drilling Services segment. Depreciation expense as a percentage of revenues decreased to 10.5% for the second quarter of 2011, compared to 12.9% for the second quarter of 2010, due to the noted increases in revenues. Contents

~~Selling, general and administrative expense was $15.4 million for the three~~ months ended ~~June~~ September 30, 2011 compared to $12151.15 million for the three months ended ~~June~~September 30, 2010. ~~Selling,~~due ~~general~~to ~~and~~capital ~~administrative expense~~ expenditures, increased ~~primarily~~utilization ~~due~~and torig anrates ~~increase~~ in ~~severance~~Argentina, ~~expense~~Bolivia and ~~other professional~~Brazil ~~fees~~and ~~for~~increased ~~the~~utilization ~~three months ended June 30, 2011 compared to the same period~~ of ~~the prior~~ ~~year~~our ~~all~~equipment ~~due principally to the Merger~~ and aimproved ~~general~~pricing ~~increase relating to additional operational activities which was partially offset by a reduction in stock based compensation~~domestically. ~~The~~Revenues ~~three~~for ~~months ended~~our ~~June 30,~~Well ~~2011~~Services ~~includes~~segment ~~approximately $1~~increased 18.~~6 million~~5% ~~of severance expense and other professional fees relating~~ to ~~the Merger and~~ $127.70 million ~~of allocated general and administrative expenses from our Parent. Stock based compensation~~ for the three months ended ~~June~~September 30, ~~2010~~2011 ~~was~~compared to $122.68 million ~~with~~ ~~no related expense~~ for the three months ended ~~June~~September 30, ~~2011~~2010 due to ~~the~~capital ~~acceleration~~expenditures, ofincreased ~~stock based~~demand ~~compensation~~from ~~expense~~our valve asmanufacturing ofoperations ~~the~~and ~~Merger~~improved ~~date.~~pricing Aswhich awas ~~percentage~~partially ofoffset ~~revenues,~~by ~~selling,~~a ~~general~~decrease in ~~and~~equipment ~~administrative~~utilization ~~expense~~for ~~was~~our 7coiled tubing operations.0% ~~for~~The ~~the~~decrease ~~three~~in ~~months~~equipment ~~ended~~utilization ~~June 30,~~was primarily ~~2011~~associated ~~compared~~with toadditional ~~7.6%~~repairs ~~for the~~and ~~same~~maintenance ~~period~~on inour ~~the~~coil ~~prior~~tubing ~~year~~units.

Our direct costs for the three months ended September 30, 2011 increased 29.1% to $164.7 million, or 74.1% of revenues, compared to $127.6 million, or 73.2%, of revenues for the three months ended September 30, 2010. Our direct costs in all of our segments increased in absolute dollars in the three months ended September 30, 2011 compared to the three months ended September 30, 2010. Our Drilling Services segment revenues for the three months ended September 30, 2011 increased 29.0% from revenues for the three months ended September 30, 2010 and direct costs increased 28.5% over that same period. Our Well Services segment revenues for the three months ended September 30, 2011 increased 18.5% from revenues for the three months ended September 30, 2010, while direct costs increased 34.2% over that same period. The reduction in gross margin was due to the decreased utilization of equipment in our coiled tubing operations and related increase in repairs and maintenance costs.

Depreciation expense increased 17.5% to $24.8 million for the three months ended September 30, 2011 from $21.1 million for the three months ended September 30, 2010. The primary increase in depreciation expense is due to our capital expenditure programs for our Drilling Services segment. Depreciation expense as a percentage of revenues decreased to 11.1% for the third quarter of 2011, compared to 12.1% for the third quarter of 2010, due to the noted increases in revenues.

Selling, general and administrative expense was $18.6 million for the three months ended September 30, 2011 compared to $12.8 million for the three months ended September 30, 2010. Selling, general and administrative expense increased primarily due to $5.9 million allocated general and administrative expenses from our Parent and a general increase relating to additional operational activities which was partially offset by a reduction in stock based compensation expense. Stock based compensation for the three months ended September 30, 2010 was $1.4 million with no related expense for the three months ended September 30, 2011 due to the acceleration of stock based compensation expense as of the Merger date. As a percentage of revenues, selling, general and administrative expense was 8.4% for the three months ended September 30, 2011 compared to 7.3% for the same period in the prior year.

Amortization expense for the three months ended September 30, 2011 increased $1.6 million to $2.9 million compared to $1.3 million for the three months ended September 30, 2010. The increase is primarily related to the amortization of intangibles recorded in connection with the Merger.

We had income from operations of $11.4 million for the three months ended September 30, 2011, compared to income from operations of $11.5 million for the three months ended September 30, 2010. The decrease in income from operations was mainly due to the slight reduction in gross margin, the increases in depreciation, amortization and selling, general and administrative expenses.

Our interest expense was $9.3 million for the three months ended September 30, 2011, compared to $11.9 million for the three months ended September 30, 2010. Approximately $51.5 million of our debt was paid in connection with the Merger. Interest expense for the three months ended September 30, 2011 was reduced by approximately $849,000 in connection with debt premium amortization and interest expense for the three months ended September 30, 2010 includes amortization expense of deferred financing costs of $555,000. Interest expense for the three months ended September 30, 2011 included approximately $1.2 million of allocated interest charges from our Parent.

Income tax expense for the three months ended September 30, 2011 was $3.4 million or 210.9% of our income before income taxes compared to an income tax expense of $1.6 million or (169.5)% of our net loss before income taxes from 2010. The change in the tax rate is principally the result of valuation allowances on losses generated in the United States and variances in withholding taxes from foreign operations as a percentage of pretax income (loss).

We had a net loss of $1.8 million for the three months ended September 30, 2011, compared to net loss of $2.6 million for the three months ended September 30, 2010 due to the foregoing reasons.

The net loss attributed to common stockholders for the three months ended September 30, 2010 was $3.2 million after $637,000 in preferred stock dividends. The preferred stock dividend related to 36,393 preferred shares of $1,000 par value at 7.0%.

~~Amortization~~The ~~expense~~following ~~for~~table ~~the~~compares ~~three~~revenues ~~months~~and ~~ended~~income ~~June 30,~~from ~~2011~~operations ~~increased~~for ~~$3.2 million~~each toof ~~$4.4 million~~our ~~compared~~business ~~to $1.2 million~~ segments for the ~~three~~quarter ~~months~~ ended ~~June~~September 30, 2011 and 2010. ~~The~~Income ~~increase~~from isoperations ~~primarily~~consists ~~related~~of toour ~~the~~revenues ~~amortization~~less ofdirect ~~intangibles~~costs, ~~recorded~~selling, ingeneral ~~connection~~and ~~with~~administrative ~~the~~expenses, ~~Merger.~~depreciation and amortization:

We had income from operations of $14.7 million for the three months ended June 30, 2011, compared to income from operations of $4.1 million for the three months ended June 30, 2010. The increase in income from operations was mainly due to the increase in revenues and improved margins which was partially offset by the increases in depreciation, amortization and selling, general and administrative expenses.



