UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended March 31, 2006

or

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

For the transition period from                                               to                                              

Commission file number: 001-32395

ConocoPhillips

(Exact name of registrant as specified in its charter)

281-293-1000

(Registrant’s telephone number, including area code)

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):

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

The registrant had 1,650,644,278 shares of common stock, $.01 par value, outstanding at March 31, 2006.

CONOCOPHILLIPS

TABLE OF CONTENTS

PART I. FINANCIAL INFORMATION

Item 1. FINANCIAL STATEMENTS

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Note 1—Interim Financial Information

The interim-period financial information presented in the financial statements included in this report is unaudited and includes all known accruals and adjustments that, in the opinion of management, are necessary for a fair presentation of the consolidated financial position of ConocoPhillips and its results of operations and cash flows for such periods. All such adjustments are of a normal and recurring nature. The acquisition of Burlington Resources Inc. is reflected in our March 31, 2006, balance sheet, and it will be reflected in our results of operations beginning in the second quarter of 2006. To enhance your understanding of these interim financial statements, see the consolidated financial statements and notes included in our 2005 Annual Report on Form 10-K.

Note 2—Accounting Policies

Revenue Recognition—Revenues associated with sales of crude oil, natural gas, natural gas liquids, petroleum and chemical products, and other items are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry. Revenues include the sales portion of transactions commonly called buy/sell contracts, in which physical commodity purchases and sales are simultaneously contracted with the same counterparty to either obtain a different quality or grade of refinery feedstock supply, reposition a commodity (for example, where we enter into a contract with a counterparty to sell refined products or natural gas volumes at one location and purchase similar volumes at another location closer to our wholesale customer), or both.

Buy/sell transactions have the same general terms and conditions as typical commercial contracts including: separate title transfer, transfer of risk of loss, separate billing and cash settlement for both the buy and sell sides of the transaction, and non-performance by one party does not relieve the other party of its obligation to perform, except in events of force majeure. Because buy/sell contracts have similar terms and conditions, we and many other companies in our industry account for these purchase and sale transactions separately as a purchase and a sale in the consolidated income statement.

In September 2005, the Emerging Issues Task Force (EITF) reached a consensus on Issue No. 04-13, “Accounting for Purchases and Sales of Inventory with the Same Counterparty.” Issue No. 04-13 requires purchases and sales of inventory with the same counterparty entered into “in contemplation” of one another to be combined and reported net (i.e. on the same income statement line). Exceptions to this are exchanges of finished goods for raw materials or work-in-progress within the same line of business, which are only reported net if the transaction lacks economic substance.

The guidance provided by EITF No. 04-13 is effective for new arrangements entered into after March 31, 2006, and for modifications or renewals of existing arrangements made after that date. Any impact to income from continuing operations and net income would result from changes in last-in, first-out (LIFO) inventory valuations, and is not expected to be material.

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Had this new guidance been effective for the periods included in this report, the pro forma sales and other operating revenues, and purchased crude oil, natural gas and products would have been as follows:

Our Commercial organization uses commodity derivative contracts (such as futures and options) in various markets to optimize the value of our supply chain and to balance physical systems. In addition to cash settlement prior to contract expiration, exchange-traded futures contracts may also be settled by physical delivery of the commodity, providing another source of supply to meet our refinery requirements or marketing demand.

Revenues from the production of natural gas properties, in which we have an interest with other producers, are recognized based on the actual volumes we sold during the period. Any differences between volumes sold and entitlement volumes, based on our net working interest, which are deemed to be non-recoverable through remaining production, are recognized as accounts receivable or accounts payable, as appropriate. Cumulative differences between volumes sold and entitlement volumes are generally not significant. Revenues associated with royalty fees from licensed technology are recorded based either upon volumes produced by the licensee or upon the successful completion of all substantive performance requirements related to the installation of licensed technology.

Stock-Based Compensation—Effective January 1, 2003, we voluntarily adopted the fair-value accounting method prescribed by Statement of Financial Accounting Standards (SFAS) No. 123, “Accounting for Stock-Based Compensation.”  We used the prospective transition method, applying the fair-value accounting method and recognizing compensation expense equal to the fair-market value on the grant date for all stock options granted or modified after December 31, 2002.

