UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

Form 10-Q

 

 

Commission file number 1-368-2

Chevron Corporation

(Exact name of registrant as specified in its charter)

 

 

Registrant’s telephone number, including area code: (925) 842-1000

 

NONE
(Former name or former address, if changed since last report.)

 

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

 

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

 

(Do not check if a smaller

reporting company)

 

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

 

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date:

 

 

 

INDEX

 

 

This quarterly report on Form 10-Q of Chevron Corporation contains forward-looking statements relating to Chevron’s operations that are based on management’s current expectations, estimates, and projections about the petroleum, chemicals, and other energy-related industries. Words such as “anticipates,” “expects,” “intends,” “plans,” “targets,” “projects,” “believes,” “seeks,” “schedules,” “estimates,” “budgets” and similar expressions are intended to identify such forward-looking statements. These statements are not guarantees of future performance and are subject to certain risks, uncertainties and other factors, some of which are beyond our control and are difficult to predict. Therefore, actual outcomes and results may differ materially from what is expressed or forecasted in such forward-looking statements. The reader should not place undue reliance on these forward-looking statements, which speak only as of the date of this report. Unless legally required, Chevron undertakes no obligation to update publicly any forward-looking statements, whether as a result of new information, future events or otherwise.

 

Among the important factors that could cause actual results to differ materially from those in the forward-looking statements are crude-oil and natural-gas prices; refining, marketing and chemicals margins; actions of competitors; timing of exploration expenses; the competitiveness of alternate energy sources or product substitutes; technological developments; the results of operations and financial condition of equity affiliates; the inability or failure of the company’s joint-venture partners to fund their share of operations and development activities; the potential failure to achieve expected net production from existing and future crude-oil and natural-gas development projects; potential delays in the development, construction or start-up of planned projects; the potential disruption or interruption of the company’s net production or manufacturing facilities or delivery/transportation networks due to war, accidents, political events, civil unrest, severe weather or crude-oil production quotas that might be imposed by OPEC (Organization of Petroleum Exporting Countries); the potential liability for remedial actions or assessments under existing or future environmental regulations and litigation; significant investment or product changes under existing or future environmental statutes, regulations and litigation; the potential liability resulting from pending or future litigation; the company’s acquisition or disposition of assets; gains and losses from asset dispositions or impairments; government-mandated sales, divestitures, recapitalizations, industry-specific taxes, changes in fiscal terms or restrictions on scope of company operations; foreign currency movements compared with the U.S. dollar; the effects of changed accounting rules under generally accepted accounting principles promulgated by rule-setting bodies; and the factors set forth under the heading “Risk Factors” on pages 32 and 33 of the company’s 2007 Annual Report on Form 10-K/A. In addition, such statements could be affected by general domestic and international economic and political conditions. Unpredictable or unknown factors not discussed in this report could also have material adverse effects on forward-looking statements.

 

 

 

See accompanying notes to consolidated financial statements.

 

 

See accompanying notes to consolidated financial statements.

 

 

See accompanying notes to consolidated financial statements.

 

 

See accompanying notes to consolidated financial statements.

 

 

The accompanying consolidated financial statements of Chevron Corporation and its subsidiaries (the company) have not been audited by independent accountants. In the opinion of the company’s management, the interim data include all adjustments necessary for a fair statement of the results for the interim periods. These adjustments were of a normal recurring nature.

 

Certain notes and other information have been condensed or omitted from the interim financial statements presented in this Quarterly Report on Form 10-Q. Therefore, these financial statements should be read in conjunction with the company’s 2007 Annual Report on Form 10-K/A.

 

The results for the three- and six-month periods ended June 30, 2008, are not necessarily indicative of future financial results.

 

Earnings in the first quarter 2007 included a $700 million gain on a sale of the company’s interest in refining and related assets in the Netherlands. Second quarter 2007 results included a $680 million gain on the sale of the company’s holding of Dynegy Inc. common stock.

 

 

The “Net increase in operating working capital” was composed of the following operating changes:

 

 

In accordance with the cash-flow classification requirements of FAS 123R, Share-Based Payment, the “Net increase in operating working capital” includes reductions of $98 million and $65 million for excess income tax benefits associated with stock options exercised during the six months ended June 30, 2008 and 2007, respectively. These amounts are offset by an equal amount in “Net purchases of treasury shares.”

 

“Net Cash Provided by Operating Activities” included the following cash payments for interest on debt and for income taxes:

 

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

The “Net sales of marketable securities” consisted of the following gross amounts:

 

 

The “Net purchases of treasury shares” represents the cost of common shares acquired in the open market less the cost of shares issued for share-based compensation plans. Net purchases totaled $3.6 billion and $2.6 billion in the 2008 and 2007 periods, respectively. Purchases in the first half of 2008 were under the company’s stock repurchase program initiated in September 2007.

 

The major components of “Capital expenditures” and the reconciliation of this amount to the capital and exploratory expenditures, including equity affiliates, presented in “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” are presented in the following table:

 

 

 

Although each subsidiary of Chevron is responsible for its own affairs, Chevron Corporation manages its investments in these subsidiaries and their affiliates. For this purpose, the investments are grouped as follows: upstream — exploration and production; downstream — refining, marketing and transportation; chemicals; and all other. The first three of these groupings represent the company’s “reportable segments” and “operating segments” as defined in Financial Accounting Standards Board (FASB) Statement No. 131, Disclosures about Segments of an Enterprise and Related Information (FAS 131).

 

The segments are separately managed for investment purposes under a structure that includes “segment managers” who report to the company’s “chief operating decision maker” (CODM) (terms as defined in FAS 131). The CODM is the company’s Executive Committee, a committee of senior officers that includes the Chief Executive Officer, and that in turn reports to the Board of Directors of Chevron Corporation.

 

The operating segments represent components of the company as described in FAS 131 terms that engage in activities (a) from which revenues are earned and expenses are incurred; (b) whose operating results are regularly reviewed by the CODM, which makes decisions about resources to be allocated to the segments and to assess their performance; and (c) for which discrete financial information is available.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

Segment managers for the reportable segments are directly accountable to and maintain regular contact with the company’s CODM to discuss the segment’s operating activities and financial performance. The CODM approves annual capital and exploratory budgets at the reportable segment level, as well as reviews capital and exploratory funding for major projects and approves major changes to the annual capital and exploratory budgets. However, business-unit managers within the operating segments are directly responsible for decisions relating to project implementation and all other matters connected with daily operations. Company officers who are members of the Executive Committee also have individual management responsibilities and participate in other committees for purposes other than acting as the CODM.

 

“All other” activities include mining operations, power generation businesses, worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities, alternative fuels, technology companies, and the company’s interest in Dynegy Inc. prior to its sale in May 2007.

 

The company’s primary country of operation is the United States of America, its country of domicile. Other components of the company’s operations are reported as “International” (outside the United States).

 

Segment Earnings  The company evaluates the performance of its operating segments on an after-tax basis, without considering the effects of debt financing interest expense or investment interest income, both of which are managed by the company on a worldwide basis. Corporate administrative costs and assets are not allocated to the operating segments. However, operating segments are billed for the direct use of corporate services. Nonbillable costs remain at the corporate level in “All Other.” Income by major operating area for the three- and six-month periods ended June 30, 2008 and 2007, is presented in the following table:

 

Segment Income

 

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

Segment Assets  Segment assets do not include intercompany investments or intercompany receivables. “All Other” assets in 2008 consist primarily of worldwide cash, cash equivalents and marketable securities, real estate, information systems, mining operations, power generation businesses, technology companies and assets of the corporate administrative functions. Segment assets at June 30, 2008, and December 31, 2007, are as follows:

 

Segment Assets

 

 

Segment Sales and Other Operating Revenues  Operating-segment sales and other operating revenues, including internal transfers, for the three- and six-month periods ended June 30, 2008 and 2007, are presented in the following table. Products are transferred between operating segments at internal product values that approximate market prices. Revenues for the upstream segment are derived primarily from the production and sale of crude oil and natural gas, as well as the sale of third-party production of natural gas. Revenues for the downstream segment are derived from the refining and marketing of petroleum products such as gasoline, jet fuel, gas oils, lubricants, residual fuel oils and other products derived from crude oil. This segment also generates revenues from the transportation and trading of crude oil and refined products. Revenues for the chemicals segment are derived primarily from the manufacture and sale of additives for lubricants and fuels. “All Other” activities include revenues from mining operations of coal and other minerals, power generation businesses, insurance operations, real estate activities and technology companies.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