	Revenues						Income from Operations
	Successor		Predecessor				Successor		Predecessor
	Three Months Ended		Three Months Ended				Three Months Ended		Three Months Ended
	September 30, 2011		September 30, 2010		Change		September 30, 2011		September 30, 2010		Change
				(in thousands)
Revenues:
Drilling Services	$	195,446	$	151,536	$	43,910	$	8,206	$	6,969	$	1,237
Well Services		26,962		22,752		4,210		3,155		4,576		(1,421	)

Total	$	222,408	$	174,288	$	48,120	$	11,361	$	11,545	$	(184	)

Our interest expense was $10.1 million for the three months ended June 30, 2011, compared to $11.1 million for the three months ended June 30, 2010. Approximately $51.5 million of our debt was paid in connection with the Merger. Interest expense for the three months ended June 30, 2011 was reduced by approximately $1.1 million in connection with debt premium amortization and interest expense for the three months ended June 20, 2010 includes amortization expense of deferred financing costs of $554,000. Interest expense for the three months ended June 30, 2011 included approximately $969,000 of allocated interest charges from our Parent.

Income tax expense for the three months ended June 30, 2011 was $3.0 million or 63.6% of our income before income taxes compared to an income tax benefit of $1.6 million or 23.4% of our net loss before income taxes from 2010. The change in the tax rate is principally the result of valuation allowances on losses generated in the United States and variances in withholding taxes from foreign operations as a percentage of pretax income (loss).

We had net income of $1.7 million for the three months ended June 30, 2011, compared to net loss of $5.4 million for the three months ended June 30, 2010 due to the foregoing reasons.

The net loss attributed to common stockholders for the three months ended June 30, 2010 was $6.0 million after $637,000 in preferred stock dividends. The preferred stock dividend related to our 36,393 shares of $1,000 par value preferred shares at 7.0%.

The following table compares revenues and income (loss) from operations for each of our business segments for the quarter ended June 30, 2011 and 2010. Income (loss) from operations consists of our revenues less direct costs, selling, general and administrative expenses, depreciation and amortization:

	Revenues						Income (Loss) from Operations
	Successor		Predecessor				Successor		Predecessor
	Three Months Ended		Three Months Ended				Three Months Ended		Three Months Ended
	June 30,		June 30,				June 30,		June 30,
	2011		2010		Change		2011		2010			Change
			(in thousands)
Revenues:
Drilling Services	$	187,969	$	146,913	$	41,056	$	8,084	$	4,551		$	3,533
Well Services		32,169		11,731		20,438		6,653		(417	)		7,070
Total	$	220,138	$	158,644	$	61,494	$	14,737	$	4,134		$	10,603

Drilling Services

Revenues for the quarter ended ~~June~~September 30, 2011 for the Drilling Services segment were $~~188~~195.0 4 million, an increase of 2729.90% compared to $~~146~~151.95 million in revenues for the quarter ended ~~June~~ September 30, 2010. Income from operations increased $31.52 million and resulted in income from operations of $8.1 2 million for the quarter ended ~~June~~September 30, 2011 compared to income from operations of $47.60 million in the three months ended ~~June~~September 30, 2010. The revenue increase was due to our investment in new equipment, increased utilization and rig rates in Argentina, Bolivia and ~~Bolivia~~Brazil and improved pricing and utilization for our directional drilling services, underbalanced services, rental services and tubular services domestically. The increase in income from operations was mainly due to the noted revenue increases which were partially offset by~~: (1) allocations of merger related costs~~ ~~consisting of severance expense and other professional fees of $1.2 million for the three months ended June 30, 2011; (2)~~ allocations of $14.36 million of Parent general and administration charges~~; (3) decrease~~ ~~in utilization~~ and ~~pricing for our land drilling services in Brazil; and (4)~~ an increase of $4.6 8 million, or 2324.92%, in depreciation and amortization in the ~~second~~third quarter of 2011 compared to the third ~~second~~ quarter of 2010. The increase in depreciation and amortization expense was the result of capital expenditure programs and Merger related adjustments to the fair value of intangible assets.

Well Services

Revenues for the quarter ended September 30, 2011 for the Well Services segment were $27.0 million, an increase of 18.5% compared to $22.8 million in revenues for the quarter ended September 30, 2010. Income from operations decreased $1.4 million and resulted in income from operations of $3.2 million for the quarter ended September 30, 2011 compared to $4.6 million in the three months ended September 30, 2010. The revenue increase was due to capital expenditures, increased demand from our valve manufacturing operations and improved pricing which was partially offset by a decrease in equipment utilization for our coiled tubing operations. The reduction in income from operations was primarily due to a decrease in equipment utilization for our coiled tubing operations, allocations of $1.3 million of Parent general and administration charges and an increase of $581,000, or 22.6%, in depreciation and amortization in the third quarter of 2011 compared to the third quarter of 2010. The increase in depreciation and amortization expense was the result of capital expenditure programs and Merger related adjustments to the fair value of intangible assets.

Comparison of Nine Months Ended September 30, 2011 and 2010

Our revenues for the nine months ended September 30, 2011 were $640.2 million, an increase of 35.3% compared to $473.3 million for the nine months ended September 30, 2010. The increase in revenues is due to the increase in revenues in both of our operating segments. Our Drilling Services segment revenues increased 27.9% to $548.8 million for the nine months ended September 30, 2011 compared to $429.0 million for the nine months ended September 30, 2010 due to our investment in new equipment, increased utilization and rig rates in Argentina and Bolivia and increased utilization of our equipment and improved pricing domestically. Revenues for our Well Services segment increased 106.2% to $91.4 million for the nine months ended September 30, 2011 compared to $44.3 million for the nine months ended September 30, 2010 due to a $21.9 million increase in revenues from AWC, increased utilization of our equipment and improved pricing. AWC was acquired in July 2010.

Our direct costs for the nine months ended September 30, 2011 increased 33.6% to $475.6 million, or 74.3% of revenues, compared to $356.1 million, or 75.2%, of revenues for the nine months ended September 30, 2010. Our direct costs in all of our segments increased in absolute dollars in the nine months ended September 30, 2011 compared to the nine months ended September 30, 2010. Our Drilling Services segment revenues for the nine months ended September 30, 2011 increased 27.9% from revenues for the nine months ended September 30, 2010, while direct costs increased 28.1% over that same period, resulting in a minor reduction in gross margin as a percentage of revenues to 23.7% for the nine months ended September 30,

~~Well~~2011 compared to 23.9% for the nine months ended September 30, 2010. The domestic operations in our Drilling Services segment realized price increases starting in the later part of the first quarter of 2010 and our domestic land drilling operations began in the first quarter of 2011 with the related improvement being offset by a decrease in utilization for our land drilling services in Brazil and increased compensation costs and other inflationary cost increases in Argentina and Brazil. Our Well Services segment revenues for the nine months ended September 30, 2011 increased 106.2% from revenues for the nine months ended September 30, 2010, while direct costs increased 93.9% over that same period. The improvement in gross margin is due to improved utilization of equipment and pricing.