Employee stock options granted prior to 2003 were accounted for under Accounting Principles Board (APB) Opinion No. 25, “Accounting for Stock Issued to Employees,” and related Interpretations; however, by the end of 2005, all of these awards had vested. Because the exercise price of our employee stock options equals the market price of the underlying stock on the date of grant, generally no compensation expense was recognized under APB Opinion No. 25. The following table displays 2005 pro forma information as if provisions of SFAS No. 123 had been applied to all employee stock options granted:

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*Per-share amounts restated to reflect a two-for-one stock split effected as a 100 percent stock dividend on June 1, 2005.

Effective January 1, 2006, we adopted SFAS No. 123 (revised 2004), “Share-Based Payment,” (SFAS No. 123(R)). For information about our adoption of this new accounting standard, see Note 3—Changes in Accounting Principles.

Note 3—Changes in Accounting Principles

In December 2004, the Financial Accounting Standards Board (FASB) issued SFAS No. 123(R), which supercedes APB Opinion No. 25, “Accounting for Stock Issued to Employees,” and replaces SFAS No. 123, “Accounting for Stock-Based Compensation.”  SFAS No. 123(R), which was effective January 1, 2006, prescribes the accounting for a wide range of share-based compensation arrangements, including options, restricted share plans, performance-based awards, share appreciation rights, and employee share purchase plans, and generally requires the fair value of share-based awards to be expensed. We adopted the provisions of this Statement on January 1, 2006, using the modified-prospective transition method.

SFAS No. 123(R) permits the use of either the accelerated method or the straight-line method to recognize expense for share-based awards subject to graded vesting (i.e., when portions of the award vest at different dates throughout the vesting period). In the past, we have used the accelerated recognition method for these awards, but concurrent with our adoption of SFAS No. 123(R), we elected to use the straight-line recognition method to account for new awards granted with graded vesting provisions.

Generally, our stock-based compensation programs provide accelerated vesting (i.e., a waiver of the remaining period of service required to earn an award) for awards held by employees at the time of their retirement. For awards granted prior to January 1, 2006, we recognize expense over the period of time during which the employee earns the award, accelerating the recognition of expense only when an employee actually retires.

For stock-based compensation awards granted after December 31, 2005, our adoption of SFAS No. 123(R) requires us to recognize expense over the shorter of: 1) the service period (i.e., the stated period of time required to earn the award); or 2) the period beginning at the start of the service period and ending when an employee first becomes eligible for retirement. This change in recognition method will shorten the

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period over which we recognize expense for most of our stock-based awards granted to our employees who are already age 55 or older.

During the first quarter of 2006, the company granted 3,057,505 restricted stock units, with an average fair value of $58.44 per unit, under the 2004 Omnibus Stock and Performance Incentive Plan and lifted restrictions on 41,102 restricted stock units granted in prior years.

Also during the first quarter of 2006, the company granted 1,734,100 stock options under the 2004 Omnibus Stock and Performance Incentive Plan with an average exercise price of $59.08 and an average fair value of $16.11 per option. This value was calculated using the Black-Scholes option-pricing model, assuming a risk-free interest rate of 4.62 percent, an expected dividend yield of 2.50 percent, a volatility factor of 26.1 percent and an expected life of 7.2 years. None of these stock options were exercisable as of March 31, 2006. During the first quarter of 2006, 1,848,948 stock options were exercised with an average exercise price of $24.06 per option, and 5,999,645 options became eligible for exercise.

In addition to the above stock option activity, on March 31, 2006, in exchange for outstanding Burlington Resources Inc. stock options, the company granted approximately 3.6 million vested stock options, with an average exercise price of $23.40 per share, and approximately 1.3 million non-vested stock options with an average exercise price of $62.99 per share. The aggregate fair value of these options, as calculated with the Black-Scholes option-pricing model, was approximately $140 million.

Due in part to our having fully adopted the fair-value accounting method prescribed by SFAS No. 123 on January 1, 2003, the adoption of SFAS No. 123(R) did not have a material impact on our first-quarter 2006 financial statements, nor do we expect it to have a material impact on our future financial statements.

