Chevron - 10-Q quarterly report FY

 

 

 

 

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, or anon-acceleratedfiler. See definition of “accelerated filer and large accelerated filer” inRule 12b-2of the Act. (Check one):

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

 

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

 

 

 

This quarterly report onForm 10-Qof 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 theseforward-lookingstatements, 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 theforward-lookingstatements are crude oil and natural gas prices; refining margins and marketing margins; chemicals prices and competitive conditions affecting supply and demand for aromatics, olefins and additives products; actions of competitors; 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 orstart-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 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; government-mandated sales, divestitures, recapitalizations, 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 31 and 32 of the company’s 2006 Annual Report onForm 10-K.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.

 

 

 

 

Refer to accompanying notes to consolidated financial statements.

 

 

Refer to accompanying notes to consolidated financial statements.

 

 

 

Refer to accompanying notes to consolidated financial statements.

 

 

Refer to 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 onForm 10-Q.Therefore, these financial statements should be read in conjunction with the company’s 2006 Annual Report onForm 10-K.The results for the three- and nine-month periods ended September 30, 2007, are not necessarily indicative of future financial results.

 

Earnings for the third quarter 2007 included a $265 million gain on the sale of marketing assets in the Benelux region of Europe. Earnings for the first nine months of 2007 also included gains of $700 million on the sale of refining-related assets in the Netherlands and $680 million on the sale of the company’s holding of Dynegy Inc. common stock.

 

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

 

 

In accordance with the cash-flow classification requirements of FAS 123(R), Share-Based Payment, the “Net decrease (increase) in operating working capital” includes reductions of $90 million and $60 million for excess income tax benefits associated with stock options exercised during the first nine months of 2007 and 2006, 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:

 

 

 

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

 

 

“Net purchases of treasury shares” represents the cost of common shares acquired less the cost of shares issued for share-based compensation plans. Purchases totaled $5.0 billion and $3.7 billion in the 2007 and 2006 periods, respectively. Purchases in the first nine months of 2007 were primarily under the company’s stock buyback program initiated in December 2006 and completed in September 2007. The purchases also included $100 million related to a program that began in September 2007. The 2006 purchases related to a program that began in December 2005 and was completed in November 2006.

 

The major components of “Capital expenditures” and the reconciliation of this amount to “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 the 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 which 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.

 

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-unitmanagers 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” includes the company’s investment in Dynegy Inc. until the time of its sale in May 2007, mining operations, power generation businesses, worldwide cash management and debt financing activities, corporate administrative functions, insurance operations, real estate activities and technology companies.

 

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 operating segment for the three- and nine-month periods ended September 30, 2007 and 2006, is presented in the following table:

 

 

 

Segment Assets  Segment assets do not include intercompany investments or intercompany receivables. “All Other” assets in 2007 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. In addition, the amounts at year-end 2006 include the company’s investment in Dynegy that was sold in May 2007. Segment assets at September 30, 2007, and December 31, 2006 follow:

 

 

Segment Sales and Other Operating Revenues  Upstream segment revenues 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, kerosene, 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” includes revenues from mining operations, power generation businesses, insurance operations, real estate activities and technology companies.

 

 

Operating-segment sales and other operating revenues, including internal transfers, for the three- andnine-monthperiods ended September 30, 2007 and 2006, are presented in the following table. Products are transferred between operating segments at internal product values that approximate market prices.

 

 

 

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 Chevron’s equity-method investment in the Chevron Phillips Chemical Company LLC (CPChem) joint venture and held the company’s equity-method investment in Dynegy Inc. until its sale in the second quarter 2007.

 

During the first nine months of 2007, Chevron implemented legal reorganizations in which certain Chevron subsidiaries transferred assets to or under CUSA. The summarized financial information for CUSA and its consolidated subsidiaries presented in the table below gives retroactive effect to the reorganization as if it had occurred on January 1, 2006. However, the financial information below may not reflect the financial position and operating results in the future or the historical results in the period presented if the reorganization actually had occurred on that date.

 

 

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 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:

 

 

 

 

There were no restrictions on CTC’s ability to pay dividends or make loans or advances at September 30, 2007.

 

Effective January 1, 2007, the company implemented Financial Accounting Standards Board (FASB) Interpretation No. 48, Accounting for Uncertainty in Income Taxes — An Interpretation of FASB Statement No. 109 (FIN 48), which clarifies the accounting for income tax benefits that are uncertain in nature. This interpretation was intended by the standard-setters to address the diversity in practice that existed in this area of accounting for income taxes.