Sales and Other Operating Revenues

 

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

 

Chevron U.S.A. Inc. (CUSA) is a major subsidiary of Chevron Corporation. CUSA and its subsidiaries manage and operate most of Chevron’s U.S. businesses. Assets include those related to the exploration and production of crude oil, natural gas and natural gas liquids and those associated with refining, marketing, supply and distribution of products derived from petroleum, excluding most of the regulated pipeline operations of Chevron. CUSA also holds the company’s investment in the Chevron Phillips Chemical Company LLC (CPChem) joint venture, which is accounted for using the equity method.

 

The summarized financial information for CUSA and its consolidated subsidiaries is presented in the table below.

 

 

 

 

Chevron Transport Corporation Limited (CTC), incorporated in Bermuda, is an indirect, wholly owned subsidiary of Chevron Corporation. CTC is the principal operator of Chevron’s international tanker fleet and is engaged in the marine transportation of crude oil and refined petroleum products. Most of CTC’s shipping revenue is derived by providing transportation services to other Chevron companies. Chevron Corporation has fully and unconditionally guaranteed this subsidiary’s obligations in connection with certain debt securities issued by a third party. Summarized financial information for CTC and its consolidated subsidiaries is presented as follows:

 

 

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

 

There were no restrictions on CTC’s ability to pay dividends or make loans or advances at June 30, 2008.

 

 

Taxes on income for the second quarter and first half of 2008 were $5.8 billion and $10.3 billion, respectively, compared with $3.7 billion and $6.5 billion for the corresponding periods in 2007. The associated effective tax rates for the second quarters of 2008 and 2007 were 49 percent and 41 percent, respectively. For the comparative six-month periods, the effective tax rates were 48 percent and 39 percent, respectively. The 2008 rates in the comparative periods were higher primarily because a greater proportion of income was earned in international upstream tax jurisdictions, which generally have higher income tax rates than other tax jurisdictions. The 2007 second quarter included a relatively low effective tax rate on the sale of the company’s investment in Dynegy common stock. In addition, the 2007 six-month period included a relatively low effective tax rate on the first quarter sale of refining-related assets in the Netherlands.

 

 

The company has defined-benefit pension plans for many employees. The company typically prefunds defined-benefit plans as required by local regulations or in certain situations where pre-funding provides economic advantages. In the United States, this includes all qualified plans subject to the Employee Retirement Income Security Act of 1974 (ERISA) minimum funding standard. The company does not typically fund U.S. nonqualified pension plans that are not subject to funding requirements under applicable laws and regulations because contributions to these pension plans may be less economic and investment returns may be less attractive than the company’s other investment alternatives.

 

The company also sponsors other postretirement plans that provide medical and dental benefits, as well as life insurance for some active and qualifying retired employees. The plans are unfunded, and the company and the retirees share the costs. Medical coverage for Medicare-eligible retirees in the company’s main U.S. medical plan is secondary to Medicare (including Part D) and the increase to the company contribution for retiree medical coverage is limited to no more than 4 percent each year. Certain life insurance benefits are paid by the company.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

The components of net periodic benefit costs for 2008 and 2007 were:

 

 

 

 

At the end of 2007, the company estimated it would contribute $500 million to employee pension plans during 2008 (composed of $300 million for the U.S. plans and $200 million for the international plans). Through June 30, 2008, a total of $127 million was contributed (including $61 million to the U.S. plans). Total estimated contributions for the full year continue to be $500 million, but the company may contribute an amount that differs from this estimate. Actual contribution amounts are dependent upon investment returns, changes in pension obligations, regulatory environments and other economic factors. Additional funding may ultimately be required if investment returns are insufficient to offset increases in plan obligations.

 

During the first half of 2008, the company contributed $96 million to its other postretirement benefit plans. The company anticipates contributing $112 million during the remainder of 2008.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

 

The company accounts for the cost of exploratory wells in accordance with FAS 19, Financial Accounting and Reporting by Oil and Gas Producing Companies, as amended by FASB Staff Position FAS 19-1, Accounting for Suspended Well Costs, which provides that an exploratory well continues to be capitalized after the completion of drilling if certain criteria are met. The company’s capitalized cost of suspended wells at June 30, 2008, was $1.84 billion, an increase of approximately $180 million from year-end 2007 due primarily to activities in the United States, Nigeria and Australia. For the category of exploratory well costs at year-end 2007 that were suspended more than one year, a total of $65 million was expensed in the first half of 2008.

 

 

MTBE  Chevron and many other companies in the petroleum industry have used methyl tertiary butyl ether (MTBE) as a gasoline additive. The company is a party to 89 lawsuits and claims, the majority of which involve numerous other petroleum marketers and refiners, related to the use of MTBE in certain oxygenated gasolines and the alleged seepage of MTBE into groundwater. Chevron has agreed in principle to a tentative settlement of 59 pending lawsuits and claims. The terms of this agreement which is currently under court review are confidential and not material to the company’s results of operations, liquidity or financial position.

 

Resolution of remaining lawsuits and claims may ultimately require the company to correct or ameliorate the alleged effects on the environment of prior release of MTBE by the company or other parties. Additional lawsuits and claims related to the use of MTBE, including personal-injury claims, may be filed in the future. The tentative settlement of the referenced 59 lawsuits did not set any precedents related to standards of liability to be used to judge the merits of the claims, corrective measures required or monetary damages to be assessed for the remaining lawsuits and claims or future lawsuits and claims. As a result, the company’s ultimate exposure related to pending lawsuits and claims is not currently determinable, but could be material to net income in any one period. The company no longer uses MTBE in the manufacture of gasoline in the United States.

 

RFG Patent  Fourteen purported class actions were brought by consumers of reformulated gasoline (RFG) alleging that Unocal misled the California Air Resources Board into adopting standards for composition of RFG that overlapped with Unocal’s undisclosed and pending patents. Eleven lawsuits were consolidated in U.S. District Court for the Central District of California, where a class action has been certified, and three were consolidated in a state court action. Unocal is alleged to have monopolized, conspired and engaged in unfair methods of competition, resulting in injury to consumers of RFG. Plaintiffs in both consolidated actions seek unspecified actual and punitive damages, attorneys’ fees, and interest on behalf of an alleged class of consumers who purchased “summertime” RFG in California from January 1995 through August 2005. The parties have reached a tentative agreement to resolve all of the above matters in an amount that is not material to the company’s results of operations, liquidity or financial position. The terms of this agreement are confidential, and subject to further negotiation and approval, including by the courts.

 

Ecuador  Chevron is a defendant in a civil lawsuit before the Superior Court of Nueva Loja in Lago Agrio, Ecuador brought in May 2003 by plaintiffs who claim to be representatives of certain residents of an area where an oil production consortium formerly had operations. The lawsuit alleges damage to the environment from the oil exploration and production operations, and seeks unspecified damages to fund environmental remediation and restoration of the alleged environmental harm, plus a health monitoring program. Until 1992, Texaco Petroleum Company (Texpet), a subsidiary of Texaco Inc., was a minority member of this consortium with Petroecuador, the Ecuadorian state-owned oil company, as the majority partner; since 1990, the operations have been conducted solely by Petroecuador. At the conclusion of the consortium, and following an independent third-party environmental audit of the concession area, Texpet entered into a formal agreement with the Republic of Ecuador and Petroecuador for Texpet to remediate specific sites assigned by the government in proportion to Texpet’s ownership share of the consortium. Pursuant to that agreement, Texpet conducted a three-year remediation program at a cost of $40 million. After certifying that the sites were properly remediated, the government granted

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

Texpet and all related corporate entities a full release from any and all environmental liability arising from the consortium operations.

 

Based on the history described above, Chevron believes that this lawsuit lacks legal or factual merit. As to matters of law, the company believes first, that the court lacks jurisdiction over Chevron; second, that the law under which plaintiffs bring the action, enacted in 1999, cannot be applied retroactively to Chevron; third, that the claims are barred by the statute of limitations in Ecuador; and, fourth, that the lawsuit is also barred by the releases from liability previously given to Texpet by the Republic of Ecuador and Petroecuador. With regard to the facts, the Company believes that the evidence confirms that Texpet’s remediation was properly conducted and that the remaining environmental damage reflects Petroecuador’s failure to timely fulfill its legal obligations and Petroecuador’s further conduct since assuming full control over the operations.

 

In April 2008, a mining engineer appointed by the court to identify and determine the cause of environmental damage, and to specify steps needed to remediate it, issued a report recommending that the court assess $8 billion, which would, according to the engineer, provide financial compensation for purported damages, including wrongful death claims, and pay for, among other items, environmental remediation, healthcare systems, and additional infrastructure for Petroecuador. The engineer’s report also asserts that an additional $8.3 billion could be assessed against Chevron for unjust enrichment. The engineer’s report is not binding on the court. Chevron also believes that the engineer’s work was performed, and his report prepared, in a manner contrary to law and in violation of the court’s orders. Chevron intends to move to strike the report and otherwise continue a vigorous defense against any attempted imposition of liability.

 

Management does not believe an estimate of a reasonably possible loss (or a range of loss) can be made in this case. Due to the defects associated with the engineer’s report, management does not believe the report itself has any utility in calculating a reasonably possible loss (or a range of loss). Moreover, the highly uncertain legal environment surrounding the case provides no basis for management to estimate a reasonably possible loss (or a range of loss).

 

 

Guarantees  The company and its subsidiaries have certain other contingent liabilities with respect to guarantees, direct or indirect, of debt of affiliated companies or third parties. Under the terms of the guarantee arrangements, generally the company would be required to perform should the affiliated company or third party fail to fulfill its obligations under the arrangements. In some cases, the guarantee arrangements may have recourse provisions that would enable the company to recover any payments made under the terms of the guarantees from assets provided as collateral.

 

Off-Balance-Sheet Obligations  The company and its subsidiaries have certain other contractual obligations relating to long-term unconditional purchase obligations and commitments, including throughput and take-or-pay agreements, some of which relate to suppliers’ financing arrangements. The agreements typically provide goods and services, such as pipeline, storage and regasification capacity, drilling rigs, utilities and petroleum products, to be used or sold in the ordinary course of the company’s business.

 

Indemnifications  The company provided certain indemnities of contingent liabilities of Equilon and Motiva to Shell and Saudi Refining, Inc., in connection with the February 2002 sale of the company’s interests in those investments. The company would be required to perform if the indemnified liabilities become actual losses. Were that to occur, the company could be required to make future payments up to $300 million. Through the end of June 2008, the company paid $48 million under these indemnities and continues to be obligated for possible additional indemnification payments in the future.

 

The company has also provided indemnities relating to contingent environmental liabilities related to assets originally contributed by Texaco to the Equilon and Motiva joint ventures and environmental conditions that existed prior to the formation of Equilon and Motiva or that occurred during the period of Texaco’s ownership interest in the joint ventures. In general, the environmental conditions or events that are subject to these indemnities must have

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

arisen prior to December 2001. Claims must be asserted no later than February 2009 for Equilon indemnities and no later than February 2012 for Motiva indemnities. Under the terms of these indemnities, there is no maximum limit on the amount of potential future payments. The company has not recorded any liabilities for possible claims under these indemnities. The company posts no assets as collateral and has made no payments under the indemnities.

 

The amounts payable for the indemnities described above are to be net of amounts recovered from insurance carriers and others and net of liabilities recorded by Equilon or Motiva prior to September 30, 2001, for any applicable incident.

 

In the acquisition of Unocal, the company assumed certain indemnities relating to contingent environmental liabilities associated with assets that were sold in 1997. Under the indemnification agreement, the company’s liability is unlimited until April 2022, when the liability expires. The acquirer of the assets sold in 1997 shares in certain environmental remediation costs up to a maximum obligation of $200 million, which had not been reached as of June 30, 2008.

 

Minority Interests  The company has commitments of $226 million related to minority interests in subsidiary companies.

 

Environmental  The company is subject to loss contingencies pursuant to laws, regulations, private claims and legal proceedings related to environmental matters that are subject to legal settlements or that in the future may require the company to take action to correct or ameliorate the effects on the environment of prior release of chemicals or petroleum substances, including MTBE, by the company or other parties. Such contingencies may exist for various sites, including, but not limited to, federal Superfund sites and analogous sites under state laws, refineries, crude-oil fields, service stations, terminals, land development areas, and mining operations, whether operating, closed or divested. These future costs are not fully determinable due to such factors as the unknown magnitude of possible contamination, the unknown timing and extent of the corrective actions that may be required, the determination of the company’s liability in proportion to other responsible parties, and the extent to which such costs are recoverable from third parties.

 

Although the company has provided for known environmental obligations that are probable and reasonably estimable, the amount of additional future costs may be material to results of operations in the period in which they are recognized. The company does not expect these costs will have a material effect on its consolidated financial position or liquidity. Also, the company does not believe its obligations to make such expenditures have had, or will have, any significant impact on the company’s competitive position relative to other U.S. or international petroleum or chemical companies.

 

Chevron’s environmental reserve at December 31, 2007, was approximately $1.5 billion. At June 30, 2008, the environmental reserve increased to approximately $1.9 billion. The increase was mainly associated with remediation liabilities Chevron has incurred for sites that were previously sold.

 

Financial Instruments  The company believes it has no material market or credit risks to its operations, financial position or liquidity as a result of its commodities and other derivatives activities, including forward-exchange contracts and interest rate swaps.

 

Equity Redetermination  For oil and gas producing operations, ownership agreements may provide for periodic reassessments of equity interests in estimated crude-oil and natural-gas reserves. These activities, individually or together, may result in gains or losses that could be material to earnings in any given period. One such equity redetermination process has been under way since 1996 for Chevron’s interests in four producing zones at the Naval Petroleum Reserve at Elk Hills, California, for the time when the remaining interests in these zones were owned by the U.S. Department of Energy. A wide range remains for a possible net settlement amount for the four zones. For this range of settlement, Chevron estimates its maximum possible net before-tax liability at approximately $200 million, and the possible maximum net amount that could be owed to Chevron is estimated at about $150 million. The timing of the settlement and the exact amount within this range of estimates are uncertain.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

Other Contingencies  Chevron receives claims from and submits claims to customers; trading partners; U.S. federal, state and local regulatory bodies; governments; contractors; insurers; and suppliers. The amounts of these claims, individually and in the aggregate, may be significant and take lengthy periods to resolve.

 

The company and its affiliates also continue to review and analyze their operations and may close, abandon, sell, exchange, acquire or restructure assets to achieve operational or strategic benefits and to improve competitiveness and profitability. These activities, individually or together, may result in gains or losses in future periods.

 

 

In 2007, the company implemented a restructuring and reorganization program in its global downstream operations. Approximately 1,000 employees were eligible for severance payments. As of June 30, 2008, approximately 600 employees had been terminated under the program. Most of the associated positions are located outside of the United States. The program is expected to be complete by the end of 2009.

 

Shown in the table below is the activity for the company’s liability related to the downstream reorganization. The associated charges against income were categorized as “Operating expenses” or “Selling, general and administrative expenses” on the Consolidated Statement of Income.

 

 

 

The company implemented FASB Statement No. 157, Fair Value Measurements (FAS 157), as of January 1, 2008. FAS 157 was amended in February 2008 by FASB Staff Position (FSP) FAS No. 157-1, Application of FASB Statement No. 157 to FASB Statement No. 13 and Its Related Interpretive Accounting Pronouncements That Address Leasing Transactions, and by FSP FAS 157-2, Effective Date of FASB Statement No. 157, which delayed the company’s application of FAS 157 for nonrecurring nonfinancial assets and liabilities until January 1, 2009.

 

Implementation of FAS 157 did not have a material effect on the company’s results of operations or consolidated financial position and had no effect on the company’s existing fair-value measurement practices. However, FAS 157 requires disclosure of a fair-value hierarchy of inputs the company uses to value an asset or a liability. The three levels of the fair-value hierarchy are described as follows:

 

Level 1: Quoted prices (unadjusted) in active markets for identical assets and liabilities. For the company, Level 1 inputs include exchange-traded futures contracts for which the parties are willing to transact at the exchange-quoted price and marketable securities that are actively traded.

 

Level 2: Inputs other than Level 1 that are observable, either directly or indirectly. For the company, Level 2 inputs include quoted prices for similar assets or liabilities, prices obtained through third-party broker quotes and prices that can be corroborated with other observable inputs for substantially the complete term of a contract.

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

 

Level 3: Unobservable inputs. The company does not use Level 3 inputs for any of its recurring fair-value measurements. Beginning January 1, 2009, Level 3 inputs may be required for the determination of fair value associated with certain nonrecurring measurements of nonfinancial assets and liabilities.

 

The fair value hierarchy for assets and liabilities measured at fair value at June 30, 2008, is as follows:

 

Assets and Liabilities Measured at Fair Value on a Recurring Basis

 

 

Marketable securities  The company calculates fair value for its marketable securities based on quoted market prices for identical assets and liabilities.

 

Derivatives  The company records its derivative instruments — other than any commodity derivative contracts that are designated as normal purchase and normal sale — on the Consolidated Balance Sheet at fair value, with virtually all the offsetting amount to the Consolidated Statement of Income. For derivatives with identical or similar provisions as contracts that are publicly traded on a regular basis, the company uses the market values of the publicly traded instruments as an input for fair-value calculations.

 

The company’s derivative instruments principally include crude oil, natural gas and refined-product futures, swaps, options and forward contracts, as well as interest-rate swaps and foreign-currency forward contracts. Derivatives classified as Level 1 include futures, swaps and options contracts traded in active markets such as the NYMEX (New York Mercantile Exchange). Level 2 derivatives include swaps (including interest rate), options, and forward (including foreign currency) contracts principally with financial institutions and other oil and gas companies, the fair values for which are obtained from third party broker quotes, industry pricing services and exchanges. These Level 2 fair values are routinely corroborated on a sample basis with observable market-based inputs.

 

 

FASB Statement No. 141 (revised 2007), Business Combinations (FAS 141-R)  In December 2007, the FASB issued FAS 141-R, which will become effective for business combination transactions having an acquisition date on or after January 1, 2009. This standard requires the acquiring entity in a business combination to recognize the assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at the acquisition date to be measured at their respective fair values. The Statement requires acquisition-related costs, as well as restructuring costs the acquirer expects to incur for which it is not obligated at acquisition date, to be recorded against income rather than included in purchase-price determination. It also requires recognition of contingent arrangements at their acquisition-date fair values, with subsequent changes in fair value generally reflected in income.

 

FASB Statement No. 160, Noncontrolling Interests in Consolidated Financial Statements, an amendment of ARB No. 51 (FAS 160)  The FASB issued FAS 160 in December 2007, which will become effective for the company January 1, 2009, with retroactive adoption of the Statement’s presentation and disclosure requirements for existing minority interests. This standard will require ownership interests in subsidiaries held by parties other than the parent to be presented within the equity section of the consolidated statement of financial position but separate from the parent’s equity. It will also require the amount of consolidated net income attributable to the parent and the

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

 

noncontrolling interest to be clearly identified and presented on the face of the consolidated income statement. Certain changes in a parent’s ownership interest are to be accounted for as equity transactions and when a subsidiary is deconsolidated, any noncontrolling equity investment in the former subsidiary is to be initially measured at fair value. The company does not anticipate the implementation of FAS 160 will significantly change the presentation of its consolidated income statement or consolidated balance sheet.

 

FASB Statement No. 161, Disclosures about Derivative Instruments and Hedging Activities (FAS 161)  In March 2008, the FASB issued FAS 161, which becomes effective for the company on January 1, 2009. This standard amends and expands the disclosure requirements of FASB Statement No. 133, Accounting for Derivative Instruments and Hedging Activities. FAS 161 requires disclosures related to objectives and strategies for using derivatives; the fair-value amounts of, and gains and losses on, derivative instruments; and credit-risk-related contingent features in derivative agreements. The effect on the company’s disclosures for derivative instruments as a result of the adoption of FAS 161 in 2009 will depend on the company’s derivative instruments and hedging activities at that time.

 

Second Quarter 2008 Compared with Second Quarter 2007
and Six Months 2008 Compared with Six Months 2007