In November 2004, the FASB issued SFAS No. 151, “Inventory Costs, an amendment of ARB No. 43, Chapter 4.”  This Statement clarifies that items such as abnormal amounts of idle facility expense, freight, handling costs, and wasted material (spoilage) be recognized as current-period charges. In addition, the Statement requires that allocation of fixed production overheads to the costs of conversion be based on the normal capacity of the production facilities. We adopted this Statement in the first quarter of 2006. The adoption of this Statement did not have a material impact on our financial statements.

Note 4—Common Stock Split

On April 7, 2005, our Board of Directors declared a two-for-one common stock split effected in the form of a 100 percent stock dividend, payable June 1, 2005, to stockholders of record as of May 16, 2005. The total number of authorized common shares and associated par value per share were unchanged by this action. Shares and per-share information in the Consolidated Income Statement and Balance Sheet are on an after-split basis for all periods presented.

Note 5—Acquisition of Burlington Resources Inc.

On March 31, 2006, ConocoPhillips completed the $33.8 billion acquisition of Burlington Resources Inc., an independent exploration and production company that held a substantial position in North American natural gas proved reserves, production and exploratory acreage. We issued approximately 270.4 million shares of our common stock and paid approximately $17.4 billion in cash. We acquired $3.2 billion in cash from Burlington Resources in the acquisition, resulting in a net cash acquisition amount of

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$14.2 billion. Results of operations attributable to Burlington Resources will be included in ConocoPhillips’ consolidated income statement beginning in the second quarter of 2006.

The acquisition of Burlington Resources added approximately 2 billion barrels of oil equivalent to our proved reserves.

The primary reasons for the acquisition and the principal factors contributing to a purchase price resulting in the recognition of goodwill were expanded growth opportunities in North American natural gas exploration and development, cost savings from the elimination of duplicate activities, and the sharing of best practices in the operations of both companies.

The $33.8 billion purchase price was based on Burlington Resources shareholders receiving $46.50 in cash and 0.7214 shares of ConocoPhillips common stock for each Burlington Resources share owned. ConocoPhillips issued approximately 270.4 million shares of common stock and approximately 3.6 million of vested employee stock options in exchange for 374.8 million shares of Burlington Resources common stock and 2.5 million Burlington Resources vested stock options. The ConocoPhillips common stock was valued at $59.85 per share, which was the weighted-average price of ConocoPhillips common stock for a five-day period beginning two available trading days before the public announcement of the transaction on the evening of December 12, 2005. The Burlington Resources vested stock options, whose fair value was determined using the Black-Scholes option-pricing model, were exchanged for ConocoPhillips stock options valued at $127 million. Estimated transaction-related costs were $35 million.

Also included in the acquisition was the replacement of 0.9 million non-vested Burlington Resources stock options and 0.4 million shares of non-vested restricted stock with 1.3 million non-vested ConocoPhillips stock options and 0.5 million non-vested ConocoPhillips restricted stock. In addition, 1.2 million Burlington Resources shares of common stock held by a consolidated grantor trust, related to a deferred compensation plan, were converted into 0.9 million ConocoPhillips common shares and were recorded as a reduction of stockholders’ equity at March 31, 2006.

The preliminary allocation of the purchase price to specific assets and liabilities was based, in part, upon a preliminary outside appraisal of the fair value of Burlington Resources assets. Over the next few months, ConocoPhillips expects to receive the final outside appraisal of the long-lived assets and conclude the fair value determination of all other Burlington Resources assets and liabilities. The following table summarizes, based on the preliminary purchase price allocation described above, the fair values of the assets acquired and liabilities assumed as of March 31, 2006:

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Goodwill recorded in the acquisition is not subject to amortization, but will be tested periodically for impairment as required by SFAS No. 142, “Goodwill and Other Intangible Assets.”

ConocoPhillips assigned all of the Burlington Resources goodwill to the Worldwide Exploration and Production reporting unit. Of the $16,466 million of goodwill, $8,481 million relates to net deferred tax liabilities arising from differences between the allocated financial bases and deductible tax bases of the acquired assets. None of the goodwill is deductible for tax purposes.

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The following table presents unaudited pro forma summary information as if the acquisition had occurred at the beginning of each period presented.

The unaudited pro forma information does not reflect any anticipated synergies that might be achieved from combining the operations. The pro forma information is not intended to reflect the actual results that would have occurred if the companies had been combined during the periods presented, nor is it intended to be indicative of the results of operations that may be achieved by ConocoPhillips in the future.

The pro forma adjustments include estimates and assumptions based on currently available information. Management believes the estimates and assumptions are reasonable, and the significant effects of the transactions are properly reflected. However, actual results may differ materially from this pro forma financial information.

Note 6—Restructuring

As a result of the acquisition of Burlington Resources Inc., we implemented a restructuring program in March 2006 to capture the synergies of combining the two companies. Under this program, which is expected to be completed by the end of March 2008, we recorded accruals totaling $172 million for employee severance payments, incremental pension benefit costs associated with the workforce reductions, and Burlington Resources employee relocations. Approximately 585 positions have been identified for elimination, most of which are in the United States. Of the total accrual, $165 million is reflected in the Burlington Resources purchase price allocation as an assumed liability, and $7 million ($4 million after-tax) related to ConocoPhillips is reflected in selling, general and administrative expense. Included in the total accruals of $172 million is $5 million related to pension benefits to be paid in conjunction with other retirement benefits over a number of future years. Benefit payments of $8 million related to the non-pension accrual of $167 million were made in March 2006, resulting in an ending liability balance of $159 million. The ending accrual balance is expected to be extinguished within one year, except for $63 million, which is classified as long-term.

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Note 7—Consolidation of Variable Interest Entities (VIEs)

In 2004, we finalized a transaction with Freeport LNG Development, L.P. (Freeport LNG) to participate in a liquefied natural gas (LNG) receiving terminal in Quintana, Texas. We have no ownership in the facility, but we do have a 50 percent interest in the general partnership managing the venture, along with contractual rights to regasification capacity of the terminal. We entered into a credit agreement with Freeport LNG, whereby we will provide loan financing of approximately $630 million for the construction of the terminal. Through March 31, 2006, we had provided $283 million in financing, including accrued interest. We determined Freeport LNG was a VIE and we were not the primary beneficiary. We account for our loan to Freeport LNG as a financial asset.

In June 2005, ConocoPhillips and OAO LUKOIL (LUKOIL) created the OOO Naryanmarneftegaz (NMNG) joint venture to develop resources in the Timan-Pechora region of Russia. We determined NMNG is a VIE because we and our related party, LUKOIL, have disproportionate interests. We have a 30 percent ownership interest with a 50 percent governance interest in the joint venture. We determined we were not the primary beneficiary and we use the equity method of accounting for this investment. The acquisition cost for the 30 percent ownership interest in NMNG was $528 million. This amount was comprised of $512 million paid at the June 2005 closing and a subsequent payment of $16 million in February 2006, primarily related to working capital. At March 31, 2006, the book value of our investment in the venture was $670 million.

Production from the NMNG joint-venture fields is transported via pipeline to LUKOIL’s existing terminal at Varandey Bay on the Barents Sea and then shipped via tanker to international markets. LUKOIL intends to complete an expansion of the terminal’s capacity in late 2007, with ConocoPhillips participating in the design and financing of the expansion. We determined the terminal entity, Varandey Terminal Company, is also a VIE because we and our related party, LUKOIL, have disproportionate interests. We have an obligation to fund, through loans, 30 percent of the terminal’s costs, but we will have no governance or ownership interest in the terminal. We have determined we were not the primary beneficiary and account for our loan to Varandey Terminal Company as a financial asset. Through March 31, 2006, we had provided $76 million in loan financing.

In 2003, we entered into two 20-year agreements establishing separate guarantee facilities of $50 million each for two LNG ships then under construction. Subject to the terms of the facilities, we will be required to make payments should the charter revenue generated by the ships fall below a certain specified minimum threshold, and we will receive payments to the extent such revenues exceed those thresholds. To the extent we receive any such payments, our actual gross payments over the 20 years could exceed $100 million. In September 2003, the first ship was delivered to its owner and in July 2005, the second ship was delivered to its owner. We determined both agreements represented a VIE, but we were not the primary beneficiary and, therefore, we did not consolidate these entities. The amount drawn under the guarantee facilities at March 31, 2006, was approximately $5 million for both ships. We currently account for these agreements as guarantees and contingent liabilities. See Note 15—Guarantees, for additional information.