 

Under FIN 48, a company recognizes a tax benefit in the financial statements for an uncertain tax position only if management’s assessment is that the position is “more likely than not” (i.e., a likelihood greater than 50 percent) to be allowed by the tax jurisdiction based solely on the technical merits of the position. The term “tax position” in FIN 48 refers to a position in a previously filed tax return or a position expected to be taken in a future tax return that is reflected in measuring current or deferred income tax assets and liabilities for interim or annual periods. The accounting interpretation also provides guidance on measurement methodology, derecognition thresholds, financial statement classification and disclosures, recognition of interest and penalties, and accounting for thecumulative-effectadjustment at the date of adoption. Upon adoption of FIN 48 on January 1, 2007, the company recorded a cumulative-effect adjustment that reduced retained earnings by $35 million.

 

Tax positions for Chevron and its subsidiaries and affiliates are subject to income tax audits by many tax jurisdictions throughout the world. For the company’s major tax jurisdictions, examinations of tax returns for certain prior tax years had not been completed as of January 1, 2007. In this regard, examinations had not been finalized for years beginning after 2001 for the company’s U.S. federal income taxes. For other major tax jurisdictions, the earliest years for which income tax examinations had not been finalized were as follows: Nigeria — 1995, Angola — 2002, and Saudi Arabia — 2004. In these and other tax jurisdictions, the company may make refund claims for years that have had examinations completed. As a result of these refund claims, the audited tax years may be subject to reexamination by the taxing authorities.

 

The company’s total amount of unrecognized tax benefits for numerous issues and all tax jurisdictions at January 1, 2007, was approximately $2.3 billion. The term “unrecognized tax benefits” in FIN 48 refers to the differences between a tax position taken or expected to be taken in a tax return and the benefit measured and recognized in the financial statements in accordance with the guidelines of FIN 48. Interest and penalties are not included. Although unrecognized tax benefits for individual tax positions may increase or decrease during 2007, the company believed none had a reasonable possibility of significantly increasing or decreasing the total amount of unrecognized tax benefits during 2007 or for the period one year after September 30, 2007. Substantially all of the estimated $2.3 billion of unrecognized tax benefits at January 1, 2007, would have an impact on the overall tax rate if subsequently recognized.

 

On the Consolidated Statement of Income, the company reports interest and penalties related to liabilities for uncertain tax positions as “Income tax expense.” As of January 1, 2007, accruals of approximately $130 million for anticipated interest and penalty obligations were included on the Consolidated Balance Sheet. For the third quarter and first nine months of 2007, income tax expense associated with interest and penalties was not material.

 

 

In March 2007, the company received a final U.S. federal income tax audit report for years 2002 and 2003. The impact of the report on the total amount of unrecognized tax benefits as of September 30, 2007, was not significant.

 

Taxes on income for the third quarter and first nine months of 2007 were $3.2 billion and $9.8 billion, respectively, compared with $4.3 billion and $12 billion for the comparable periods in 2006. The associated effective tax rate for the third quarters of 2007 and 2006 were 47 percent and 46 percent, respectively. For the comparative nine-month periods, the effective tax rates were 41 percent and 47 percent, respectively. The primary reason for the lower average tax rate in the 2007 nine-month period was the impact of the sales of refining-related assets in the Netherlands and the company’s investment in Dynegy common stock. The 2006 period included the effect of one-time charges, mainly for an increase in tax rates on upstream operations in the U.K. North Sea.

 

The company has defined benefit pension plans for many employees and typically pre-funds these 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 domestic 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 and annual contributions are based on actual plan experience.

 

 

The components of net periodic benefit costs for 2007 and 2006 were:

 

 

 

 

At the end of 2006, the company estimated it would contribute $500 million to employee pension plans during 2007 (composed of $300 million for the U.S. plans and $200 million for the international plans). Through September 30, 2007, a total of $219 million was contributed (including $71 million to the U.S. plans) and total contributions for the full year are now estimated at $350 million. Actual contribution amounts may differ from this estimate and 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 nine months of 2007, the company contributed $138 million to its plans for other postretirement benefits. The company anticipates contributing an additional $50 million during the remainder of 2007.

 

 

 

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 PositionFAS 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 September 30, 2007, was $1.46 billion, an increase of approximately $200 million from year-end 2006 due mainly to drilling activities in the United Kingdom, Angola and United States. For the category of exploratory well costs at year-end 2006 that were suspended more than one year, a total of $25 million was expensed in the first nine months of 2007.

 

The company adopted the accounting prescribed by EITF IssueNo. 04-13,Accounting for Purchases and Sales of Inventory with the Same Counterparty (Issue04-13) on a prospective basis from April 1, 2006. Issue04-13requires that two or more legally separate exchange transactions with the same counterparty, including buy/sell transactions, be combined and considered as a single arrangement for purposes of applying the provisions of Accounting Principles Board Opinion No. 29, Accounting for Nonmonetary Transactions, when the transactions are entered into “in contemplation” of one another. In prior periods, the company accounted for buy/sell transactions in the Consolidated Statement of Income the same as a monetary transaction — purchases were reported as “Purchased crude oil and products”; sales were reported as “Sales and other operating revenues.”

 

With the company’s adoption of Issue04-13,buy/sell transactions from April 1, 2006, are netted against each other on the Consolidated Statement of Income, with no effect on net income. The amount associated with buy/sell transactions in the first quarter 2006 is disclosed in the footnote to the Consolidated Statement of Income on page 3.

 

MTBE  Chevron and many other companies in the petroleum industry have used methyl tertiary butyl ether (MTBE) as a gasoline additive. Chevron is a party to 87 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. Resolution of these actions 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 company’s ultimate exposure related to these lawsuits and claims is not currently determinable, but could be material to net income in any one period. The company does not use 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 are now consolidated in U.S. District Court for the Central District of California, where a class action has been certified, and three are consolidated in a state court action that has been stayed. 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 company intends to vigorously defend against these lawsuits. The company’s potential exposure related to these lawsuits cannot currently be estimated.

 

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 and storage capacity, drilling rigs, utilities and petroleum products, to be used or sold in the ordinary course of the company’s business.

 

Securitization  The company securitizes certain retail and trade accounts receivable in its downstream business through the use of qualifying Special Purpose Entities (SPEs). At September 30, 2007, approximately $1.3 billion, representing about 7 percent of Chevron’s total current accounts and notes receivable balance, were securitized. These arrangements have the effect of accelerating Chevron’s collection of the securitized amounts. Chevron’s total estimated financial exposure under these securitizations at September 30, 2007, was approximately $130 million. In the event the SPEs experience major defaults in the collection of receivables, Chevron believes it would have no additional loss exposure connected with third-party investments in these securitizations.

 

During the third quarter 2007, the company entered into an agreement to sell its U.S. proprietary consumer credit card business and related retail accounts receivable and expects to record a gain upon the close of sale. The transaction is subject to obtaining necessary regulatory approvals. This transaction will include terminating the qualifying SPE associated with the retail accounts receivable in accordance with Financial Accounting Standards Board (FASB) Statement No. 140,Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities. At September 30, 2007, approximately $670 million of these retail accounts receivable were securitized. The company will continue to securitize certain trade accounts receivable in its downstream business through the use of a SPE, and at September 30, 2007, approximately $640 million of these receivables were securitized.

 

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 September 2007, the company had 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 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 indemnification expires. The acquirer shares in certain environmental remediation costs up to a maximum obligation of $200 million, which had not been reached as of September 30, 2007.

 

 

Minority Interests  The company has commitments of $209 million related to minority interests in subsidiary companies.

 

Environmental  The company is subject to loss contingencies pursuant to environmental laws and regulations (both U.S. and international) that in the future may require the company to take action to correct or ameliorate the effects on the environment of prior release of chemical 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 and international 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.

 

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 estimates a maximum possible net before-tax amount that could be owed to the company at about $150 million. The timing of the settlement and the exact amount within this range of estimates are uncertain.

 

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.

 

The company recorded a before-tax charge of $69 million ($45 million after tax) in the third quarter 2007 associated with estimated termination benefits for approximately 700 downstream employees located primarily outside the United States. No payments to employees were made under this program during the third quarter. All employee terminations and benefit payments are expected to be completed during the first-half 2008.

 

 

 

FASB Statement No. 157, Fair Value Measurements (FAS 157)  In September 2006, the FASB issued FAS 157, which will become effective for the company on January 1, 2008. This standard defines fair value, establishes a framework for measuring fair value and expands disclosures about fair value measurements. FAS 157 does not require any new fair value measurements but would apply to assets and liabilities that are required to be recorded at fair value under other accounting standards. Based on estimates as of September 30, 2007, the company does not anticipate that the adoption of FAS 157 will have an impact on the company’s results of operations or consolidated financial position.

 

FASB Statement No. 159, The Fair Value Option for Financial Assets and Financial Liabilities — Including an amendment of FASB Statement No. 115 (FAS 159)  In February 2007, the FASB issued FAS 159, which becomes effective for the company on January 1, 2008. This standard permits companies to choose to measure many financial instruments and certain other items at fair value and report unrealized gains and losses in earnings. Such accounting is optional and is generally to be applied instrument by instrument. The company does not anticipate that election, if any, of this fair-value option will have a material effect on its results of operations or consolidated financial position.