~~Revenues~~Depreciation ~~for~~expense ~~the~~increased ~~quarter ended June 30, 2011 for the Well Services segment were $32~~13.~~2 million, an increase of 174.2~~5% ~~compared~~ to $1170.72 million ~~in revenues~~ for the ~~quarter~~nine months ended ~~June~~September 30, ~~2010.~~2011 ~~Income~~ from ~~operations increased~~ $761.18 million ~~and resulted in income from operations of $6.7 million~~ for the ~~quarter~~nine ~~ended June 30, 2011 compared to a loss from operations of $417,000 in the three~~ months ended ~~June~~September 30, 2010. The ~~acquisition~~primary ofincrease ~~AWC provided our Well Services segment with~~in ~~$9.7 million~~depreciation ofexpense ~~additional~~is ~~revenues~~due ~~and~~to ~~$2.6 million~~our ofcapital ~~additional~~expenditure ~~operating~~programs ~~income during the second quarter of 2011. We also had improved utilization and pricing~~ for our ~~coil~~Drilling ~~tubing~~Services ~~units~~segment. ~~Partially~~Depreciation ~~offsetting~~expense ~~the~~as ~~improved~~a ~~results~~percentage ~~in the three months ended June 30, 2011 were: (1) allocations~~ of ~~merger~~revenues ~~related~~decreased ~~costs~~to ~~consisting~~11.0% ~~of severance expense and other professional fees of $400,000~~ for the ~~three~~nine months ended ~~June~~ September 30, 2011~~; (2) allocations of $400~~,~~000~~ ofcompared ~~Parent~~to ~~general and administration charges and (3) an increase of $1~~13.1 ~~million, or 47.6~~%, infor ~~depreciation and amortization in~~ the ~~second~~same ~~quarter~~period ~~of 2011 compared to the second quarter of 2010. The increase~~ in ~~depreciation~~ ~~and amortization expense was~~ the ~~result~~prior ofyear, ~~capital~~due ~~expenditure programs and Merger related adjustments~~ to the ~~fair~~noted increases ~~value~~in ~~of intangible assets~~revenues.

~~Comparison~~Selling, general and administrative expense was $62.5 million for the nine months ended September 30, 2011 compared to $36.9 million for the nine months ended September 30, 2010. Selling, general and administrative expense increased primarily due to an increase in stock based compensation expense, severance expenses and professional and other fees for the nine months ended September 30, 2011 compared to the same period of ~~Six~~the ~~Months~~prior ~~Ended~~year ~~June~~all due principally to the Merger. Stock based compensation for the nine months ended September 30, 2011 was $6.1 million with approximately $5.4 million of this amount relating to the acceleration of stock based compensation expense associated with the Merger and ~~2010~~was $4.4 million in the same period of the prior year. The nine months ended September 30, 2011 includes approximately $4.6 million of severance expense relating to the separation of certain executives after the Merger. Professional and other fees for the nine months ended September 30, 2011 included $7.1 million of costs related to the Merger. The nine months ended September 30, 2011 also includes $7.7 million of allocated general and administrative expenses from our Parent and other increases related to additional operating activities. As a percentage of revenues, selling, general and administrative expense was 9.8% for the nine months ended September 30, 2011 compared to 7.8% for the same period in the prior year.

~~Our~~During ~~revenues for~~ the ~~six~~nine months ended ~~June~~September 30, 2011 ~~were $417.7 million~~, anwe ~~increase~~recorded ofa ~~39.7% compared to~~ $~~299~~5.01 million ~~for~~loss ~~the~~on ~~six months ended June 30, 2010. The increase in revenues is due to~~ the ~~increase in revenues in both~~ impairment of ~~our~~intangible ~~operating segments~~assets. ~~Our~~In ~~Drilling~~connection ~~Services~~with ~~segment revenues increased 27.4% to $353.3 million for~~ the ~~six months ended June 30~~Merger, ~~2011~~a ~~compared to~~ $~~277~~5.41 million ~~for~~value ~~the~~was ~~six~~assigned ~~months ended June 30, 2010 due~~ to ~~our~~the Allis-Chalmers ~~investment~~tradename. inFollowing ~~new~~the ~~equipment~~Merger, ~~increased~~ ~~utilization~~Seawell and ~~rig~~its ~~rates~~subsidiaries, inincluding ~~Argentina~~us, ~~and Bolivia and increased utilization of our~~have ~~equipment~~begun ~~and~~operating ~~improved~~under ~~pricing domestically. Revenues for our Well Services segment increased 198.6% to $64.4 million for~~ the ~~six~~name ~~months ended June 30, 2011 compared to $21~~Archer.~~6 million~~ ~~for~~As ~~the six~~a ~~months ended June~~result, ~~2010~~it ~~due~~was todetermined ~~$19.8 million~~that ofthere ~~revenues~~was ~~from~~no ~~AWC~~material remaining invalue ~~the~~associated ~~current period, along~~ with anthe ~~increased~~Allis-Chalmers ~~utilization of our equipment and improved pricing~~tradename.

~~Our~~Amortization ~~direct~~expense ~~costs~~ for the ~~six~~nine months ended ~~June~~September 30, 2011 increased ~~36.1% to~~ $~~310~~6.90 million, ~~or 74.4% of revenues, compared~~ to $228.4 million, or 76.4%, of revenues for the six months ended June 30, 2010. Our direct costs in all of our segments increased in absolute dollars in the six months ended June 30, 2011 compared to the six months ended June 30, 2010. Our Drilling Services segment revenues for the six months ended June 30, 2011 increased 27.4% from revenues for the six months ended June 30, 2010, while direct costs increased 27.9~~% over that same period, resulting in a minor reduction in gross margin as a percentage of revenues to 23~~.~~0% for the six months ended June 30,~~6 ~~2011~~million compared to 23$3.~~4% for the six months ended June~~6 ~~30,~~million 2010. Our Drilling Services segment began to realize price increases starting in the later part of the first quarter of 2010 with the related improvement being offset by a decrease in utilization and pricing for ~~our land drilling services in Brazil. Our Well Services segment revenues for~~ the ~~six~~nine months ended ~~June~~September 30, ~~2011 increased 198.6% from revenues for the six months ended June 30,~~ 2010~~, while direct costs increased 145~~.0% ~~over that same period.~~ The ~~improvement~~increase ~~in gross margin~~ is primarily ~~due~~related to ~~improved utilization of equipment and pricing which was partially offset by~~ the ~~impact~~amortization of ~~the~~intangibles ~~acquisition~~recorded ofin ~~AWC.~~connection ~~AWC~~with ~~provided $19.8 million of revenues during~~ the ~~six months ended June 30, 2011 and it also increased direct costs by $13~~Merger.~~0 million for the same period for an effective gross margin as a percentage of revenues of~~ 34.4%. AWC’s gross margin as a percentage of revenues is less than our overall Well Services gross margin percentage as AWC’s manufacturing operation has a higher labor component. Gross margin as a percentage of revenues for our Well Services segment for the six months ended June 30, 2011 was 39.6% compared to 26.3% for the six months ended June 30, 2010.

~~Depreciation~~Income ~~expense~~from ~~increased~~operations ~~11.5%~~was to $4517.42 million for the ~~six~~nine months ended ~~June~~September 30, 2011 ~~from~~compared to $4014.79 million for the ~~six~~nine months ended ~~June~~September 30, 2010. The ~~primary~~ increase in ~~depreciation~~income ~~expense~~from operations iswas mainly due to ~~our~~the ~~capital~~increase ~~expenditure~~in ~~programs~~revenues ~~for~~and ~~our~~improved ~~Drilling~~margins ~~Services~~which ~~segment.~~was ~~Depreciation~~partially ~~expense as~~offset aby ~~percentage~~the impairment of ~~revenues~~intangible ~~decreased~~assets toand ~~10.9%~~increases ~~for~~in ~~the~~depreciation, ~~first~~amortization ~~half~~and ~~of 2011~~selling, ~~compared to 13.6% for~~general ~~the~~and ~~first~~administrative ~~half of 2010, due to the noted increases in revenues~~expenses.

~~Selling,~~Our ~~general~~interest ~~and administrative~~ expense was $4331.90 million for the ~~six~~nine months ended ~~June~~September 30, 2011, compared to $2434.20 million for the ~~six~~nine months ended ~~June~~September 30, 2010. ~~Selling,~~Approximately ~~general and administrative expense increased primarily due to an increase in stock based compensation expense, severance expenses and professional and other fees for the six months ended June~~$51.5 ~~30,~~million ~~2011~~of ~~compared~~our todebt ~~the~~was ~~same~~paid ~~period~~in ofconnection ~~the~~with ~~prior year all due principally to~~ the Merger. ~~Stock~~Interest ~~based~~expense ~~compensation~~ for the ~~six~~nine months ended ~~June~~ September 30, 2011 was ~~$6.1 million~~reduced ~~with~~by approximately $51.49 million ofin ~~this amount~~connection ~~relating~~with todebt ~~the~~premium ~~acceleration~~amortization ofand interest ~~stock based compensation~~ expense ~~associated~~for ~~with~~ the ~~Merger and~~nine ~~was $3.0 million in the same period of the prior year. The six~~ months ended ~~June~~September 30, ~~2011~~ 2010 includes ~~approximately~~amortization ~~$4.6 million of severance~~ expense ~~relating to the separation~~ of ~~certain~~ ~~executives~~deferred ~~after~~financing ~~the~~costs ~~Merger.~~of ~~Professional and other fees for the six months ended June 30, 2011 included~~ $7.1.7 million. ofInterest ~~costs~~expense ~~related~~for to the ~~Merger.~~three ~~The six~~ months ended ~~June~~ September 30, 2011 ~~also includes~~included approximately $12.75 million of allocated ~~general~~interest ~~and~~charges ~~administrative expenses~~ from our Parent ~~and other increases related to additional operating activities~~. ~~As a percentage of revenues, selling,~~ ~~general and administrative expense was 10.5% for the six months ended June 30, 2011 compared to 8.1% for the same period in the prior year.~~

Other expense was $330,000 for the nine months ended September 30, 2011 compared to other expense of $2.5 million for the nine months ended September 30, 2010. Results for the nine months ended September 30, 2010 include a pre-tax non-cash loss of $1.5 million on the sale of an investment in a private oil and gas company that was assumed as part of an acquisition in 2006.

Income tax expense for the nine months ended September 30, 2011 was $9.7 million or (68.6)% of our net loss before income taxes compared to an income tax benefit of $3.6 million or 16.9% of our net loss before income taxes from 2010. The change in the tax rate is principally the result of valuation allowances on losses generated in the United States and variances in withholding taxes from foreign operations as a percentage of pretax income (loss).

We had a net loss of $23.8 million for the nine months ended September 30, 2011, compared to net loss of $17.5 million for the nine months ended September 30, 2010 due to the foregoing reasons.

The net loss attributed to common stockholders for the nine months ended September 30, 2011 and 2010 was $24.2 and $19.4 million after $375,000 and $1.9 million in preferred stock dividends, respectively. The preferred stock dividend related to 36,393 preferred shares of $1,000 par value at 7.0%.

~~During~~The ~~the~~following ~~six~~table ~~months~~compares ~~ended~~revenues ~~June 30,~~and ~~2011,~~income ~~we recorded a $5.1~~(loss) ~~million~~from ~~loss~~operations onfor ~~the~~each ~~impairment~~ of ~~intangible~~ ~~assets.~~our Inbusiness segments ~~connection~~for ~~with~~ the ~~Merger,~~nine amonths ~~$5.1 million~~ended ~~value was assigned to the Allis-Chalmers tradename. Following the Merger~~September 30, ~~Seawell~~2011 and ~~its~~2010. ~~subsidiaries,~~Income ~~including~~(loss) from ~~us, have~~operations ~~begun~~consists ~~operating~~of ~~under~~our ~~the~~revenues ~~name~~less ~~Archer.~~direct Ascosts, ~~a result~~selling, itgeneral ~~was~~and ~~determined~~administrative ~~that there was no material~~expenses, ~~remaining~~impairment ~~value~~of ~~associated~~intangible ~~with~~assets, ~~the~~depreciation ~~Allis-Chalmers~~and ~~tradename.~~amortization:

Amortization expense for the six months ended June 30, 2011 increased $4.3 million to $6.6 million compared to $2.3 million for the six months ended June 30, 2010. The increase is primarily related to the amortization of intangibles recorded in connection with the merger.


	Successor		Predecessor
	Seven Months		Two Months
	Ended		Ended
	September 30,		February 28,
	2011		2011			Combined 2011		Predecessor 2010		Change
Revenues:
Drilling Services	$	442,723	$	106,050		$	548,773	$	428,977	$	119,796
Well Services		70,549		20,835			91,384		44,325		47,059

Total	$	513,272	$	126,885		$	640,157	$	473,302	$	166,855


Income (Loss) from Operations:
Drilling Services	$	16,694	$	(9,943	)	$	6,751	$	11,276	$	(4,525	)
Well Services		10,334		109			10,443		3,651		6,792

Total	$	27,028	$	(9,834	)	$	17,194	$	14,927	$	2,267

Income from operations was $5.8 million for the six months ended June 30, 2011 compared to $3.4 million for the six months ended June 30, 2010. The increase in income from operations was mainly due to the increase in revenues and improved margins which was partially offset by the impairment of intangible assets and increases in depreciation, amortization and selling, general and administrative expenses.

Our interest expense was $21.7 million for the six months ended June 30, 2011, compared to $22.1 million for the six months ended June 30, 2010. Approximately $51.5 million of our debt was paid in connection with the Merger. Interest expense includes amortization expense of deferred financing costs of $366,000 and $1.1 million for the six months ended June 30, 2011 and 2010, respectively. Interest expense for the six months ended June 30, 2011 included approximately $1.3 million of allocated interest charges from our Parent and was reduced by approximately $1.1 million in connection with debt premium amortization.

Other income was $101,000 for the six months ended June 30, 2011 compared to other expense of $1.8 million for the six months ended June 30, 2010. Results for the first half of 2010 include a pre-tax non-cash loss of $1.5 million on the sale of an investment in a private oil and gas company that was assumed as part of an acquisition in 2006.

Income tax expense for the six months ended June 30, 2011 was $6.3 million or (39.9)% of our net loss before income taxes compared to an income tax benefit of $5.2 million or 25.8% of our net loss before income taxes from 2010. The change in the tax rate is principally the result of valuation allowances on losses generated in the United States and variances in withholding taxes from foreign operations as a percentage of pretax income (loss).

We had a net loss of $22.0 million for the six months ended June 30, 2011, compared to net loss of $14.9 million for the six months ended June 30, 2010 due to the foregoing reasons.

The net loss attributed to common stockholders for the six months ended June 30, 2011 and 2010 was $22.4 and $16.2 million after $375,000 and $1.3 million in preferred stock dividends, respectively. The preferred stock dividend related to our 36,393 shares of $1,000 par value preferred shares at 7.0%.

The following table compares revenues and income (loss) from operations for each of our business segments for the six months ended June 30, 2011 and 2010. Income (loss) from operations consists of our revenues less direct costs, selling, general and administrative expenses, impairment of intangible assets, depreciation and amortization:

	Successor		Predecessor
	Four Months		Two Months
	Ended		Ended
	June 30,		February 28,			Combined			Predecessor
	2011		2011			2011			2010			Change
Revenues:
Drilling Services	$	247,277	$	106,050		$	353,327		$	277,441		$	75,886
Well Services		43,587		20,835			64,422			21,573			42,849
Total	$	290,864	$	126,885		$	417,749		$	299,014		$	118,735
Income (Loss) from Operations:
Drilling Services	$	8,488	$	(9,943	)	$	(1,455	)	$	4,307		$	(5,762	)
Well Services		7,179		109			7,288			(925	)		8,213
Total	$	15,667	$	(9,834	)	$	5,833		$	3,382		$	2,451

Drilling Services

Revenues for the Drilling Services segment for the ~~six~~nine months ended ~~June~~September 30, 2011 were $~~353~~548.38 million, an increase of 27.49% compared to $~~277~~429.40 million in revenues for the ~~six~~nine months ended ~~June~~ September 30, 2010. ~~Loss~~Income from operations for the nine months ended September 30, 2011 was $16.5 8 million compared to ~~income~~$11.3 million in the nine months ended September 30, 2010. The revenue increase was due to our investment in new equipment, increased utilization and rig rates in Argentina and Bolivia and improved pricing and utilization for our directional drilling services, underbalanced services, rental services and tubular services domestically. The decrease in income from operations was mainly due to: (1) allocations of Merger related costs consisting of accelerated stock based compensation expense of $3.9 million, severance expense of $3.4 million and professional and other fees of $5.1 million for the nine months ended September 30, 2011; (2) allocations of $5.9 million of Parent general and administration charges; (3) decrease in utilization and pricing for our land drilling services in Brazil; (4) a $2.9 million non-cash loss recorded in the ~~six~~nine months ended ~~June~~September 30, ~~2010~~2011 on an intangible asset impairment (5) increased compensation costs and other inflationary cost increases in Argentina and Brazil and (6) an increase of $11.8 million, ~~The~~or ~~revenue~~20.2%, in depreciation and amortization for the nine months ended September 30, 2011 compared to the same period of the prior year. The increase in depreciation and amortization expense was ~~due~~the result of capital expenditure programs and Merger related adjustments to the fair value of intangible assets.

Well Services

Revenues for the Well Services segment for the nine months ended September 30, 2011 were $91.4 million, an increase of 106.2% compared to $44.3 million in revenues for the nine months ended September 30, 2010. Income from operations was $10.4 million for the nine months ended September 30, 2011 compared to $3.7 million in the nine months ended September 30, 2010. The acquisition of AWC provided our Well Services segment with $28.8 million of revenues and $6.3 million of operating income during the nine months ended September 30, 2011 compared to $6.8 million of revenues and $2.4 million of operating income during the nine months ended September 30, 2010. AWC was acquired in July 2010. We also had improved utilization and pricing for our coil tubing units. Partially offsetting the improved results in the nine months ended September 30, 2011 were: (1) allocations of Merger related costs consisting of accelerated stock based compensation expense of $1.5 million, severance expense of $1.2 million and professional and other fees of $2.0 million for the nine months ended September 30, 2011; (2) allocations of $1.8 million of Parent general and administration charges; (3) a $2.2 million non-cash loss recorded in the nine months ended September 30, 2011 on an intangible asset impairment and (4) an increase of $2.6 million, or 36.7%, in depreciation and amortization for the nine months ended September 30, 2011 compared to the same period of the prior year. The increase in depreciation and amortization expense was the result of capital expenditure programs and Merger related adjustments to the fair value of intangible assets.

our investment in new equipment, increased utilization and rig rates in Argentina and Bolivia and improved pricing and utilization for our directional drilling services, underbalanced services, rental services and tubular services domestically. The increase in loss from operations was mainly due to: (1) allocations of merger related costs consisting of accelerated stock based compensation expense of $3.9 million, severance expense of $3.4 million and professional and other fees of $5.1 million for the six months ended June 30, 2011; (2) allocations of $1.3 million of Parent general and administration charges; (3) decrease in utilization and pricing for our land drilling services in Brazil; (4) a $2.9 million non-cash loss recorded in the six months ended June 30, 2011 on an intangible asset impairment and (5) an increase of $7.0 million, or 18.1%, in depreciation and amortization for the six months ended 2011 compared to the same period of the prior year. The increase in depreciation and amortization expense was the result of capital expenditure programs and Merger related adjustments to the fair value of intangible assets.

Well Services

Revenues for the Well Services segment for the six months ended June 30, 2011 were $64.4 million, an increase of 198.6% compared to $21.6 million in revenues for the six months ended June 30, 2010. Income from operations increased $8.2 million and resulted in income from operations of $7.3 million for the six months ended June 30, 2011 compared to a loss from operations of $925,000 in the six months ended June 30, 2010. The acquisition of AWC provided our Well Services segment with $19.8 million of additional revenues and $4.0 million of additional operating income during the first half of 2011. We also had improved utilization and pricing for our coil tubing units. Partially offsetting the improved results in the six months ended June 30, 2011 were: (1) allocations of merger related costs consisting of accelerated stock based compensation expense of $1.5 million, severance expense of $1.2 million and professional and other fees of $2.0 million for the six months ended June 30, 2011; (2) allocations of $400,000 of Parent general and administration charges (3) a $2.2 million non-cash loss recorded in the six months ended June 30, 2011 on an intangible asset impairment and (4) an increase of $2.0 million, or 44.8%, in depreciation and amortization in the first half of 2011 compared to the first half of 2010. The increase in depreciation and amortization expense was the result of capital expenditure programs and Merger related adjustments to the fair value of intangible assets.

Liquidity

Our on-going capital requirements arise primarily from our need to service our debt, to acquire and maintain equipment, to fund our working capital requirements and to complete acquisitions. Our primary sources of liquidity are proceeds from Parent contributions and cash flows from operations. Cash flows from operations are expected to be our primary source of liquidity in fiscal 2011. We had cash and cash equivalents ~~and restricted cash~~ of $1710.2 million at ~~June~~ September 30, 2011 compared to $20.9 million at December 31, 2010.

Operating Activities

During the ~~six~~nine months ended ~~June~~ September 30, 2011, our operating activities provided $2117.0 million in cash. Our net loss for the ~~six~~nine months ended ~~June~~September 30, 2011 was $2223.08 million. Non-cash expenses totaled $6291.50 million during the first ~~six~~nine months of 2011 primarily consisting of $5279.0 7 million of depreciation and amortization, $5.1 million on an impairment of intangible assets, $6.1 million for share based compensation expense, $366,000 in amortization of deferred financing fees, $~~587~~925,000 loss on sale of property and equipment ~~net of $1.1 million of debt premium amortization~~ and $~~799~~369,000 for deferred ~~income~~ income taxes ~~related~~relating to timing differences net of $1.9 million of debt premium amortization.

During the ~~six~~nine months ended ~~June~~September 30, 2011, changes in operating assets and liabilities used $1950.5 2 million in cash, principally due to an increase in accounts receivable of $30.93 million, an increase in inventories of 714.92 million, an increase in prepaid expenses and other assets of $95.69 million, ~~offset~~a bydecrease ~~an increase~~ in ~~accounts~~accrued ~~payable~~interest of $1412.70 million, offset by an increase in ~~accrued expenses~~accounts payable of $117.54 million and an increase in accrued ~~salaries,~~expenses ~~benefits and payroll taxes~~ of $25.7 1 million. Accounts receivable, inventory, accounts payable, ~~accrued expense~~ and accrued ~~salaries, benefits~~expense ~~and payroll taxes~~ increases primarily related to the increase in our activity in the first ~~six~~ nine months of 2011. The increase in prepaid expenses primarily relates to additional prepaid taxes in Argentina and Brazil. The decrease in accrued interest was due to the scheduled interest payments on our senior notes.

During the ~~six~~nine months ended ~~June~~September 30, 2010, our operating activities provided $2126.59 million in cash. Our net loss for the ~~six~~nine months ended ~~June~~September 30, 2010 was $1417.95 million. Non-cash expenses totaled $3861.85 million during the first ~~six~~nine months of 2010 consisting of $4365.04 million of depreciation and amortization, $34.04 million for share -based compensation expense, $1.17 million in amortization of debt issuance costs, $1.5 million loss on the sale of an investment, $~~0.8 million~~150,000 of losses from asset disposals, $~~260~~409,000 equity in loss of unconsolidated affiliates, partly offset by ~~deferred~~ deferred income tax benefit of $1012.80 million related to timing differences.

During the ~~six~~nine months ended ~~June~~September 30, 2010, changes in operating assets and liabilities used $17.1 million in cash, principally due to an increase in accounts receivable of $30.4 million, an increase in inventories of $2.7 million, a decrease in accrued interest of $8.9 million and a decrease in other long-term liabilities of $0.7 million, offset in part by an increase in accounts payable of $8.4 million, a decrease in prepaid expenses and other current assets of $8.0 million, an increase in accrued expenses of $5.5 million, an increase in ~~cash~~accrued salaries, ~~principally~~benefits and payroll taxes of $2.4 million and a decrease in other assets of $1.3 million. Accounts receivable, inventory, accounts payable, accrued expenses and accrued salaries, benefits and payroll taxes increased primarily due to the increase in our activity in the first nine months of 2010. The decrease in prepaid expense assets was the result of current operations in Argentina utilizing the prepaid taxes that existed at December 31, 2009, offset by a non-cash increase in prepaid expenses from the financing of $2.6 million of insurance premiums. Accrued interest decreased due to the scheduled interest payment on our senior notes in July of 2010.

Investing Activities

During the nine months ended September 30, 2011, we used $67.1 million in investing activities, consisting of $70.9 million for capital expenditures, $1.2 million cash contribution into our investment in our Saudi Arabia joint venture, offset by $5.2 million of proceeds from equipment sales. Included in the $70.9 million for capital expenditures were $59.3 million for additional equipment in our Drilling Services segment and $11.6 million for additional equipment in our Well Services segment. A majority of our equipment sales relate to items “lost in hole” or “damaged beyond repair” by our customers.

During the nine months ended September 30, 2010, we used $76.4 million in investing activities, consisting of $50.9 million for capital expenditures, $18.2 million net for the acquisition of AWC, $13.0 million for other assets, offset in part by $5.3 million of proceeds from equipment sales and $368,000 from the sale of an investment. Included in the $50.9 million for capital expenditures were $44.5 million for additional equipment in our Drilling Services segment and $6.4 million for additional equipment in our Well Services segment. A majority of our equipment sales relate to items “lost in hole” or “damaged beyond repair” by our customers. The increase in other assets was primarily due to $12.7 million of advance payments made toward the construction of two drilling rigs. A majority of our equipment sales relate to items “lost in hole” or “damaged beyond repair” by our customers.

due to an increase in accounts receivable of $25.8 million, an increase in inventory of $2.4 million and a decrease in other long-term liabilities of $466,000, offset in part by an increase in accounts payable of $10.8 million, a decrease in prepaid expenses and other current assets of $8.8 million, an increase in accrued expenses of $3.8 million, an increase in accrued salaries, benefits and payroll taxes of $1.9 million and a decrease in other assets of $0.8 million. Accounts receivable, inventory, accounts payable, accrued expenses and accrued salaries, benefits and payroll taxes increased primarily due to the increase in our activity in the first six months of 2010. The decrease in prepaid expense assets was the result of current operations in Argentina utilizing the prepaid taxes that existed at December 31, 2009.

Investing Activities

During the six months ended June 31, 2011, we used $50.4 million in investing activities, consisting of $48.3 million for capital expenditures, $3.8 million increase in restricted cash relating to deposits at a financial institution to secure outstanding letters of credit and a $1.2 million cash contribution into our investment in our Saudi Arabia joint venture, offset by $2.9 million of proceeds from equipment sales. Included in the $48.3 million for capital expenditures were $41.5 million for additional equipment in our Drilling Services segment and $6.8 million for additional equipment in our Well Services segment. A majority of our equipment sales relate to items “lost in hole” or “damaged beyond repair” by our customers.

During the six months ended June 30, 2010, we used $38.1 million in investing activities, consisting of $31.0 million for capital expenditures, $10.1 million for other assets, offset by $2.6 million of proceeds from equipment sales and $368,000 from the sale of an investment. Included in the $31.0 million for capital expenditures were $27.2 million for our Drilling Services segment and $3.8 million for additional equipment in our Well Services segment. The increase in other assets was primarily due to $10.0 million of advance payments made toward the construction of a drilling rig. A majority of our equipment sales relate to items “lost in hole” or “damaged beyond repair” by our customers.

Financing Activities

During the ~~six~~nine months ended ~~June~~September 30, 2011, financing activities provided $2139.93 million in cash. In connection with the Merger, we received approximately $71.4 million in funding from our Parent. Proceeds were mainly used to pay off debt, debt related interest and ~~merger~~Merger related expenses. The ~~merger~~ ~~related~~Merger related expenses were primarily for legal and professional fees and change of control provisions. An additional $319.09 million in funding was subsequently received from our Parent. We repaid $50143.1 3 million in borrowings under long-term debt facilities and borrowed $130.0 million under our Parent’s Multicurrency Term and Revolving Facility. We had a net cash outlay of $1.8 million related to the payment of payroll taxes as a result of net exercises of restricted stock vestings and paid $637,000 in preferred stock dividends.

During the ~~six~~nine months ended ~~June~~September 30, 2010, financing activities ~~used~~provided $623.98 million in cash. We borrowed $36.5 million under our revolving credit facility and borrowed an additional $4.0 million under a long-term debt facility and repaid $914.46 million in borrowings under long-term debt facilities. We also incurred $189,000 in debt issuance costs related to an amendment to our revolving credit facility to modify our loan covenants, and we paid $1.39 million in preferred stock dividends. In addition, we financed our renewal of $2.46 million in insurance policy premiums and issued $2.0 million of our common stock in the acquisition of AWC in non-cash transactions.

At ~~June~~September 30, 2011, we had $461.6 million in outstanding indebtedness, of which $454.7 million ~~was~~ was long-term debt and $6.9 million iswas due within one year.

In January 2006 and August 2006, we closed on private offerings, to qualified institutional buyers pursuant to Rule 144A under the Securities Act of 1933, of $160.0 and $95.0 million aggregate principal amount of our senior notes, respectively. The senior notes are due January 15, 2014 and bear interest at 9.0%. The proceeds were used to fund the acquisitions of Specialty Rental Tools, Inc. and DLS, to repay existing debt and for general corporate purposes. In June 2009, we closed on a tender offer in which we purchased $30.6 million aggregate principal of our 9.0% senior notes for a total consideration of $650 per $1,000 principal amount. In connection with the Merger and based on actively traded prices of our senior notes, we increased the fair value of the 9.0% senior notes to $1,022 per $1,000 principal amount. In May 2011, pursuant to the terms of change of control provisions in the indentures governing the senior notes and as a result of the Merger, holders had the right to require us to purchase, all or a portion of such holders’ ~~notes~~Notes. We Accordingly we purchased $1.8 million aggregate principal of our 9.0% senior notes for a total consideration of $1,010 per $1,000 principal amount. In July 2011, pursuant to the terms of the senior notes indenture, we redeemed $125.0 million aggregate principal of our 9.0% senior notes for a total consideration of $1,023 per $1,000 principal amount. In connection with this redemption we have drawn $130.0 million on our Parent’s $1.2 billion Multicurrency Term and Revolving Facility. The $1.2 billion facility is divided into tranches with $350.0 million having a final maturity date of December 31, 2011 and the remainder having a final maturity date of November 11, 2015. The interest rate is based on LIBOR plus a margin.

As part of our acquisition of DLS, we assumed various bank loans with floating interest rates based on LIBOR plus a margin

~~Merger~~ and ~~based~~terms onranging ~~actively~~from ~~traded~~2 ~~prices~~to of5 years. ~~our~~The ~~senior~~weighted ~~notes,~~average weinterest ~~increased~~rate ~~the~~on these ~~fair~~loans ~~value~~was ~~of the 8~~2.50% ~~senior~~as ~~notes~~of ~~to $1~~December 31,~~070~~ ~~per~~2010. ~~$1,000~~The ~~principal~~outstanding amount. Indue ~~May 2011,~~under ~~pursuant~~these tobank ~~the~~loans ~~terms of~~as ~~change~~ of ~~control~~September 30, ~~provisions~~2011 ~~in the indentures governing the senior notes~~ and ~~as a result of the Merger~~December 31, we2010 ~~purchased~~was $~~92,000~~0 ~~aggregate~~and ~~principal of our 8.5% senior notes for a total consideration of~~ $1350,~~010 per $1,~~000, ~~principal amount~~respectively.

WeOn ~~had a $90.0~~February ~~million~~15, ~~revolving~~2008, ~~line~~through ofour ~~credit~~DLS ~~with~~subsidiary ain ~~final~~Argentina, ~~maturity~~we ~~date~~entered ofinto ~~April 26,~~a ~~2012~~$25.0 million ~~pursuant~~import tofinance afacility ~~revolving~~with ~~credit~~a bank. ~~agreement~~Borrowings ~~that~~under ~~contained~~this ~~customary~~facility ~~events~~were ofused ~~default~~to ~~and~~fund ~~financial covenants~~a ~~and~~portion ~~limited~~of ~~our~~the ~~ability~~purchase toprice ~~incur~~of ~~additional~~the ~~indebtedness, make capital expenditures, pay~~new ~~dividends~~drilling orand ~~make~~service ~~other~~rigs ~~distributions,~~ordered ~~create~~for ~~liens~~our ~~and~~Drilling ~~sell~~Services ~~assets~~segment. ~~Effective~~The ~~December 31,~~loan ~~2009, we~~is ~~amended~~repayable ~~the~~over four ~~leverage~~years ~~and~~in ~~interest~~equal ~~coverage~~semi-annual ~~ratio~~installments ~~covenants~~beginning ofone ~~the~~year ~~revolving~~after ~~credit~~each ~~agreement. This~~disbursement ~~amendment~~with ~~relaxed~~ the final ~~required~~principal ~~financial~~payment ~~ratios~~due ~~for~~not ~~the~~later ~~quarter~~than ~~ended December~~March 3115, ~~2009~~2013. ~~and for~~The ~~each~~import offinance ~~the~~facility ~~quarters~~is unsecured inand ~~2010.~~contains ~~Our~~customary ~~obligations~~events ~~under~~of ~~the~~default ~~amended~~and financial covenants and ~~restated~~limits ~~credit~~DLS’ ~~agreement~~ability ~~are~~to ~~secured~~incur byadditional ~~substantially~~indebtedness, ~~all~~make ofcapital ~~our~~expenditures, ~~assets~~create ~~located~~liens inand ~~the~~sell ~~United States~~assets. We were in compliance with all debt covenants as of ~~December~~September 3130, ~~2010.~~2011 Asand of December 31, 2010~~, we had $36~~.~~5 million~~ ofThe bank ~~borrowings~~loan ~~outstanding~~rates ~~and~~are ~~$4.1 million~~based inon ~~outstanding~~LIBOR ~~letters~~plus ofa ~~credit under our revolving credit facility~~margin. The weighted- average interest rate was 75.82% at September 30, 2011 and 4.2% at December 31, 2010. The ~~revolving~~outstanding ~~line~~amount ofunder the import finance ~~credit~~facility ~~was~~as ~~repaid~~of September 30, 2011 and ~~terminated~~December 31, in2010 ~~connection~~was ~~with~~$9.8 million ~~the~~and ~~Merger~~$14.4 million, respectively.

As part of our acquisition of DLS, we assumed various bank loans with floating interest rates based on LIBOR plus a margin and terms ranging from 2 to 5 years. The weighted average interest rate on these loans was 2.0% as of December 31, 2010. The outstanding amount due under these bank loans as of June 30, 2011 and December 31, 2010 was $0 and $350,000, respectively.

On February 15, 2008, through our DLS subsidiary in Argentina, we entered into a $25.0 million import finance facility with a bank. Borrowings under this facility were used to fund a portion of the purchase price of the new drilling and service rigs ordered for our Drilling Services segment. The loan is repayable over four years in equal semi-annual installments beginning one year after each disbursement with the final principal payment due not later than March 15, 2013. The import finance facility is unsecured and contains customary events of default and financial covenants and limits DLS’ ability to incur additional indebtedness, make capital expenditures, create liens and sell assets. We were in compliance with all debt covenants as of June 30, 2011 and December 31, 2010. The bank loan rates are based on LIBOR plus a margin. The weighted average interest rate was 4.2% at June 30, 2011 and December 31, 2010. The outstanding amount under the import finance facility as of June 30, 2011 and December 31, 2010 was $11.5 million and $14.4 million, respectively.

On February 9, 2010, through our DLS subsidiary, we entered into a $4.0 million term loan facility. The loan is repayable in semi-annual installments beginning April 14, 2011 and bears interest at 8.5% per annum. The final maturity date is April 14, 2014 and the loan is unsecured. The outstanding amount under the term loan facility as of ~~June~~September 30, 2011 and December 31, 2010 was $3.4 million and $4.0 million, respectively.

In 2010, we obtained insurance premium financings in the aggregate amount of $2.9 million with a fixed weighted-average interest rate of 4.8%. Under terms of the agreements, amounts outstanding are paid over eight and 11 month repayment schedules. The outstanding balance of these notes was approximately $0 and $1.0 million at ~~June~~September 30, 2011 and December 31, 2010, respectively. We also have amounts outstanding under a capital lease that will expire in 2013. As of September 30, 2011, the amount outstanding under the capital lease was $61,000.

Off Balance Sheet Arrangements

We have no off balance sheet arrangements, other than normal operating leases and employee contracts, 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 have $34.87 million of outstanding letters of credit ~~that~~under ~~are~~our ~~secured~~Parent’s byMulticurrency ~~deposits~~Term atand aRevolving ~~financial institution~~Facility. ~~We do not guarantee obligations of any~~ ~~unconsolidated entities.~~

Critical Accounting Policies

Please see our Form 10-K/A for a description of other policies that are 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 Management’s Discussion and Analysis of Financial Condition and Results of Operations where such policies affect our reported and expected financial results. No material changes to such information have occurred during the nine months ended September 30, 2011.

policies affect our reported and expected financial results. No material changes to such information have occurred during the six months ended June 30, 2011.

Recently Issued Accounting Standards

For a discussion of new accounting standards, see the applicable section in Note 1 to our Unaudited Consolidated Condensed Financial Statements included in “Item 1. Financial Statements.”

Forward-Looking Statements

This quarterly report 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 such forward-looking statements 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. These factors include, but are not limited to, the following:

	•		the impact of the weak economic conditions and the future impact of such conditions on the oil and gas industry and demand for our services;

	•		unexpected future capital expenditures (including the amount and nature thereof);

	•		unexpected difficulties in integrating our operations as a result of any significant acquisitions;

	•		adverse weather conditions in certain regions;

	•		the impact of political disturbances, war, or terrorist attacks and changes in global trade policies;

	•		the availability (or lack thereof) of capital to fund our business strategy and/or operations;

	•		the potential impact of the loss of one or more key employees;

	•		the effect of environmental liabilities that are not covered by an effective indemnity or insurance;

	•		the impact of current and future laws;

	•		the impact of customer defaults and related bad debt expense;

	•		the potential impairment in the carrying value of goodwill and other acquired intangible assets;

	•		the risks associated with doing business outside the United States, including currency exchange rates; the effects of competition; and

	•		the effects of our indebtedness, which could adversely restrict our ability to operate, could make us vulnerable to general adverse economic and industry conditions, could place us at a competitive disadvantage compared to competitors that have less debt, and could have other adverse consequences

Further information about the risks and uncertainties that may impact us are described under “Item 1A—Risk Factors” in our Form 10-K/A. You should read those sections carefully. You should not place undue reliance on forward-looking statements, which speak only as of the date of this quarterly report. 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 quarterly report or currently unknown facts or conditions or the occurrence of unanticipated events.


ITEM 4.		CONTROLS AND PROCEDURES.

(a) Evaluation of Disclosure Controls and Procedures.

As of the end of the period covered by this quarterly report, we have evaluated the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15(e) and 15d — 15(e) of the Securities Exchange Act of 1934, as amended, or the Exchange Act. Management recognizes that any disclosure controls and procedures no matter how well designed and operated, can only provide reasonable assurance of achieving their objectives and management necessarily applies its judgment in evaluating the cost-benefit relationship of possible controls and procedures. This evaluation was carried out under the supervision and with the participation of our management, including our chief executive officer and chief financial officer. Based on this evaluation, these officers concluded that, for the period ending ~~June~~September 30, 2011, our ~~disclosure~~ disclosure controls and procedures were not effective to provide a reasonable assurance regarding ~~the~~ the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles because of a material weakness in our internal control over financial reporting described below.

Material Weakness in Internal Control over Financial Reporting

A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of the Company’s annual or interim financial statements will not be prevented or detected on a timely basis. Based on this assessment, management has concluded that we did not maintain effective internal control over financial reporting for the period ending ~~June~~September 30, 2011, because of a material weakness relating to accounting for income taxes. Specifically, we did not maintain effective controls over the identification and proper accounting treatment of the calculation and valuation of deferred tax assets. This material weakness resulted in a material misstatement of our income tax expense, deferred tax asset, net loss and accumulated deficit with accompanying notes and the restatement of our consolidated financial statements for the year ended December 31, 2010 as discussed in Note 2 to the consolidated financial statements included in our Form 10-K/A. Additionally, this deficiency could result in misstatements of the aforementioned accounts and disclosures that would result in a material misstatement of the consolidated financial statements that would not be prevented or detected.

Plan for Remediation of Material Weakness

Management has developed a plan to remediate the material weakness noted above. Controls over the preparation of tax calculations and associated deferred tax balances have been enhanced through the implementation of external advisory services from an independent source, under the oversight of management. In the third quarter the Company ~~has~~ hired a dedicated employee with tax expertise to oversee this area, along with enhanced procedural and review controls.

(b) Changes in Internal Control Over Financial Reporting.

Except as described above, there were not any changes in our internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) during the period covered by this report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION


ITEM 1.		LEGAL PROCEEDINGS

See Note 11 to our Unaudited Consolidated Condensed Financial Statements included in “Item 1. Financial Statements.”


ITEM 6.		EXHIBITS

(a) The exhibits listed on the Exhibit Index immediately following the signature page of this Quarterly Report on Form 10-Q are filed as part of this report.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized on ~~August 31,~~November 22, 2011.



		Allis-Chalmers Energy Inc.
		(Registrant)

		/s/ Christoph Bausch
		Christoph Bausch
		Chief Financial Officer

EXHIBIT INDEX

31.1*		Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*		Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1*		Certification of the Chief Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS*		XBRL Instance Document
101.SCH*		XBRL Taxonomy Extension Schema Document
101.CAL*		XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF*		XBRL Taxonomy Extension Definition Linkbase Document
101.LAB*		XBRL Taxonomy Extension Label Linkbase Document
101.PRE*		XBRL Taxonomy Extension Presentation Linkbase Document
101.DEF*		XBRL Taxonomy Extension Definition Linkbase Document


*		Filed herewith

Table of Contents

Table of Contents

Filing Compare · Allis Chalmers Energy Inc.