Hess - 10-Q quarterly report FY2010 Q3

     The financial statements included in this report reflect all normal and recurring adjustments which, in the opinion of management, are necessary for a fair presentation of Hess Corporation’s (the Corporation) consolidated financial position at September 30, 2010 and December 31, 2009 and the consolidated results of operations for the three and nine month periods ended September 30, 2010 and 2009 and the consolidated cash flows for the nine month periods ended September 30, 2010 and 2009. The unaudited results of operations for the interim periods reported are not necessarily indicative of results to be expected for the full year.

     These financial statements were prepared in accordance with the requirements of the Securities and Exchange Commission (SEC) for interim reporting. As permitted under those rules, certain notes or other financial information that are normally required by U.S. generally accepted accounting principles (GAAP) have been condensed or omitted from these interim financial statements. These statements, therefore, should be read in conjunction with the consolidated financial statements and related notes included in the Corporation’s Form 10-K for the year ended December 31, 2009. Certain information in the financial statements and notes has been reclassified to conform to the current period presentation.

     Effective January 1, 2010, the Corporation adopted the amended accounting standards that eliminated the consolidation exception for a qualifying special-purpose entity and changed the analysis necessary to determine whether consolidation of a variable interest entity is required. The adoption of these standards resulted in an increase of approximately $10 million to Property, plant and equipment and a corresponding increase to Long-term debt. The debt was repaid during the first quarter of 2010.

     Inventories consist of the following (in millions):

     The Corporation accounts for its investment in HOVENSA L.L.C. (HOVENSA) using the equity method. Summarized financial information for HOVENSA follows (in millions):

     Acquisitions and Divestitures: In September 2010, the Corporation completed the exchange of its interests in Gabon and the Clair Field in the United Kingdom for additional interests of 28.1% and 25.0%, respectively, in the Valhall and Hod fields in Norway. This exchange was accounted for as a business combination and was recorded at fair value. The transaction resulted in a pre-tax gain of $1,150 million ($1,072 million after income taxes) which has been included in Other, net in the Statement of Consolidated Income. The total combined carrying amount of the disposed assets prior to the exchange was $702 million, including goodwill of $65 million.

     In September 2010, the Corporation also acquired, from a different third party, additional interests of 7.85% and 12.5% in the Valhall and Hod fields, respectively, for $507 million in cash. This transaction was accounted for as a business combination. As a result of these third quarter 2010 transactions, the Corporation’s total interests in the Valhall and Hod fields are 64.05% and 62.50%, respectively.

     The following table summarizes the preliminary allocation of the purchase price to the assets and liabilities acquired in these transactions (in millions):

     The preliminary purchase price allocation is subject to normal post-closing adjustments. The allocation of fair value to assets and liabilities was determined using market-related unobservable inputs, which the Corporation believes are consistent with the view of a market participant and are classified as Level 3 fair value measurements. The goodwill recorded equals the deferred tax liability recognized for the differences in book and tax bases of the assets acquired. The goodwill is not expected to be deductible for income tax purposes. The primary reason for these transactions was to acquire long-lived crude oil reserves and future production growth.

     In July 2010, the Corporation agreed to acquire American Oil & Gas Inc. (American Oil & Gas) through the issuance of approximately 8.6 million shares of the Corporation’s common stock in order to increase its acreage position in the Bakken oil play in North Dakota by approximately 85,000 net acres. The transaction, which has been approved by the Boards of Directors of both companies, is subject to certain closing conditions, including the approval of American Oil & Gas shareholders, and is expected to be completed in the fourth quarter of 2010.

     Assets Held for Sale: In March 2010, the Corporation entered into an agreement to sell a package of mature, non-operated natural gas production and transportation assets in the United Kingdom North Sea. These transactions are subject to various regulatory and other approvals. The Corporation has classified all of the properties to be disposed of as held for sale. At September 30, 2010, the carrying amount of these assets totalling $237 million was reported in Other current assets. In addition, asset retirement obligations and deferred income taxes totalling $211 million were reported in Accrued liabilities. In accordance with generally accepted accounting principles, properties classified as held for sale are not depreciated but are subject to impairment testing.

     Asset Impairments: In September 2010, the Corporation recorded a charge of $532 million ($334 million after income taxes) to fully impair the carrying value of its 55% interest in the West Mediterranean Block 1 concession (West Med Block), located offshore Egypt. This interest was acquired in 2006 and included four natural gas discoveries and additional exploration prospects. The Corporation and its partners subsequently explored and further evaluated the area, made a fifth discovery, conducted development planning, and held negotiations with the Egyptian authorities to amend the existing gas sales agreement. In late September 2010, the Corporation and its partners notified Egyptian authorities of their decision to cease exploration activities on the block and to relinquish a significant portion of the block. As a result, the Corporation fully impaired the carrying value of its interests in the West Med Block. The Corporation’s estimated fair value of the West Med Block was determined using market-related unobservable inputs, which the Corporation believes are consistent with the view of a market participant and are classified as Level 3 fair value measurements.

     Capitalized Exploratory Well Costs: The following table discloses the net changes in capitalized exploratory well costs pending determination of proved reserves for the nine months ended September 30, 2010 (in millions):

     Capitalized exploratory well costs charged to expense reported in the table above include $22 million related to the impairment of the West Med Block. The table above excludes $80 million of exploratory well costs which were incurred and subsequently expensed in 2010. Capitalized exploratory well costs greater than one year old after completion of drilling were $1,122 million at September 30, 2010. Approximately 54% of the capitalized well costs in excess of one year relate to the Pony and Tubular Bells projects in the deepwater Gulf of Mexico where development planning is progressing. Approximately 14% relates to Area 54 offshore Libya where commercial analysis and development planning activities are ongoing. Approximately 13% relates to Block WA-390-P offshore Western Australia where further drilling, other appraisal activities and commercial analysis are ongoing. Approximately 7% relates to Block BM-S-22 offshore Brazil where the operator plans to commence drilling a third exploration well in the fourth quarter of 2010. The remainder of the capitalized well costs in excess of one year relates to projects where further drilling is planned or development planning and other assessment activities are ongoing to determine the economic and operating viability of the projects.

     In August 2010, the Corporation issued $1,250 million of 30-year bonds with a coupon of 5.60%. A portion of the proceeds were used to finance the acquisition of the additional interests in the Valhall and Hod fields (see Note 4, “Property, Plant and Equipment”) and the remainder will be used for general corporate purposes.

     In January 2010, the Corporation completed the purchase of $116 million of bonds, due in August 2011. This transaction resulted in a charge of approximately $11 million ($7 million after income taxes).

     Pre-tax foreign currency gains (losses) amounted to the following (in millions):

     Components of net periodic pension cost consisted of the following (in millions):

     In 2010, the Corporation expects to contribute approximately $190 million to its pension plans. Through September 30, 2010, the Corporation had contributed $178 million to its pension plans.

     In the normal course of its business, the Corporation is exposed to commodity risks related to changes in the prices of crude oil, natural gas, refined products and electricity, as well as to changes in interest rates and foreign currency values. In the disclosures that follow these activities are referred to as energy marketing and risk management activities. The Corporation also has trading operations, principally through a 50% voting interest in a consolidated partnership, that are exposed to commodity price risks primarily related to the prices of crude oil, natural gas and refined products.

     Following is a description of the Corporation’s activities that use derivatives as part of their operations and strategies. Derivatives include both financial instruments and forward purchase and sale contracts. Gross notional amounts of both long and short positions are presented in the volume tables below. These amounts include long and short positions that offset in a closed position and have not reached contractual maturity. Gross notional amounts do not quantify risk or represent assets or liabilities of the Corporation, but are used in the calculation of cash settlements under the contracts.

     Energy Marketing Activities: In its energy marketing activities the Corporation sells refined petroleum products, natural gas and electricity principally to commercial and industrial businesses at fixed and floating prices for varying periods of time. Commodity contracts such as futures, forwards, swaps and options together with physical assets, such as storage and pipeline capacity, are used to obtain supply and reduce margin volatility or lower costs related to sales contracts with customers.

     The table below shows the gross volume of the Corporation’s energy marketing commodity contracts outstanding at September 30, 2010:

     The changes in fair value of certain energy marketing commodity contracts that are not designated as hedges are recognized currently in earnings. Revenues from the sales contracts are recognized in Sales and other operating revenues, supply contract purchases are recognized in Cost of products sold and net settlements from financial derivatives related to these energy marketing activities are recognized in Cost of products sold. Net realized and unrealized pre-tax gains on derivative contracts not designated as hedges amounted to $50 million and $5 million for the three months ended September 30, 2010 and 2009, respectively, and $162 million and $86 million for the nine months ended September 30, 2010 and 2009, respectively.

     At September 30, 2010, a portion of energy marketing commodity contracts are designated as cash flow hedges to hedge variability of expected future cash flows of forecasted supply transactions. The length of time over which the Corporation hedges exposure to variability in future cash flows is predominantly two years or less. For contracts outstanding at September 30, 2010, the maximum duration was four years. The Corporation records the effective portion of changes in the fair value of cash flow hedges as a component of Other comprehensive income. Amounts recorded in Accumulated other comprehensive income are reclassified into Cost of products sold in the same period that the hedged item is recognized in earnings. The ineffective portion of changes in fair value of cash flow hedges is recognized immediately in Cost of products sold.

     At September 30, 2010, the after-tax deferred losses relating to energy marketing activities recorded in Accumulated other comprehensive income were $239 million ($303 million at December 31, 2009). The Corporation estimates that approximately $167 million of this amount will be reclassified into earnings over the next twelve months. During the three months ended September 30, 2010 and 2009, the Corporation reclassified losses on an after-tax basis from Accumulated other comprehensive income of $56 million and $199 million, respectively, and $257 million and $453 million for the nine months ended September 30, 2010 and 2009, respectively. The amount reflected in earnings due to hedge ineffectiveness was a gain of less than $1 million for both the three months ended September 30, 2010 and 2009, respectively, and a gain of less than $1 million and a loss of $1 million for the nine months ended September 30, 2010 and 2009, respectively. The fair value of energy marketing cash flow hedge positions decreased by $34 million and $83 million for the three months ended September 30, 2010 and 2009, respectively, and $193 million and $519 million for the nine months ended September 30, 2010 and 2009, respectively. The pre-tax amount of deferred hedge losses is reflected in Accounts payable and the related income tax benefits are recorded as Deferred income tax assets on the balance sheet.

     Corporate Risk Management: Corporate risk management activities include transactions designed to reduce risk in the selling prices of crude oil or natural gas produced by the Corporation or to reduce exposure to foreign currency or interest rate movements. Generally, futures, swaps or option strategies may be used to fix the forward selling price of a portion of the Corporation’s crude oil or natural gas production. Forward contracts may also be used to purchase certain currencies in which the Corporation does business with the intent of reducing exposure to foreign currency fluctuations. These forward contracts comprise various currencies including the British pound and Thai baht. The Corporation has executed interest rate swaps to convert interest payments on certain long term debt from fixed to floating rates.

     The table below shows the gross volume of the Corporate risk management derivative instruments outstanding:

     During 2008, the Corporation closed Brent crude oil cash flow hedges covering 24,000 barrels per day through 2012, by entering into offsetting contracts with the same counterparty. As a result, the valuation of those contracts is no longer subject to change due to price fluctuations. There were no other open hedges of crude oil or natural gas production at September 30, 2010. Hedging activities decreased Exploration and Production Sales and other operating revenue by $134 million for both the three month periods ended September 30, 2010 and 2009 and $398 million for both the nine month periods ended September 30, 2010 and 2009.

     At September 30, 2010, the after-tax deferred losses in Accumulated other comprehensive income relating to the closed Brent crude oil hedges were $720 million ($941 million at December 31, 2009). The Corporation estimates that approximately $335 million of this amount will be reclassified into earnings over the next twelve months. The pre-tax amount of deferred hedge losses is reflected in Accounts payable and the related income tax benefits are recorded as Deferred income tax assets on the balance sheet.

     The Corporation designates interest rate swaps as fair value hedges. Changes in the fair value of interest rate swaps and the hedged fixed rate debt are recorded in Interest expense. For the three and nine months ended September 30, 2010, the Corporation recorded an increase of $4 million and $13 million, respectively, in the fair value of interest rate swaps and a corresponding increase in the carrying value of the hedged fixed rate debt.

     Foreign exchange contracts are not designated as hedges. Gains or losses on foreign exchange contracts are recognized immediately in Other, net in Revenues and non-operating income.

     Net pre-tax gains (losses) on derivative contracts used for Corporate risk management and not designated as hedges amounted to the following (in millions):

     Trading Activities: Trading activities are conducted principally through a trading partnership in which the Corporation has a 50% voting interest. This consolidated entity intends to generate earnings through various strategies primarily using energy commodities, securities and derivatives. The Corporation also takes trading positions for its own account.

     The table below summarizes the gross volume of derivative instruments outstanding relating to trading activities:

     Pre-tax gains (losses) recorded in Sales and other operating revenues from trading activities amounted to the following (in millions):

     Fair Value Measurements: The Corporation determines fair value in accordance with the fair value measurements accounting standard (ASC 820 – Fair Value Measurements and Disclosures), which established a hierarchy that categorizes the sources of inputs, which generally range from quoted prices for identical instruments in a principal trading market (Level 1) to estimates determined using related market data (Level 3).

     When Level 1 inputs are available within a particular market, those inputs are selected for determination of fair value over Level 2 or 3 inputs in the same market. To value Level 2 and 3 derivatives the Corporation uses observable inputs for similar instruments that are available from exchanges, pricing services or broker quotes. These observable inputs may be supplemented with other methods, including internal extrapolation, that result in the most representative prices for instruments with similar characteristics. Multiple inputs may be used to measure fair value, however, the level of fair value for each financial asset or liability presented below is based on the lowest significant input level within this fair value hierarchy.

     The following table provides the Corporation’s financial assets and (liabilities) that are measured at fair value based on this hierarchy (in millions):

     The following table provides changes in financial assets and liabilities that are measured at fair value based on Level 3 inputs (in millions):

     Effective January 1, 2010, the Corporation’s policy is to recognize transfers in and transfers out as of the end of the reporting period. During the nine months ended September 30, 2010, transfers into Level 1 and Level 2 were net assets of $123 million and $121 million, respectively, and transfers out of Level 1 and Level 2 were net assets of $23 million and net liabilities of $271 million, respectively. Transfers into Level 1 and transfers into Level 2 primarily resulted from instruments that became more actively traded as they moved closer to maturity and moved out of Levels 2 and 3, respectively. The remaining transfers into Level 2 and all transfers into Level 3 were due to the increased significance of the lower level inputs to the instrument’s fair value, causing those instruments to move out of Levels 1 and 2.

     In addition to the financial assets and liabilities disclosed in the tables on pages 12 and 13, the Corporation had other short-term financial instruments, primarily cash equivalents and accounts receivable and payable, for which the carrying value approximated their fair value at September 30, 2010 and December 31, 2009. Long-term debt had a carrying value of $5,574 million compared with a fair value of $6,650 million at September 30, 2010, and a carrying value of $4,467 million compared with a fair value of $5,073 million at December 31, 2009.

     The table below reflects the gross and net fair values of the Corporation’s risk management and trading derivative instruments (in millions):

     Credit Risk: The Corporation is exposed to credit risks that may at times be concentrated with certain counterparties or groups of counterparties. Accounts receivable are generated from a diverse domestic and international customer base. The Corporation’s net receivables at September 30, 2010 are concentrated with counterparties as follows: Integrated Oil Companies – 23%, Government Entities – 13%, Manufacturing – 12% and Education and Health Services – 11%. The Corporation reduces its risk related to certain counterparties by using master netting arrangements and requiring collateral, generally cash or letters of credit. The Corporation records the cash collateral received or posted as an offset to the fair value of derivatives executed with the same counterparty. At September 30, 2010 and December 31, 2009, the Corporation is holding cash from counterparties of $187 million and $317 million, respectively. The Corporation has posted cash to counterparties at September 30, 2010 and December 31, 2009 of $5 million and $269 million, respectively.

     At September 30, 2010, the Corporation had a total of $2,540 million of outstanding letters of credit, primarily issued to satisfy margin and collateral requirements. Certain of the Corporation’s agreements also contain contingent collateral provisions that could require the Corporation to post additional collateral if the Corporation’s credit rating declines. As of September 30, 2010, the net liability related to derivatives with contingent collateral provisions was approximately $1,858 million before cash collateral posted of approximately $0.3 million. At September 30, 2010, all three major credit rating agencies that rate the Corporation’s debt had assigned an investment grade rating. If two of the three agencies were to downgrade the Corporation’s rating to below investment grade, as of September 30, 2010, the Corporation would be required to post additional collateral of approximately $337 million.

     The weighted average numbers of common shares used in the basic and diluted earnings per share computations are as follows (in thousands):

     The Corporation issued 2,768,715 stock options and 944,250 shares of restricted stock in the nine months ended September 30, 2010 (3,091,080 and 1,041,530 shares, respectively, for the same period in 2009). The table above excludes the effect of 8,932,000 shares and 5,797,000 shares related to out-of-the money options for the three and nine months ended September 30, 2010, respectively (3,533,000 and 3,893,000 shares, respectively, for the same periods in 2009).

     The table below summarizes changes in equity (in millions):

     The Corporation’s results by operating segment were as follows (in millions):

     Hess Corporation (the Corporation) is a global integrated energy company that operates in two segments, Exploration and Production (E&P) and Marketing and Refining (M&R). The E&P segment explores for, develops, produces, purchases, transports and sells crude oil and natural gas. The M&R segment manufactures refined petroleum products and purchases, trades and markets refined petroleum products, natural gas and electricity. The Corporation reported net income of $1,154 million in the third quarter of 2010, compared with $341 million in the third quarter of 2009. Net income for the third quarter of 2010 included an after-tax gain of $1,072 million relating to an asset exchange and an after-tax charge of $347 million relating to an asset impairment.

     E&P reported earnings of $1,277 million for the third quarter of 2010, compared with income of $397 million in the third quarter of 2009. Reported E&P earnings for the third quarter of 2010 included the after-tax gain and the after-tax impairment charge referred to above. Reported E&P earnings for the third quarter of 2009 include $89 million of after-tax income related to the settlement of the U.S. deepwater royalty dispute. In the third quarter of 2010, the Corporation’s average worldwide crude oil selling price, including the effect of hedging, was $64.81 per barrel compared with $56.07 per barrel in the third quarter a year ago. The Corporation’s average worldwide natural gas selling price was $5.73 per thousand cubic feet (mcf) in the third quarter of 2010 compared with $4.60 per mcf in the same quarter last year. Worldwide crude oil and natural gas production was 413,000 barrels of oil equivalent per day (boepd) in the third quarter of 2010 compared with 420,000 boepd in the same period of 2009.

     The following is an update of significant E&P activities during the third quarter of 2010:

     M&R generated a loss of $38 million for the third quarter of 2010, compared with income of $38 million in the third quarter of 2009, primarily reflecting lower margins. M&R results in the third quarter of 2009 included a benefit of $12 million due to an income tax adjustment relating to refining operations.

     Gulf of Mexico Update: In April 2010, an accident occurred on a deepwater drilling rig at the BP p.l.c. (BP) operated Macondo prospect in the Gulf of Mexico, resulting in loss of life, the sinking of the rig, a significant crude oil spill and a temporary drilling moratorium in the Gulf of Mexico. The Corporation was not a participant in the well. The impact to the Corporation of the drilling moratorium was minimal in the second and third quarters. In June, the Corporation’s only operated rig in the Gulf of Mexico, the Stena Forth, left the Pony prospect on Green Canyon 469, where it was being used to drill an appraisal well, as part of a preexisting farm-out agreement with another operator. The Corporation is planning to resume drilling of the Pony appraisal well in 2011 contingent upon receipt of necessary drilling permits. Additionally, the drilling of a production well at the Shenzi Field, in which the Corporation has a 28% interest, was suspended as a result of the moratorium, which is expected to reduce the Corporation’s 2010 production by approximately 2,000 boepd.

     In October 2010, the drilling moratorium in the Gulf of Mexico was lifted by the United States Department of the Interior’s Bureau of Ocean Energy Management, Regulation and Enforcement (BOEMRE) as it had determined that drilling could resume, provided operators certified compliance with all rules and requirements, including the new drilling and safety rules issued on September 30, 2010. The Corporation is currently evaluating the impact of the new rules and requirements on its activities and operations.

     In September 2010, the BOEMRE issued notices to all lessees in the Gulf of Mexico to establish guidelines that provide a consistent and systematic approach to determine the future utility of idle infrastructure on inactive leases and to ensure all wells, structures and pipelines are decommissioned within established timeframes. The notices to lessees were effective on October 15, 2010. Although the new guidelines will impact the timing and cost of inactive well abandonments on the Corporation’s operated and non-operated blocks, the impact is not expected to be material to its financial condition or results of operations.

     Remediation Plans and Procedures: The Corporation has in place a series of asset-specific emergency response and continuity plans which detail procedures for rapid and effective emergency response and environmental mitigation activities for its global offshore operations. These plans are maintained, reviewed and updated annually to ensure their accuracy and suitability.

     Where appropriate, plans are reviewed and approved by the relevant host government authorities on a periodic basis. The Corporation has a current Oil Spill Response Plan for its Gulf of Mexico operations that has been approved by the BOEMRE. This Plan sets forth expectations for response training, drills and capabilities and the strategies, procedures and methods that we will employ in the event of a spill covering the following topics: spill response organization, incident command post, communications and notifications, spill detection and assessment (including worst case discharge scenarios), identification and protection of environmental resources, strategic response planning, mobilization and deployment of spill response equipment and personnel, oil and debris removal and disposal, the use of dispersants and chemical and biological agents, in-situ burning of oil, wildlife rehabilitation and documentation requirements.

     Responder training and drills are routinely held worldwide to assess and continually improve the effectiveness of the Corporation’s plans. The Corporation’s contractors, service providers, representatives from government agencies and, where applicable, joint venture partners participate in the drills to ensure that emergency procedures are comprehensive and can be effectively implemented.

     To complement internal capabilities, the Corporation maintains membership contracts with oil spill response organizations to provide coverage for its global drilling and production operations. These organizations are Clean Gulf Associates, National Response Corporation (NRC) and Oil Spill Response (OSR). Clean Gulf Associates is a regional spill response organization for the Gulf of Mexico; NRC and OSR are global response corporations and are available to assist the Corporation when needed anywhere in the world. In addition to owning response assets in their own right, these organizations maintain business relationships that provide immediate access to additional critical response support services if required. These owned response assets include nearly 300 recovery and storage vessels and barges, more than 250 skimmers, over 300,000 feet of boom, and significant quantities of dispersants and other ancillary equipment, including aircraft. If we were to request these organizations to obtain additional critical response support services, we would provide the funding for such services and seek reimbursement under our insurance coverages described below. In certain circumstances, the Corporation pursues and enters into mutual aid agreements with other companies and government cooperatives to receive and provide oil spill response equipment and personnel support. It also has representation on the Executive Committee of Clean Gulf Associates and the Board of Directors of OSR, maintaining close associations with these organizations.

     In light of the recent events in the Gulf of Mexico, the Corporation is participating in a number of industry-wide task forces that are studying better ways to assess the risk of and prevent offshore incidents, access and control blowouts in subsea environments, and improve containment and recovery methods. The task forces are working closely with the oil and gas industry and international government agencies to implement improvements and increase the effectiveness of oil spill prevention, preparedness, response and recovery processes.

     Insurance Coverage and Indemnification: The Corporation maintains insurance coverage that includes coverage for physical damage to its property, third party liability, workers’ compensation and employers’ liability, general liability, sudden and accidental pollution, and other coverage. This insurance coverage is subject to deductibles, exclusions and limitations and there is no assurance that such coverage will adequately protect the Corporation against liability from all potential consequences and damages.

     The amount of insurance covering physical damage to the Corporation’s property and liability related to negative environmental effects resulting from a sudden and accidental pollution event, excluding windstorm coverage in the Gulf of Mexico where it is self insured, varies by asset, based on the asset’s estimated replacement value or the estimated maximum loss. In the case of a catastrophic event, first party coverage consists of two tiers of insurance. The first $250 million of coverage is provided through an industry mutual insurance group. Above this $250 million threshold, insurance is carried which ranges in value between $250 million to over $1 billion, depending on the asset coverage level, as described above. Additionally, the Corporation carries insurance which provides third party coverage for general liability, and sudden and accidental pollution, up to $695 million.

     Other insurance policies provide coverage for, among other things: charterer’s legal liability, in the amount of $500 million per occurrence and aircraft liability, in the amount of $300 million per occurrence.

     The Corporation’s insurance policies renew at various dates each year. Future insurance coverage for the industry could increase in cost and may include higher deductibles or retentions, or additional exclusions or limitations. In addition, some forms of insurance may become unavailable in the future or unavailable on terms that are deemed economically acceptable.

     Generally, the Corporation’s drilling contracts (and most of its other offshore services contracts) provide for a mutual hold harmless indemnity structure whereby each party to the contract (the Corporation and Contractor) indemnifies the other party for injuries or damages to their personnel and property regardless of fault. Variations include indemnity exclusions to the extent a claim is attributable to the gross negligence and/or willful misconduct of a party. Third-party claims, on the other hand, are generally allocated on a fault basis.

     The Corporation is customarily responsible for, and indemnifies the Contractor against, all claims, including those from third-parties, to the extent attributable to pollution or contamination by substances originating from its reservoirs or other property (regardless of fault, including gross negligence and willful misconduct) and the Contractor is responsible for and indemnifies the Corporation for all claims attributable to pollution emanating from the Contractor’s property. Additionally, the Corporation is generally liable for all of its own losses and most third-party claims associated with catastrophic losses such as blowouts, cratering and loss of hole, regardless of cause, although exceptions for losses attributable to gross negligence and/or willful misconduct do exist. Lastly, many offshore services contracts include overall limitations of the Contractor’s liability equal to the value of the contract or a fixed amount, whichever is greater.

     Under a standard joint operating agreement (JOA), each party is liable for all claims arising under the JOA, not covered by or in excess of insurance carried by the JOA, to the extent of its participating interest (operator or non-operator). Variations include indemnity exclusions where the claim is based upon the gross negligence and/or willful misconduct of a party in which case such party is solely liable.

     Financial Reform Legislation: In July 2010, the Wall Street Reform and Consumer Protection Act was signed into law. This law will establish new regulations affecting activities in the financial markets including the use of over the counter derivatives. While final regulations have not yet been issued, the Corporation is currently evaluating the potential impact, if any, that the regulations could have on future operations.

     The after-tax income (loss) by major operating activity was as follows (in millions, except per share data):

     The following table summarizes, on an after-tax basis, items of income (expense) that are included in net income and affect comparability between periods (amounts in millions). The items in the table below are explained and the pre-tax amounts are shown on pages 26, 27, 28 and 30.

     In the discussion that follows, the financial effects of certain transactions are disclosed on an after-tax basis. Management reviews segment earnings on an after-tax basis and uses after-tax amounts in its review of variances in segment earnings. Management believes that after-tax amounts are preferable to pre-tax amounts for explaining variances in earnings, since they show the entire effect of a transaction. After-tax amounts are determined by applying the appropriate income tax rate in each tax jurisdiction to pre-tax amounts.

     Following is a summarized income statement of the Corporation’s E&P operations (in millions):

Selling prices: The Corporation’s average selling prices were as follows: