YPF S.A. — Audit Report / Information 2008

Apr 7, 2010

	YPF Holdings, Inc. and Subsidiaries (A Wholly Owned Subsidiary of YPF S.A.) Consolidated Financial Statements as of and for the Years Ended December 31, 2008 and 2007, and Independent Auditors’ Report

4-19-2008 12:20 pm CT vpaehler – CSP requested visual gridlines (as opposed to printing gridlines) be toggled off in all tables. He also said to change cites to DT standard, Partner previously requested all have quotes.

4-16-2008 8:00 pm CT vpaehler – CSP requested “December 31,” above years in financials. Also changed balance sheet from 2 page spread to DT continued/concluded style per CSP.

4/15/08 910p c strammell - Per CSP: Please retain all non-zeros in tables as dashes and spell out state names. DO NOT DELETE DASH ON PAGE 12 OF FOOTNOTES - PER ANDREA.

YPF HOLDINGS, INC. AND SUBSIDIARIES

(A Wholly Owned Subsidiary of YPF S.A.)

TABLE OF CONTENTS

Page

INDEPENDENT AUDITORS’ REPORT 1

CONSOLIDATED FINANCIAL STATEMENTS AS OF AND FOR THE
YEARS ENDED DECEMBER 31, 2008 AND 2007:

Balance Sheets 2–3

Statements of Operations 4

Statements of Changes in Stockholder’s Equity (Deficit) and Comprehensive Loss 5

Statements of Cash Flows 6

Notes to Consolidated Financial Statements 7–26

INDEPENDENT AUDITORS’ REPORT

To the Board of Directors of
YPF Holdings, Inc. and Subsidiaries:

We have audited the accompanying consolidated balance sheets of YPF Holdings, Inc. and subsidiaries (the “Company”), a wholly owned subsidiary of YPF S.A., as of December 31, 2008 and 2007, and the related consolidated statements of operations, changes in stockholder’s equity (deficit) and comprehensive loss, and cash flows for the years then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, such consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Company as of December 31, 2008 and 2007, and the consolidated results of its operations and its cash flows for the years then ended in conformity with accounting principles generally accepted in the United States of America.

March 4, 2010

YPF HOLDINGS, INC. AND SUBSIDIARIES

(A Wholly Owned Subsidiary of YPF S.A.)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

AS OF AND FOR THE YEARS ENDED DECEMBER 31, 2008 AND 2007

1. ORGANIZATION

YPF Holdings, Inc. (“Holdings” or the “Company”) was incorporated in Delaware, U.S.A., on July 31, 1996, and holds investments in certain subsidiaries. The Company is engaged in oil and gas exploration activities in the Gulf of Mexico.

YPF S.A. (YPF or the “Parent”) owns 100% of the Company’s shares. YPF is a subsidiary of Repsol YPF.

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Principles of Consolidation — The consolidated financial statements of the Company include the financial statements of the Company and its wholly owned subsidiaries (collectively referred to hereafter as “subsidiaries”) Tierra Solutions Inc. (“Tierra”); Maxus Energy Corporation (“Maxus”); Maxus International Energy Company (MIEC); Maxus (U.S.) Exploration Company (“Maxus US”); CLH Holdings, Inc. (CLH); and Gateway Coal Company (“Gateway”). All intercompany transactions have been eliminated.

Use of Estimates — The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company’s consolidated financial statements include amounts that are based on management’s best estimates and judgments. Actual results could differ from these estimates.

Cash and Cash Equivalents — Short-term, highly liquid investments that have an original maturity of three months or less and deposits in money market mutual funds that are readily convertible into cash are considered cash equivalents.

Fair Value of Financial Instruments — Financial instruments are composed of accounts receivable, accounts payable, and notes payable. The carrying value of such financial instruments is equivalent to their fair value.

Oil and Gas Producing Activities — The Company follows the “successful efforts” method of accounting for its oil and gas exploration and production operations. Accordingly, exploratory costs, excluding the costs of exploratory wells, are charged to expense as incurred. No costs of drilling exploratory wells, including stratigraphic test wells, as of December 31, 2008 and 2007, have been capitalized, pending determination as to whether the wells have found proved reserves, which justify commercial development. The Company recognized dry hole costs of approximately $0 and $9.1 million in 2008 and 2007, respectively.

Capitalized costs relating to producing properties are depleted on the unit-of-production method. Proved developed reserves are used in computing unit rates for drilling and development costs and total proved reserves for depletion rates of leasehold, platform, and pipeline costs.

The Company reviews its proved oil and gas properties for impairment when changes in circumstances indicate that the carrying amount of such properties may not be recoverable.

The capitalized costs related to acquisitions of properties with unproved reserves are reviewed periodically and at least annually by management to ensure the carrying value is recoverable. If necessary, a valuation allowance is provided, by a charge against earnings, to reflect the impairment of unproved acreage.

In March 2007, the Company transferred its working interest in an exploratory well drilled in February 2004 for approximately $8.5 million, to a subsidiary of Repsol YPF while retaining an overriding royalty interest. The transaction freed the Company from the additional capital investment necessary to develop the prospect while maintaining a revenue interest. An appraisal well originally planned for 2005 was delayed to await the results of drilling on an adjacent block in which the Company also holds an overriding royalty interest. Drilling in that block occurred in the third quarter of 2007 and resulted in all capitalized costs in the amount of $9.1 million related to this prospect being fully impaired in 2007.

The Company sanctioned the Neptune prospect on June 29, 2005. The initial field development involved seven subsea producing wells and a central floating production facility located in Green Canyon 613. In February 2008, the decision was made to escalate the sixth well to the second quarter of 2008 from the fourth quarter of 2008, eliminate the seventh well from the project, and acquire a new 3D seismic survey. The seismic survey acquisition and final processing was completed by the end of the second quarter of 2009. The Company’s working interest in the Neptune Prospect is 28%.

On March 16, 2008 the Company was notified that a structural anomaly was identified in one of the pontoons of the Neptune Platform and start-up activities were suspended.  The facility was fully inspected and the anomalies were found to be isolated to the three pontoons.  Repairs to remediate the structural anomalies were substantially completed by June 30, 2008, at a gross cost to the partnership of approximately $40.0 million and a net cost of $4.3 million to Maxus.  Maxus is currently pursuing recoupment through applicable insurance and certain construction warranties of $4.1 million in net costs. First production was achieved on July 6, 2008, from the first well. As of December 31, 2008, the platform was in production from six wells.  Approximately $212.5 million has been incurred by the Company on the appraisal program and development project as of December 31, 2008.

The Neptune operator and the partnership approved the drilling of one additional well (SB-02) in the second quarter of 2009 to produce the M9 and M10 reservoirs. During the fourth quarter of 2009, the SB‑02 well was deepened to reach the M12 reservoir where additional reserves were discovered. The partnership agreed to postpone the M9 and M10 completion, and put the M12 reservoir on production.  Net expenditures by the Company for the SB-02 well during 2009 were approximately $5.3 million for drilling and completion costs.  Additional net expenditures by the Company are expected to be approximately $12.5 million.  The partnership is currently reevaluating the technical and economic merits of drilling an additional well, as well as identifying sidetrack and recompletion opportunities for consideration in 2010 and later.

Asset Retirement Obligations — The Company recognizes liabilities associated with the eventual retirement of tangible long-lived assets, upon the acquisition, construction, and development of the assets. The Company records the fair value of a liability for an asset retirement obligation in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset.

The Company recognizes depletion expense on the additional capitalized costs, accretion expense as the present value of the future asset retirement obligation increases with the passage of time, and the impact, if any, of changes in estimates of the liability. The following table sets forth a reconciliation of the beginning and ending asset retirement obligation (in thousands):

The retirement date for Neptune wells and platform abandonment was extended to 2029 based on internal reserve analysis. This created a reduction of asset retirement obligation and accretion as of December 31, 2008.

Other Property, Plant, and Equipment — The Company’s other property, plant, and equipment consisting of software, furniture, fixtures, and installations have been depreciated using the straight-line method, with depreciation rates based on the estimated useful life of each class of property. Normal maintenance and repairs to all other fixed assets have been charged to expense as incurred.

Restricted Cash — The restricted cash balance primarily represents security deposits for letters of credit. The letters of credit are used as security with various governmental agencies and as support for bonds posted with governmental agencies or insurance companies.

Income Taxes — Income taxes are recognized for (a) the amount of taxes payable or refundable for the current year and (b) deferred tax assets and liabilities for the future tax consequences of events that have been recognized in the Company’s consolidated financial statements or tax returns. Deferred tax assets and liabilities are measured based upon enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date. Deferred tax assets are reduced by a valuation allowance when it is more likely than not that some portion, or all, of the deferred tax assets will not be realized.

Revenue Recognition — Oil and gas revenues from the Company’s interests in producing wells are recognized as title and physical possession of the oil and gas passes to the purchaser.

Accumulated Other Comprehensive Income (Loss)— The Company records other comprehensive income or loss due to unrealized gains and losses relating to other postretirement and postemployment benefits liability.

New Accounting Pronouncements — In September 2006, the Financial Accounting Standards Board (FASB) issued FASB Statement No. 157, Fair Value Measurements. FASB Statement No. 157 defines fair value, establishes a framework for measuring fair value, and requires enhanced disclosures regarding fair value measurement. FASB Statement No. 157 does not add any new fair value measurements, but it does change current practice and is intended to increase consistency and comparability in such measurements. The provisions of FASB Statement No. 157 became effective beginning January 1, 2008. The adoption of FASB Statement No. 157 did not have a material impact on the Company’s consolidated financial statements. In February 2007, the FASB issued FASB Statement No. 159, The Fair Value Option for Financial Assets and Financial Liabilities— including an amendment of FASB Statement No. 115. FASB Statement No. 159 provides an entity with the option, at specified election dates, to measure certain financial assets and liabilities and other items at fair value, with changes in fair value recognized in earnings as those changes occur. FASB Statement No. 159 also establishes presentation and disclosure requirements that include displaying the fair value of those assets and liabilities for which the entity elected the fair value option on the face of the balance sheet and providing management’s reasons for electing the fair value option for each eligible item. The provisions of FASB Statement No. 159 became effective beginning January 1, 2008, and the Company did not elect to change how it records assets and liabilities.

In May 2007, the FASB issued FASB Staff Position (FSP) No. FIN 48-1, Definition of Settlement in FASB Interpretation No. 48 (“FIN 48-1”), which amends FASB Interpretation FIN 48 and provides guidance concerning how an entity should determine whether a tax position is “effectively,” rather than the previously required “ultimately,” settled for the purpose of recognizing previously unrecognized tax benefits. In addition, FIN 48-1 provides guidance on determining whether a tax position has been effectively settled. The guidance in FIN 48-1 is effective upon the initial January 1, 2007, adoption of FIN 48. Companies that have not applied this guidance must retroactively apply the provisions of this FSP to the date of the initial adoption of FIN 48. The Company has adopted FIN 48-1 and no retroactive adjustments were necessary.

In December 2007, the FASB issued FASB Statement No. 160, Noncontrolling Interests in Consolidated Financial Statements— an amendment of ARB No. 51. FASB Statement No. 160 establishes accounting and reporting standards for the non-controlling interest in a subsidiary and for the deconsolidation of a subsidiary. The statement clarifies that a non-controlling interest in a subsidiary is an ownership interest in the consolidated entity that should be reported as equity in the consolidated financial statements. FASB Statement No. 160 also requires consolidated net income to be reported at amounts that include the amounts attributable to both the parent and the non-controlling interest. The provisions of FASB Statement No. 160 become effective for fiscal years beginning on or after December 15, 2008. Management does not expect the adoption of FASB Statement No. 160 to have a material impact on its financial statements.

In December 2007, the FASB issued revised FASB Statement No. 141, Business Combinations. Among other items, FASB Statement No. 141(R) requires an acquirer to recognize the assets acquired, the liabilities assumed, and any non-controlling interest in the acquiree at the acquisition date, measured at their fair values as of that date, with limited exceptions as specified in the statement. This statement also requires the acquirer in a business combination achieved in stages to recognize the identifiable assets and liabilities, as well as the non-controlling interest in the acquiree, at the full amounts of their fair values. The provisions of FASB Statement No. 141(R) become effective for fiscal years, and interim periods within those fiscal years, beginning on or after December 15, 2008. Management does not expect the adoption of FASB Statement No. 141(R) to have a material impact on its financial statements.

In February 2008, the FASB issued FSP No. FAS 157-2, Effective Date of FASB Statement No. 157 (“FSP FAS 157-2”), which delays the effective date of FASB Statement No. 157 for all nonfinancial assets and nonfinancial liabilities, except those that are recognized or disclosed at fair value in the financial statements on at least an annual basis, until fiscal years beginning after November 15, 2008. The Company does not expect the adoption of FSP FAS 157-2 to have a material impact on its consolidated financial statements.

In March 2008, the FASB issued FASB Statement No. 161, Disclosures about Derivative Instruments and Hedging Activities — an amendment of FASB Statement No. 133. FASB Statement No. 161 requires enhanced disclosures to help investors better understand the effect of an entity’s derivative instruments and related hedging activities on its financial position, financial performance, and cash flows. FASB Statement No. 161 is effective for financial statements issued for fiscal years and interim periods beginning after November 15, 2008, with early application encouraged. The Company does not expect the adoption of FASB Statement No. 161 to have a material impact on its consolidated financial statements.

In April 2008, the FASB issued FSP No. FAS 142-3, Determination of the Useful Life of Intangible Assets (“FSP SFAS 142-3”). FSP SFAS 142-3 amends the factors that should be considered in developing renewal or extension assumptions used to determine the useful life of a recognized intangible asset under FASB Statement No. 142, Goodwill and Other Intangible Assets. The intent of FSP SFAS 142-3 is to improve the consistency between the useful life of a recognized intangible asset under FASB Statement No. 142 and the period of expected cash flows used to measure the fair value of the asset under FASB Statement No. 141(R), Business Combinations and other applicable accounting literature. FSP SFAS 142-3 is effective for financial statements issued for fiscal years beginning after December 15, 2008 and must be applied prospectively to intangible assets acquired after the effective date. The Company does not expect the adoption of FSP SFAS 142-3 to have a material impact on its consolidated financial statements.

In May 2008, the FASB issued FASB Statement No. 162, Hierarchy of Generally Accepted Accounting Principles. This statement is intended to improve financial reporting by identifying a consistent framework, or hierarchy, for selecting accounting principles to be used in preparing financial statements of nongovernmental entities that are presented in conformity with GAAP. This statement will be effective 60 days following the U.S. Securities and Exchange Commission’s approval of the Public Company Accounting Oversight Board amendment to AU Section 411, The Meaning of Present Fairly in Conformity with Generally Accepted Accounting Principles. The Company does not expect the adoption of FASB Statement No. 162 to have a material impact on its consolidated financial statements.

In December 2008, the Securities and Exchange Commission released Final Rule, Modernization of Oil and Gas Reporting to revise the existing Regulation S-K and Regulation S-X reporting requirements to align with current industry practices and technological advances. The new disclosure requirements include provisions that permit the use of new technologies to determine proved reserves if those technologies have been demonstrated empirically to lead to reliable conclusions about reserve volumes. In addition, the new disclosure requirements require a company to (a) disclose its internal control over reserves estimation and report the independence and qualification of its reserves preparer or auditor, (b) file reports when a third party is relied upon to prepare reserves estimates or conducts a reserve audit and (c) report oil and gas reserves using an average price based upon the prior 12-month period rather than period-end prices. The disclosures required by this ruling will become effective for the Company for the year ended December 31, 2009.

As of September 30, 2009, the FASB issued the Accounting Standards Codification (ASC) which will become effective for the Company for periods ending on or after September 30, 2009. The ASC is now the source of authoritative U.S. accounting and reporting standards for nongovernmental entities, in addition to guidance issued by the SEC. No changes to accounting standards or guidance resulted from the issuance of the ASC. Any references to accounting guidance in financial statements for periods ending on or after September 30, 2009 will be to the applicable ASC sections.

1. RELATED-PARTY TRANSACTIONS

During 2007, the Company performed geological and geophysical exploration activities and provided payroll and financial services for affiliated companies. As of December 31, 2008 and 2007, the Company had accounts receivable from those affiliated companies related to these services of $17.4 million and $11.6 million, respectively, which are net of an allowance for uncollectible accounts of $0.0 million and $7.6 million, respectively.

Affiliated companies perform geological and geophysical exploration services for the Company. As of December 31, 2008 and 2007, the Company had accounts payable to those affiliated companies related to these services of $7.7 million and $9.7 million, respectively.

On August 1, 2005, the Company entered into a credit agreement payable on demand with YPF. As of December 31, 2007, the principal balance payable to YPF was $187.0 million. The interest rate was the London InterBank Offered Rate (LIBOR) plus 0.4% per annum. As of December 31, 2007, accrued interest on this note amounted to $18.8 million. This note payable was capitalized as paid-in capital on March 31, 2008 (see below).

On November 17, 2006, the Company entered into a credit agreement payable on demand with YPF International S.A. This note was assigned to YPF on September 26, 2007. As of December 31, 2008 and 2007, the principal payable to YPF was $0 million and $69.0 million, respectively. The interest rate was London InterBank Offered Rate (LIBOR) plus 0.4% per annum. As of December 31, 2008 and 2007, accrued interest on this note amounted to $0 million and $4.0 million, respectively. This note payable was capitalized as paid-in capital on March 31, 2008 (see below).

On October 8, 2007, the Company and YPF entered into an agreement that provided for the capitalization as paid-in capital of the notes payable to YPF and its subsidiaries described above and the cancellation of the associated credit agreements. This agreement closed on March 31, 2008, and is effective as of such date, resulting in a total capital contribution of $282.0 million of existing notes payable, including accrued interest.

On July 2, 2007, the Company entered into a credit agreement with YPF International S.A. for an amount up to $235 million that matured on July 1, 2012. The Company pledged the assets of the Neptune Prospect as collateral for this credit agreement. The interest rate was LIBOR plus 3% per annum. As of December 31, 2007, the principal payable to YPF International S.A. was $102.8 million. As of December 31, 2007, accrued interest on this note amounted to $2.6 million. On January 30, 2008, YPF International S.A. assigned this note to YPF. As of December 31, 2008, the principal payable to YPF was $182.3 million and accrued interest on this note amounted to $3.2 million.

On March 19, 2008, YPF contributed $43 million in cash to the Company for the development of the Neptune project and pension funding.

On September 16, 2009 the Company entered into a loan agreement with YPF for $20 million with maturity and repayment due on November 30, 2009. Accrued interest of $0.1 million and principal of $20 million was repaid on November 30, 2009.

On November 27, 2009, YPF made an equity contribution of $35 million in cash to the Company. Of this amount, $20 million was used to pay off the $20 million loan mentioned above plus accrued interest. The remaining $15 million, together with the capitalization of notes payable described above, were contributed for general corporate purposes to allow the Company and its subsidiaries to continue operating at its current and planned levels.

On December 23, 2009, the Company entered into an Assignment and Acceptance Agreement with YPF whereby the principal payable of $189.3 million and accrued interest of $10.3 million as of such date were effectively capitalized as shareholder’s equity for issuance of common stock in the Company.

In December 2009, YPF has committed to contribute up to additional $40 million to the Company in 2010 for the development plan of the Neptune project.

On July 8, 2009 the Company, together with Repsol E&P, Repsol Services Company and Repsol Offshore E&P USA entered into a settlement agreement where, among other things, all affiliated receivable and payable balances for all involved parties were released and discharged. The resulting effect was a transfer to the Repsol entities mentioned above of affiliated receivables of $17.0 million and affiliated payables of $4.2 million in exchange of cash to the Company.

1. EMPLOYEE BENEFIT PLANS

Pensions — The Company had a number of noncontributory defined pension plans covering approximately 2,500 former employees who retired and were receiving an annuity benefit or non-retirees who earned a benefit for service worked and are due a deferred vested benefit at a future date when they reach the requisite age threshold. The plans provide a full retirement benefit when age 62 is reached with an option to take a reduced amount as early as age 55. The pension benefit obligation at the beginning of 2008 totaled $107.9 million with an underfunded position of $28.4 million.

The Company affected an annuitization on March 20, 2008 with a major insurance company which transferred a large portion of these obligations to the insurance company. The Company contributed $41.5 million in cash to the pension trust to address underfunding, transferred this obligation to the insurance company, and recognized $75.4 million in total settlement losses in pension expense. There were $2.5 million in additional pension expenses in 2008 for the supplemental pension benefits plan and normal periodic pension expense for the aforementioned plan.

Current liabilities of $10 million at December 31, 2008 reflect cash amounts to be paid in 2009 to ultimately settle all defined benefit obligations. Noncurrent liabilities of $4.2 million at December 31, 2008 relates to supplemental pension benefits due to 19 former and 4 active executives. This represents benefits which exceed the defined benefit threshold which the Company pays separately and which could not be annuitized. Key information of these plans as of the date of the actuarial report is as follows (in thousands):

The accumulated benefit obligation for all defined benefit pension plans was $14.2 million and $107.9 million at December 31, 2008 and 2007 respectively.

The estimated net loss for the defined benefit plans that will be amortized from accumulated other comprehensive loss into net periodic benefit cost over the next fiscal year is approximately $0.3 million.

The Company no longer sponsors a pension plan for its employees but instead provides a 401(k) plan benefit to address retirement needs. The plan allows for participant contributions of up to 10% of the participant’s annual eligible earnings with a Company matching contribution of $1 for each dollar contributed up to a maximum 6% of participant’s compensation. The plan includes a fixed profit-sharing contribution by the Company equal to 7.5% of the participant contribution. The Company made contributions of $167,007 and $294,000 in 2008 and 2007, respectively.

Other Postretirement and Postemployment Benefits — The Company provides certain health care and life insurance benefits for eligible retired employees and certain insurance and other postemployment benefits for eligible individuals whose employment was terminated by the Company prior to their normal retirement. The Company accrues the estimated cost of retiree benefit payments, other than pensions, during employees’ active service periods. Employees became eligible for these benefits if they met minimum age and service requirements. The Company accounts for benefits provided after employment but before retirement by accruing the estimated cost of postemployment benefits when the minimum

service period is met, payment of the benefit is probable, and the amount of the benefit can be reasonably estimated. The Company’s policy is to fund other postretirement and postemployment benefits as claims are incurred. Key information as of December 31, 2008 and 2007 is as follows (in thousands):

The estimated net loss for the other postretirement plans that will be amortized from accumulated other comprehensive income into net benefit cost over the next fiscal year is approximately $1.7 million.

1. For measurement purposes, plan assets and liabilities, as applicable, were valued as of December 31, 2008 and 2007, respectively.

For measurement purposes, a 9% annual rate of increase in the per capita cost of covered health care benefits was assumed for 2009. The rate is assumed to decrease by 0.3% each year to 4.5% for 2024 and remain level thereafter.

For measurement purposes, a 9% annual rate of increase in the per capita cost of covered health care benefits was assumed for 2008. The rate is assumed to decrease by 1% each year to 5% for 2012 and remain level thereafter.

Assumed health care trend rates have a significant effect on the amounts reported for the health care plan. A one-percentage point change in assumed health care cost trend rates would have the following effects (in thousands):

Estimated future benefit payments are as follows:

The Company expects to make cash contributions to its pension trusts of $7.1 million in 2009. Expected retiree medical payments for 2009 are $2.6 million.

The Company has decreased its postemployment liability for medical and prescription drug insurance by $19.9 million by effectively eliminating the Company subsidy of these costs for inactive employees who qualify for Medicare.

The Company recognized the subsidy available under the Medicare Prescription Drug Improvement and Modernization Act of 2003, and engaged Mercer to prepare a scope and filing. The application was approved on November 11, 2009 for payment setup in 2010.

1. INCOME TAXES

Deferred income taxes and benefits are provided for differences between the consolidated financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Significant deferred tax assets and liabilities are related primarily to net operating loss carryforwards, postretirement benefit costs, and litigation and environmental costs. Deferred tax balances as of December 31, 2008, are as follows (in thousands):

A valuation allowance has been provided for the net deferred tax assets because their future realization is not currently deemed more likely than not by management.

At December 31, 2008, the Company had $798.0 million of net operating loss carryforwards, which will begin to expire in 2022.

At December 31, 2008, the Company had alternative minimum tax credits of $15.2 million that carry forward indefinitely and are available to reduce future regular tax liability to the extent they exceed the related tentative minimum tax otherwise due.

1. COMMITMENTS and LIABILITIES

Amounts have been provided for various contingencies involving the Company. The estimated probable amounts recorded take into consideration the probability of occurrence, based on management’s expectations and on the opinion of legal counsel.

The major components of reserves as of December 31, 2008 and 2007, are as follows (in thousands):

	2008		2007
Current — environmental liabilities	$ 61,070		$ 43,770
Noncurrent:
Environmental liabilities	124,856		77,563
Black lung benefits act liabilities	8,581		9,025
Legal liabilities	23,011		18,611
Miscellaneous liabilities (1)	999		1,043
Total reserves — noncurrent	157,447		106,242
Total	$218,517		$150,012
(1) Miscellaneous liabilities are not significant individually.

Environmental Liabilities—Environmental liabilities are recorded when environmental assessments and/or remediation are probable and material and such costs to the Company can be reasonably estimated. The Company’s estimate of environmental assessment and/or remediation costs to be incurred is based on either (1) detailed feasibility studies of remediation approach and cost for individual sites or (2) the Company’s estimate of costs to be incurred based on historical experience and publicly available information based on the stage of assessment and/or remediation of each site. As additional information becomes available regarding each site or as environmental remediation standards change, the Company revises its estimate of costs to be incurred in environmental assessment and/or remediation.

Laws and regulations relating to health and environmental quality in the United States affect the operations of the Company as a consequence of the labor of remediation assumed by Tierra for compromises engaged with environmental authorities mainly in aspects referred to Diamond Shamrock Chemicals Company (“Chemicals”), which was sold to Occidental Petroleum Corporation and is presently an Occidental Petroleum Corporation subsidiary. These laws and regulations set various standards regulating certain aspects of health and environmental quality; provide for penalties and other liabilities for the violation of such standards; and establish, in certain circumstances, remedial obligations.

The Company believes that its policies and procedures in the areas of pollution control, product safety, and occupational health are adequate to prevent unreasonable risk of environmental and other damage, and of resulting financial liability, in connection with its business. Some risk of environmental and other damage is, however, inherent in particular operations of the Company, and as discussed below, Maxus and Tierra could have certain potential liabilities associated with operations of Maxus’s former chemical subsidiary. The Company cannot predict which environmental legislation or regulations will be enacted in the future or how existing or future laws or regulations will be administered or enforced. Compliance with more stringent laws or regulations, as well as more vigorous enforcement policies of the regulatory agencies, could, in the future, require material expenditures by the Company for the installation and operation of systems and equipment for remedial measures, possible dredging requirements, and in certain other respects. Also, certain laws allow for recovery of natural resource damages from responsible parties and ordering the implementation of interim remedies to abate an imminent and substantial endangerment to the environment. Potential expenditures for any such actions cannot be reasonably estimated.

In connection with the sale of Maxus’s former chemical subsidiary, Chemicals, to Occidental Petroleum Corporation (together with its subsidiary Occidental Chemical Corporation, “Occidental”), Maxus agreed in 1986 to indemnify Chemicals and Occidental from and against certain liabilities relating to the business or activities of Chemicals prior to the September 4, 1986 closing date (the “Closing Date”), including certain environmental liabilities relating to certain chemical plants and waste disposal sites used by Chemicals prior to the Closing Date.

At December 31, 2008, reserves for the environmental contingencies discussed herein totaled approximately $185.9 million. Management believes it has adequately reserved for all environmental contingencies that are probable and can be reasonably estimated as of such time; however, changes in circumstances could result in changes, including additions, to such reserves in the future.

In the following discussion concerning plant sites and third-party sites, references to the Company include, as appropriate and solely for ease of reference, references to Maxus and Tierra. Maxus and Tierra are both wholly owned subsidiaries of the Company.

Newark, New Jersey — A consent decree, previously agreed upon by the U.S. Environmental Protection Agency (EPA), the New Jersey Department of Environmental Protection and Energy (DEP), and Occidental, as successor to Chemicals, was entered in 1990 by the U.S. District Court of New Jersey for Chemicals’ former Newark, New Jersey agricultural chemicals plant. The approved remedy has been completed and paid for by Tierra pursuant to the above-described indemnification obligation to Occidental. This project is in the operation and maintenance phase. Operating and maintaining such remedy is expected to cost approximately $1.0 million per year, and as of December 31, 2008, the Company has reserved approximately $32.5 million in connection with such activities.

Passaic River/Newark Bay, New Jersey — Studies have indicated that sediments of the Newark Bay watershed, including the Passaic River adjacent to the former Newark plant, are contaminated with hazardous chemicals from many sources. These studies suggest that the older and more contaminated sediments located adjacent to the former Newark plant generally are buried under more recent sediment deposits. Maxus, on behalf of Occidental, negotiated an agreement with the EPA under which Tierra has conducted further testing and studies to characterize contaminated sediment and biota in a six-mile portion of the Passaic River near the plant site. The stability of the sediments in the entire six-mile portion of the Passaic River study area was also examined as a part of Tierra’s studies. While some work remains, these studies were substantially completed in 2005. In addition:

• Maxus and Tierra have been conducting similar studies under their own auspices for several years.

• The EPA and other agencies are addressing the lower Passaic River in a joint federal, state, local, and private sector cooperative effort designated as the Lower Passaic River Restoration Project (PRRP). Tierra, along with 72 other entities (as of December 31, 2008), has agreed to participate in a remedial investigation and feasibility study (RIFS) in connection with the PRRP. The parties are discussing the possibility of further work with the EPA. The entities that have agreed to fund the RIFS have negotiated allocations of responsibility among themselves based on a number of considerations.

• In 2003, the DEP issued a directive (“Directive No. 1”) to Occidental and Maxus and certain of their respective related entities, as well as other third parties. Directive No. 1 seeks to address natural resource damages allegedly resulting from almost 200 years of historical industrial and commercial development of the lower 17 miles of the Passaic River and a part of its watershed. Directive No. 1 asserts that the named entities are jointly and severally liable for the alleged natural resource damages without regard to fault. The DEP has asserted jurisdiction in this matter even though all or part of the lower Passaic River has been designated as a Superfund site and is a subject of the PRRP. Directive No. 1 calls for the following actions: interim compensatory restoration, injury identification, injury quantification, and value determination. Maxus and Tierra responded to Directive No. 1 setting forth good-faith defenses. Settlement discussions between the DEP and the named entities have been held; however, no agreement has been reached or is assured.

• In 2004, the EPA and Occidental entered into an administrative order on consent (AOC) pursuant to which Tierra (on behalf of Occidental) has agreed to conduct testing and studies to characterize contaminated sediment and biota in Newark Bay. The initial fieldwork on this study, which includes testing in Newark Bay, has been substantially completed. Discussions with the EPA regarding additional work that might be required are under way.

In December 2005, the DEP issued a directive to Tierra, Maxus, and Occidental directing said parties to pay the state of New Jersey’s costs of developing a Source Control Dredge Plan focused on allegedly dioxin-contaminated sediment in the lower six-mile portion of the Passaic River. The development of this plan is estimated by the DEP to cost approximately $2.3 million. This directive was issued even though this portion of the lower Passaic River has been designated as a Superfund site and is a subject of the PRRP. The DEP has advised the recipients that (1) it is engaged in discussions with the EPA regarding the subject matter of the directive and (2) the recipients are not required to respond to the directive until otherwise notified.

• Also in December 2005, the DEP sued the Company, Tierra, Maxus, and several affiliated entities, in addition to Occidental, in connection with dioxin contamination allegedly emanating from Chemicals’ former Newark plant and contaminating the lower 17-mile portion of the Passaic River, Newark Bay, other nearby waterways, and surrounding areas. The DEP seeks unspecified damages for investigation, cleanup, and removal of alleged contamination; for loss of use of property; and for other matters. The DEP also seeks punitive damages. The defendants have made responsive pleadings and/or filings.

• In June 2007, the EPA released a draft Focused Feasibility Study (FFS). The FFS outlines several proposals for early remedial action in the Passaic River, which range from no action (which would result in comparatively little cost) to extensive dredging and capping in the lower eight miles of the river (which, according to the draft FFS, the EPA estimated could cost from $900.0 million to $2.3 billion), and are all described by the EPA as involving proven technologies that could be carried out in the near term without extensive research. At this time, no remedy has been selected, nor has action been demanded of any party. Tierra, in conjunction with the other parties of the PRRP group, submitted comments on the draft FFS to the EPA, as did a number of other interested parties. EPA held a meeting of the Contaminated Sediment Technical Advisory Group (CSTAG) in April 2008, and as a result of CSTAG comments has engaged in further study and modeling; EPA is presently awaiting

results which will be further considered by CSTAG, and expects to issue a report in the first quarter of 2010 and reach a decision in the second quarter of 2010. Tierra will respond to any further EPA proposal as may be appropriate at that time.

• In August 2007, the National Oceanic and Atmospheric Administration (NOAA), as one of the Federal Natural Resources (Trustees), sent a letter to the parties of the PRRP group, including Tierra and Occidental, requesting that the group enter into an agreement to conduct a cooperative assessment of natural resources damages in the Passaic River and Newark Bay. The PRRP group has responded through its common counsel to request that discussions relating to such an agreement be postponed until 2008, due in part to the pending FFS proposal by the EPA. In November 2008, Tierra, along with a subset of PRRP group members, has entered into an agreement with the Trustees to engage in an assessment for one year; in November 2009, Tierra declined to extend this agreement citing concerns arising from litigation with NJDEP. In January 2008, NOAA sent a letter to the Company, its subsidiary CLH Holdings Inc., and other entities designating each as a potentially responsible party (PRP) with respect to this matter.

• In June 2008, the EPA, Occidental, and Tierra entered into an AOC pursuant to which Tierra (on behalf of Occidental) will undertake a removal action of sediment from the Passaic River in the vicinity of the former Diamond Alkali facility. This action will result in the removal of approximately 200,000 cubic yards of sediment. The Company has reserved $80.0 million with respect to this matter, to be fully funded through a trust mechanism by 2012. The first phase, which will encompass the removal of 40,000 cubic yards, is scheduled for completion within 30 months.

• As of December 31, 2008, there is a total of approximately $90.8 million reserved in connection with the foregoing matters related to the Passaic River, Newark Bay, and the surrounding area. This amount consists of estimated costs for studies and remediation the Company has agreed to undertake. The Company had previously evaluated alternative remediation scenarios for the lower eight miles of the Passaic River, which resulted in an increase of approximately $24.0 million to the reserve in 2007; this figure has been revised to $80.0 million with respect to the June 2008 AOC. The development of new information on the imposition of natural resource damages, or remedial actions differing from the scenarios that have been evaluated, or changes in the Company’s share estimates, could result in additional costs to be incurred.

Hudson County, New Jersey — Until 1972, Chemicals operated a chromite ore processing plant in Kearny, New Jersey (the “Kearny Plant”). According to the DEP, wastes from these ore processing operations were used as fill material at a number of sites in and near Hudson County. Occidental, as successor to Chemicals, signed an AOC with the DEP in 1990 for investigation and remediation work at certain chromite ore residue sites in Kearny and Secaucus, New Jersey. Tierra, on behalf of Occidental, is presently performing the work, and Tierra is funding Occidental’s share of the cost of investigation and remediation of these sites. Tierra, on behalf of Occidental, is providing financial assurance in the amount of $20.0 million for performance of the work. While Tierra has participated in the cost of studies and is implementing interim remedial actions and conducting remedial investigations, the ultimate cost of remediation is uncertain. Tierra submitted its remedial investigation reports to the DEP in 2001 and the DEP continues to review these reports. In addition:

• In May 2005, the DEP took two actions in connection with the chrome sites in Hudson and Essex Counties. First, the DEP issued a directive to Maxus, Occidental, and two other chromium manufacturers (the “Respondents”), directing them to arrange for the cleanup of chromite ore residue at three sites in Jersey City and the conduct of a study by paying the DEP a total of $19.5 million. While the Company believes that Maxus is improperly named and there is little or no evidence that Chemicals’ chromite ore residue was sent to any of these sites, the DEP claims the Respondents are jointly and severally liable without regard to fault. Second, the DEP filed a lawsuit against Occidental and two other entities in state court in Hudson County, seeking, among other things, cleanup of various sites where chromite ore residue is allegedly located; recovery of past costs incurred by the state at such sites (including in excess of $2.3 million allegedly spent for investigations and studies); and, with respect to certain costs at 18 sites, treble damages. The DEP claims that the defendants are jointly and severally liable, without regard to fault, for much of the damages alleged. In February 2008, the parties reached a conceptual agreement on a possible settlement that remains subject to further agreement on terms and conditions. As a result, the Company reserved $7.1 million.

• Pursuant to a request of the DEP, in the second half of 2006, Tierra and other parties tested the sediments in a portion of the Hackensack River near the former Kearny Plant. Tierra has submitted work plans for additional sampling requested by the DEP and is presently awaiting DEP comments.

• In November 2005, several environmental groups sent a notice of intent to sue the owner of the property adjacent (the “Adjacent Property”) to the former Kearny Plant and five other parties, including Tierra, under the Resource Conservation and Recovery Act. The stated purpose of the lawsuit, if filed, would be to require the noticed parties to carry out measures to abate alleged endangerments to health and the environment emanating from the Adjacent Property. The parties have entered into an agreement that addresses the concerns of the environmental groups, and these groups have agreed, at least for now, not to file suit.

In March 2008, the DEP approved an Interim Response Action Work plan for work to be performed at the Kearny Plant site by Tierra and at the Adjacent Property by Tierra in conjunction with other parties. As a result, the Company has reserved $7.8 million.

As of December 31, 2008, there is a total of approximately $30.2 million reserved in connection with the foregoing chrome-related matters. Soil action levels for chromium in New Jersey have not been finalized, and the DEP continues to review the proposed action levels. The cost of addressing these chrome-related matters could increase depending upon the final soil action levels, the DEP’s response to Tierra’s reports, and other developments.

Painesville, Ohio — From approximately 1912 through 1976, Chemicals operated manufacturing facilities in Painesville, Ohio (the “Painesville Works”). The operations over the years involved several discrete but contiguous plant sites over an area of approximately 1,300 acres. The primary area of concern historically has been Chemicals’ former chromite ore processing plant (the “Chrome Plant”). For many years, the site of the Chrome Plant has been under the administrative control of the EPA, pursuant to an AOC under which Chemicals is required to maintain a clay cap over the Chrome Plant site and to conduct certain ground water and surface water monitoring. Certain other areas have previously been clay-capped, and one specific site, which was a waste disposal site from the mid-1960s until the 1970s, has been encapsulated and is being controlled and monitored.

In 1995, the Ohio Environmental Protection Agency (OEPA) issued its Director’s Final Findings and Order (the “Director’s Order”) by consent, ordering that an RIFS be conducted at the former Painesville Works area. Tierra has agreed to participate in the RIFS as required by the Director’s Order. Tierra submitted the remedial investigation report to the OEPA, which report was finalized in 2003. Tierra is submitting required feasibility reports separately. In addition, the OEPA has approved certain work, including the remediation of specific sites within the former Painesville Works area and work associated with the development plans discussed below (the “Remediation Work”). The Remediation Work has begun. As the OEPA approves additional projects for the site of the former Painesville Works, additional amounts may need to be reserved. More than 10 years ago, the former Painesville Works site was proposed for listing on the National Priority List under the Comprehensive Environmental Response, Compensation and Liability Act of 1980, as amended (CERCLA); however, the EPA has stated that the site will not be listed as long as it is satisfactorily addressed pursuant to the Director’s Order and OEPA’s programs. The site has not been listed. The Company has reserved a total of approximately $7.4 million as of December 31, 2008, for its estimated share of the cost to perform the RIFS, the Remediation Work, and other operation and maintenance activities at this site. The scope and nature of any further investigation or remediation that may be required cannot be determined at this time; however, as the RIFS progresses, the Company will continuously assess the condition of the Painesville Works site and make any changes, including additions, to its reserve as may be required.

Tierra has entered into an agreement with a developer for the possible development and use of all or portions of this site. While the developer is proceeding with its development plans, there can be no assurance that this site will be successfully developed or that any productive use can be made of all or a portion of this site.

Greens Bayou — Pursuant to settlement agreements with the Port of Houston Authority (the “Port”) and other parties, Tierra and Maxus are participating (on behalf of Chemicals) in the remediation of property adjoining Chemicals’ former Greens Bayou facility where DDT and certain other chemicals were manufactured. Additionally, the parties have entered into negotiations with the federal and state Natural Resources Trustees concerning natural resources damages resulting from the contamination and the remediation, and have entered into a letter agreement setting forth a plan to purchase credits in specified restoration projects, pending reduction to a binding agreement. At December 31, 2008, the Company has reserved approximately $12.7 million for its estimated share of future remediation activities associated with the Greens Bayou facility.

Other Sites — In June 2005, the EPA designated Maxus as a PRP at the Milwaukee Solvay Coke & Gas Site in Milwaukee, Wisconsin. The basis for this designation is Maxus’s alleged status as the successor to Pickands Mather & Co. and Milwaukee Solvay Coke Co., companies that the EPA has asserted are former owners or operators of such site. Preliminary work in connection with the RIFS with respect to this site commenced in the second half of 2006. Maxus has reserved approximately $2.55 million as of December 31, 2008, for its estimated share of the costs of the RIFS. Maxus lacks sufficient information to determine additional exposure or costs, if any, it might have with respect to this site.

The Company has completed remediation activities at its former Tuscaloosa, Alabama facility. The Company has added a reserve of $6.5 million to address operation and maintenance activities for the future, estimated at approximately $200,000 annually.

Maxus has agreed to defend Occidental, as successor to Chemicals, with respect to the Malone Services Company Superfund Site in Galveston County, Texas. This site is a former waste disposal site where Chemicals is alleged to have sent waste products prior to September 1986. It is the subject of enforcement activities by the EPA. Although Occidental is one of many PRPs that have been identified and have agreed to an AOC, Tierra (which is handling this matter on behalf of Maxus) presently believes the degree of Occidental’s alleged involvement as successor to Chemicals is relatively small.

Chemicals has also been designated as a PRP by the EPA under CERCLA with respect to a number of third-party sites where hazardous substances from Chemicals’ plant operations allegedly were disposed or have come to be located. Numerous PRPs have been named at substantially all of these sites. At several of these, Chemicals has no known exposure. Although PRPs are typically jointly and severally liable for the cost of investigations, cleanups, and other response costs, each has the right of contribution from other PRPs, and as a practical matter, cost sharing by PRPs is usually effected by agreement among them. At a number of these sites, the ultimate response cost and Chemicals’ share of such costs cannot be estimated at this time. At December 31, 2008, the Company has reserved approximately $2.8 million in connection with its estimated share of costs related to these sites.

Black Lung Benefits Act Liabilities—The Black Lung Benefits Act provides monetary and medical benefits to miners disabled with black lung disease, and also provides benefits to the dependents of deceased miners if black lung disease caused or contributed to the miner’s death. As a result of the former operations of its coal-mining subsidiaries, the Company is required to provide insurance of this benefit to former employees and their dependents. The Company maintains a reserve to cover its estimate of these obligations.

Legal Liabilities and Proceedings — In 2001, the Texas State Comptroller assessed a Maxus subsidiary approximately $1.4 million in Texas state sales taxes for the period from September 1, 1995 through December 31, 1998, plus penalty and interest. In August 2004, the administrative law judge issued a decision affirming approximately $1.0 million of such assessment, plus penalty and interest. The Company believes the decision is erroneous, but has paid the revised tax assessment, penalty, and interest (a total of approximately $1.8 million) under protest. Maxus filed suit in Texas state court in December 2004, challenging the administrative decision. The matter will be reviewed by a trial de novo in the court action.

In 2002, Occidental sued Maxus and Tierra in state court in Dallas, Texas, seeking a declaration that Maxus and Tierra have the obligation under the agreement, pursuant to which Maxus sold Chemicals to Occidental, to defend and indemnify Occidental from and against certain historical obligations of Chemicals, including claims related to Agent Orange and vinyl chloride monomer, notwithstanding the fact that said agreement contains a 12-year cutoff for defense and indemnity obligations with respect to most litigation. Tierra was dismissed as a party, and the matter was tried in May 2006. Following trial, judgment was entered against Maxus. Maxus appealed to the Dallas Court of Appeals, and the judgment at trial was affirmed in February 2008. Maxus petitioned the Supreme Court of Texas for review, but was notified in July 2008 that the petition was denied. No further appeal is anticipated and payment is pending upon final determination of costs. The judgment awarded Occidental declaratory relief, approximately $2.5 million, and attorney’s fees and costs. In December 2006, the trial court set the amount of Maxus’s supersedeas bond, and Maxus posted such bond, in the amount of approximately $14.9 million, including post judgment interest at the rate of 8% per annum. As of December 31, 2008, Maxus had established a reserve of approximately $16.8 million with respect to this matter. In March 2009, Maxus paid over $14.9 million to Occidental. Maxus paid Occidental for expenses incurred for consultants and outside counsel, plus interest on those expenses in September 2009, and remains in discussions with Occidental regarding other amounts due. In developments related to the Agent Orange litigation, which may be affected by this lawsuit, the U.S. district court granted the defendants’ motions for summary judgment in a number of these cases. The plaintiffs appealed the judgments to the Second Circuit Court of Appeals, which affirmed the summary judgment; in March 2009, the U.S. Supreme Court declined to hear a further petition. All pending Agent Orange litigation was dismissed in December 2009, and although it is possible that further claims may be filed by unknown parties in the future, no further significant liability is anticipated.

In March 2005, Maxus agreed to defend Occidental, as successor to Chemicals, with respect to an action seeking the contribution of costs incurred in connection with the remediation of the Turtle Bayou waste disposal site in Liberty County, Texas. The plaintiffs alleged that certain wastes attributable to Chemicals found their way to the Turtle Bayou site. Trial for this matter was bifurcated, and in the liability phase, Occidental and other parties were found severally, and not jointly, liable for waste products disposed of at this site. Trial in the allocation phase of this matter was completed in the second quarter of 2007, and following post judgment motions, the court has entered a decision setting Occidental’s liability at 15.96% of those costs incurred by one of the plaintiffs. Maxus has appealed this matter and has posted a supersedeas bond in the amount of approximately $3.1 million. As of December 31, 2008, Maxus has reserved $3.8 million with respect to this matter.

In 2005, Skidmore Energy Company and others (“Skidmore”) have sued Maxus US, a subsidiary of the Company, in state court in Texas. Skidmore claims it was entitled to an assignment of approximately five oil and gas leases in the U.S. Gulf of Mexico. Maxus US denies Skidmore’s claims. Maxus US and Skidmore agreed to submit this matter to binding arbitration; the arbitration hearing was held from October 29 to November 1, 2007, with briefs submitted to the arbitration panel on November 6, 2007. The decision of the arbitration panel, holding that Skidmore should take nothing, was rendered on November 29, 2007; final judgment based upon the arbitration award was entered on March 24, 2009, by the trial court. Skidmore has appealed this entry of judgment; Maxus has made appropriate responsive filings.

Reference should be made to the sections above captioned “Passaic River/Newark Bay, New Jersey” and “Hudson County, New Jersey” for a discussion of certain other litigation.

The Company, including its subsidiaries, is a party to various other lawsuits, the outcomes of which are not expected to have a material adverse effect on the Company’s financial condition. The Company has established reserves for legal contingencies in situations where a loss is probable and can be reasonably estimated.

The Company has entered into various operating agreements and capital commitments associated with the exploration and development of its oil and gas properties, which are not significant, except those of the Neptune Prospect. Total commitments related to the development of the Neptune Prospect, located in the Atwater Valley area, are $7.8 million for 2009, and a minimum pipeline transportation payment obligation of approximately $5.0 million for 2009; $4.0 million for 2010; $3.1 million for 2011; $2.4 million for 2012; $2.0 million for 2013; and $5.3 million thereafter.

1. Subsequent events

The Company entered into two settlements agreements with affiliated companies which include outstanding accounts receivables and accounts payables as well as certain other issues. The Company executed an agreement for an advance payment on January 30, 2009 and received $30 million in February 2009. A final agreement was signed and executed in July 2009 with a final payment of an additional $20 million. The second agreement was executed in July 2008 and the associated payment of $0.6 million received on February 13, 2009.

On December 23, 2009, the Company increased its share capital to $1.1 billion.  This increase of capital was entirely subscribed by the Company's sole shareholder, YPF, pursuant to a Subscription Agreement entered into with the Company on the same date. YPF received 1,110,514 shares of common stock of the Company and contributed, as consideration for the issuance of shares, (i) a loan made by YPF to Maxus dated July 2, 2007, and with an outstanding balance of $192.6 million according to the Credit Balance Agreement entered into on December 17, 2009, and (ii) other advances and cash disbursements made by YPF to the Company from time to time for a total amount of $917.9 million.  The Certificate of Incorporation of the Company was amended accordingly to allow this issuance of shares.

Also on December 23, 2009, and immediately upon the increase of capital mentioned above, the Company's share capital was decreased by $300 million, pursuant to the redemption of 300,000 shares by YPF to the Company to be redeemed and canceled pursuant to a Contribution Agreement. Hence, as of December 23, 2009, the total share capital of the Company is $810.5 million represented by 810,514 shares of common stock of the Company, wholly subscribed by YPF at par value of $.01 per share.

During June 2009, the Company signed appropriate lease and well authorization documents to participate with a 3.5% working interest in the drilling of the Northwood Prospect in Green Canyon Block 945. The net acquisition cost to Maxus was $6.1 million for lease acquisition and rentals. This exploration well has an estimated net drilling cost to Maxus of $4.8 million. The prospect is in the vicinity of several other Maxus properties. The well commenced drilling on June 6, 2009, and the partnership decided to temporarily abandon the well on November 1, 2009. As of December 2009, the Northwood well geological results are being evaluated by the partners and further decisions on future development are still pending.

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