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Note 8—Inventories

Inventories consisted of the following:

Inventories valued on a LIFO basis totaled $4,559 million and $3,019 million at March 31, 2006, and December 31, 2005, respectively. The remainder of our inventories is valued under various methods, including first-in, first-out and weighted average. The excess of current replacement cost over LIFO cost of inventories amounted to $4,618 million and $4,271 million at March 31, 2006, and December 31, 2005, respectively.

Note 9—Investments and Long-Term Receivables

LUKOIL

We increased our ownership interest in LUKOIL to 17.1 percent at March 31, 2006, from 16.1 percent at December 31, 2005.

At March 31, 2006, the book value of our ordinary share investment in LUKOIL was $6,453 million. Our share of the net assets of LUKOIL was estimated to be $4,700 million. This basis difference of $1,753 million is primarily being amortized on a unit-of-production basis. On March 31, 2006, the closing price of LUKOIL shares on the London Stock Exchange was $83.40 per share, making the aggregate total market value of our LUKOIL investment $12,109 million.

Loans to Affiliated Companies

As part of our normal ongoing business operations and consistent with normal industry practice, we invest and enter into numerous agreements with other parties to pursue business opportunities, which share costs and apportion risks among the parties as governed by the agreements. Included in such activity are loans made to certain affiliated companies. Significant loans to affiliated companies at March 31, 2006, include the following:

•                  $283 million in loan financing, including accrued interest, to Freeport LNG for the construction of an LNG facility. We expect to provide loan financing of approximately $630 million for the construction of the facility.

•                  $76 million in loan financing to Varandey Terminal Company associated with the costs of a terminal expansion. We expect our total obligation for the terminal expansion to be approximately $340 million at current exchange rates.

•                  $78 million of project financing to Qatargas 3, an integrated project to produce and liquefy natural gas from Qatar’s North field. Our maximum exposure to this financing structure is $1.2 billion.

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Note 10—Properties, Plants and Equipment

Properties, plants and equipment included the following:

Suspended Wells

The following table reflects the net changes in suspended exploratory well costs during the first quarter of 2006:

The following table provides an aging of suspended well balances at March 31, 2006, and December 31, 2005:

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The following table provides a further aging of those exploratory well costs that have been capitalized for more than one year since the completion of drilling, as of March 31, 2006:

(1)  Development decisions pending infrastructure west of Alpine and construction authorization.

(2)  Additional appraisal wells planned.

(3)  Appraisal drilling complete; costs being incurred to assess development.

Note 11—Goodwill

Changes in the carrying amount of goodwill were as follows:

On March 31, 2006, we closed on the acquisition of Burlington Resources Inc., an independent exploration and production company. As a result of this acquisition, we recorded goodwill of $16,466 million, all of which was aligned with our E&P segment. See Note 5—Acquisition of Burlington Resources Inc., for additional information.

On February 28, 2006, we closed on the acquisition of the Wilhelmshaven refinery, located in Wilhelmshaven, Germany. The purchase included the refinery, a marine terminal, rail and truck loading facilities and a tank farm, as well as another entity that provides commercial and administrative support to the refinery. As a result of this acquisition, we recorded goodwill of $459 million, all of which was aligned with our R&M segment. This preliminary allocation of the purchase price to specific assets and liabilities was based on our internal estimate of the fair values of the various assets and liabilities acquired. An outside appraiser has been engaged to assist us in the finalization of the purchase price allocation. Over the next few months, the company expects to receive the outside appraisal of the long-lived assets acquired, and will then finalize the allocation of the purchase price to the specific assets and liabilities acquired and the calculations of deferred tax liabilities and goodwill.

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Note 12—Property Impairments

In the first quarter of 2005, we recorded property impairments related to planned asset dispositions. The property impairments by segment were:

Note 13—Debt

Our balance sheet debt at March 31, 2006, was $32.2 billion, compared with a debt balance of $12.5 billion at year-end 2005. The increase reflects debt issuances of approximately $15.3 billion during the first quarter of 2006 related to the acquisition of Burlington Resources Inc. In addition, we assumed $3.9 billion of Burlington Resources debt and recognized an incremental debt increase of $405 million to record Burlington Resources debt at its fair value.

At March 31, 2006, we had two revolving credit facilities totaling $5 billion. These facilities may be used as direct bank borrowings, as support for the ConocoPhillips $5 billion commercial paper program, as support for the ConocoPhillips Qatar Funding Ltd. $1.5 billion commercial paper program, or as support for issuances of letters of credit totaling up to $750 million. The facilities were broadly syndicated among financial institutions and did not contain any material adverse change provisions or any covenants requiring maintenance of specified financial ratios or ratings. The credit agreements contain a cross-default provision relating to our, or any of our consolidated subsidiaries’, failure to pay principal or interest on other debt obligations of $200 million or more. At March 31, 2006, and December 31, 2005, we had no outstanding borrowings under these credit facilities, but $312 million and $62 million, respectively, in letters of credit had been issued. Under both commercial paper programs there was $375 million of commercial paper outstanding at March 31, 2006, compared with $32 million at December 31, 2005.

In March 2006, we closed on two $7.5 billion bridge facilities with a group of five banks to help fund the Burlington Resources acquisition. These bridge financings are both 364-day loan facilities with pricing and terms similar to our existing revolving credit facilities. These facilities were fully drawn at March 31, 2006.

In April 2006, we entered into and funded a $5 billion five-year term loan, closed a $2.5 billion five-year revolving credit agreement, increased the ConocoPhillips commercial paper program to $7.5 billion, and issued $3 billion of debt securities. The term loan and new credit agreement were executed with a group of 36 banks and have terms and pricing provisions similar to our existing revolving credit facilities. The proceeds from the term loan, debt securities and issuances of commercial paper, together with our cash balances, allowed us to reduce the balance outstanding under the $15 billion bridge facilities to $2 billion at April 30, 2006.

The $3 billion of debt securities were issued under a new shelf registration statement filed with the U.S. Securities and Exchange Commission in early April 2006, allowing for the issuance of various types of

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debt and equity securities. Of this issuance, $1 billion of Floating Rate Notes due April 11, 2007, were issued by ConocoPhillips, and $1.25 billion of Floating Rate Notes due April 9, 2009, and $750 million of 5.50% Notes due 2013, were issued by ConocoPhillips Australia Funding Company, a wholly owned subsidiary. ConocoPhillips guaranteed the obligations of ConocoPhillips Australia Funding Company.

Burlington Resources debt assumed in the acquisition, including increases to record Burlington Resources debt at its fair value (see Note 5—Acquisition of Burlington Resources Inc., for additional information about the acquisition), had the following balances at March 31, 2006:

Maturities inclusive of net unamortized premiums and discounts on Burlington Resources debt assumed for the remainder of 2006 through 2010 are:  $680 million, $411 million, $59 million, $58 million and $206 million, respectively.

The amortization of the fair-value adjustment will result in the above fixed-rate notes having a weighted-average effective interest rate of 5.64 percent.

In April 2006, we gave notice to repay in May 2006, the $129 million of 6.60% Notes due in 2007 that we assumed from Burlington Resources in the acquisition.

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Note 14—Contingencies and Commitments

In the case of all known contingencies, we accrue a liability when the loss is probable and the amount is reasonably estimable. We do not reduce these liabilities for potential insurance or third-party recoveries. If applicable, we accrue receivables for probable insurance or other third-party recoveries.

Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Estimates that are particularly sensitive to future changes include contingent liabilities recorded for environmental remediation, tax and legal matters. Estimated future environmental remediation costs are subject to change due to such factors as the uncertain magnitude of cleanup costs, the unknown time and extent of such remedial actions that may be required, and the determination of our liability in proportion to that of other responsible parties. Estimated future costs related to tax and legal matters are subject to change as events evolve and as additional information becomes available during the administrative and litigation processes.

Environmental—We are subject to federal, state and local environmental laws and regulations. These may result in obligations to remove or mitigate the effects on the environment of the placement, storage, disposal or release of certain chemical, mineral and petroleum substances at various sites. When we prepare our financial statements, we record accruals for environmental liabilities based on management’s best estimates, using all information that is available at the time. We measure estimates and base liabilities on currently available facts, existing technology, and presently enacted laws and regulations, taking into consideration the likely effects of societal and economic factors. When measuring environmental liabilities, we also consider our prior experience in remediation of contaminated sites, other companies’ cleanup experience, and data released by the U.S. Environmental Protection Agency (EPA) or other organizations. We also consider unasserted claims in our determination of environmental liabilities and we accrue them in the period that they become both probable and reasonably estimable.

Although liability of those potentially responsible for environmental remediation costs is generally joint and several for federal sites and frequently so for state sites, we are usually only one of many companies cited at a particular site. Due to the joint and several liabilities, we could be responsible for all of the cleanup costs related to any site at which we have been designated as a potentially responsible party. If we were solely responsible, the costs, in some cases, could be material to our, or one of our segments’, results of operations, capital resources or liquidity. However, settlements and costs incurred in matters that previously have been resolved have not been material to our results of operations or financial condition. We have been successful to date in sharing cleanup costs with other financially sound companies. Many of the sites at which we are potentially responsible are still under investigation by the EPA or the state agencies concerned. Prior to actual cleanup, those potentially responsible normally assess the site conditions, apportion responsibility and determine the appropriate remediation. In some instances, we may have no liability or may attain a settlement of liability. Where it appears that other potentially responsible parties may be financially unable to bear their proportional share, we consider this inability in estimating our potential liability and adjust our accruals accordingly.

As a result of various acquisitions in the past, we assumed certain environmental obligations. Some of these environmental obligations are mitigated by indemnifications made by others for our benefit and some of the indemnifications are subject to dollar and time limits. We have not recorded accruals for any potential contingent liabilities that we expect to be funded by the prior owners under these indemnifications.

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We are currently participating in environmental assessments and cleanups at numerous federal Superfund and comparable state sites. After an assessment of environmental exposures for cleanup and other costs, we make accruals on an undiscounted basis (except for those assumed in a purchase business combination, which we record on a discounted basis) for planned investigation and remediation activities for sites where it is probable that future costs will be incurred and these costs can be reasonably estimated. At March 31, 2006, our balance sheet included a total environmental accrual of $1,009 million, compared with $989 million at December 31, 2005. We expect to incur the majority of these expenditures within the next 30 years. We have not reduced these accruals for possible insurance recoveries. In the future, we may be involved in additional environmental assessments, cleanups and proceedings.

Legal Proceedings—We apply our knowledge, experience, and professional judgment to the specific characteristics of our cases, employing a litigation management process to manage and monitor the legal proceedings against us. Our process facilitates the early evaluation and quantification of potential exposures in individual cases. This process also enables us to track trial settings, as well as the status and pace of settlement discussions in individual matters. Based on our professional judgment and experience in using these litigation management tools and available information about current developments in all our cases, we believe there is only a remote likelihood that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our financial statements.

Other Contingencies—We have contingent liabilities resulting from throughput agreements with pipeline and processing companies not associated with financing arrangements. Under these agreements, we may be required to provide any such company with additional funds through advances and penalties for fees related to throughput capacity not utilized. In addition, at March 31, 2006, we had performance obligations secured by letters of credit of $1,150 million (of which $312 million was issued under the provisions of our revolving credit facilities, and the remainder was issued as direct bank letters of credit) and various purchase commitments for materials, supplies, services and items of permanent investment incident to the ordinary conduct of business.

Note 15—Guarantees

At March 31, 2006, we were liable for certain contingent obligations under various contractual arrangements as described below. We recognize a liability, at inception, for the fair value of our obligation as a guarantor for newly issued or modified guarantees. Unless the carrying amount of the liability is noted, we have not recognized a liability either because the guarantees were issued prior to December 31, 2002, or because the fair value of the obligation is immaterial.

Construction Completion Guarantees

•                  In December 2005, we issued a construction completion guarantee for 30 percent of the $4.0 billion in loan facilities of Qatargas 3, which will be used to construct an LNG train in Qatar. Of the $4.0 billion in loan facilities, ConocoPhillips has committed to provide $1.2 billion. The maximum potential amount of future payments to third-party lenders under the guarantee is estimated to be $850 million, which could become payable if the full debt financing is utilized and completion of the Qatargas 3 project is not achieved. The project financing will be non-recourse upon certified completion, which is expected by December 31, 2009. At March 31, 2006, the carrying value of the guarantee to the third-party lenders was $11 million. For additional information, see Note 9—Investments and Long-Term Receivables.

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Guarantees of Joint-Venture Debt

•                  At March 31, 2006, we had guarantees outstanding for our portion of joint-venture debt obligations, which have terms of up to 12 years.  The maximum potential amount of future payments under the guarantees is approximately $160 million.  Payment would be required if a joint venture defaults on its debt obligations.

Other Guarantees

•                  The Merey Sweeny, L.P. (MSLP) joint-venture project agreement requires the partners in the venture to pay cash calls to cover operating expenses in the event that the venture does not have enough cash to cover operating expenses after setting aside the amount required for debt service over the next 19 years.  Although there is no maximum limit stated in the agreement, the intent is to cover short-term cash deficiencies should they occur.  Our maximum potential future payments under the agreement are currently estimated to be $100 million, assuming such a shortfall exists at some point in the future due to an extended operational disruption.

•                  In February 2003, we entered into two agreements establishing separate guarantee facilities of $50 million each for two liquefied natural gas ships.  Subject to the terms of each such facility, we will be required to make payments should the charter revenue generated by the respective ship fall below certain specified minimum thresholds, and we will receive payments to the extent that such revenues exceed those thresholds.  The net maximum future payments that we may have to make over the 20-year terms of the two agreements could be up to an aggregate of $100 million.  To the extent we receive any such payments, our actual gross payments over the 20 years could exceed that amount.  In the event either ship is sold or a total loss occurs, we also may have recourse to the sales or insurance proceeds to recoup payments made under the guarantee facilities.  See Note 7—Consolidation of Variable Interest Entities, for additional information.

•                  We have other guarantees with maximum future potential payment amounts totaling $260 million, which consist primarily of dealer and jobber loan guarantees to support our marketing business, a guarantee to fund the short-term cash liquidity deficits of a lubricants joint venture, three small construction completion guarantees, a guarantee supporting a lease assignment on a corporate aircraft, a guarantee associated with a pending lawsuit and guarantees of the lease payment obligations of a joint venture.  The carrying amount recorded for these other guarantees, as of March 31, 2006, was $50 million.  These guarantees generally extend up to 15 years and payment would be required only if the dealer, jobber or lessee goes into default, if the lubricants joint venture has cash liquidity issues, if construction projects are not completed, if guaranteed parties default on lease payments, or if an adverse decision occurs in the lawsuit.

Indemnifications

Over the years, we have entered into various agreements to sell ownership interests in certain corporations and joint ventures and sold several assets, including sales of downstream and midstream assets, certain exploration and production assets, and downstream retail and wholesale sites, giving rise to qualifying indemnifications.  Agreements associated with these sales include indemnifications for taxes, environmental liabilities, permits and licenses, employee claims, real estate indemnity against tenant defaults, and litigation.  The terms of these indemnifications vary greatly.  The majority of these indemnifications are related to environmental issues, the term is generally indefinite and the maximum amount of future payments is generally unlimited.  The carrying amount recorded for these indemnifications, as of March 31, 2006, was $461 million. We amortize the indemnification liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of indemnity.  In cases where the indemnification term is indefinite, we will reverse the liability when we have information that the liability is essentially relieved or amortize the liability over an appropriate time

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period as the fair value of our indemnification exposure declines.  Although it is reasonably possible that future payments may exceed amounts recorded, due to the nature of the indemnifications, it is not possible to make a reasonable estimate of the maximum potential amount of future payments.  Included in the carrying amount recorded were $338 million of environmental accruals for known contamination that is included in asset retirement obligations and accrued environmental costs at March 31, 2006.  For additional information about environmental liabilities, see Note 14—Contingencies and Commitments.

Note 16—Financial Instruments and Derivative Contracts

Derivative assets and liabilities were:

These derivative assets and liabilities appear as prepaid expenses and other current assets, other assets, other accruals, or other liabilities and deferred credits on the balance sheet.

Note 17—Comprehensive Income

ConocoPhillips’ comprehensive income was as follows: