ConocoPhillips (COP) 10-Q 1 Aug 17 2017 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	6 Months Ended
	Jun. 30, 2017shares
Document and Entity Information [Abstract]
Entity Registrant Name	CONOCOPHILLIPS
Entity Central Index Key	1,163,165
Document Type	10-Q
Document Period End Date	Jun. 30, 2017
Amendment Flag	false
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	1,216,949,231
Trading Symbol	COP

Consolidated Income Statement

Consolidated Income Statement - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Revenues and Other Income
Sales and other operating revenues	$ 6,781	$ 5,348	$ 14,299	$ 10,469
Equity in earnings (losses) of affiliates	178	80	378	(69)
Gain on Dispositions	1,876	128	1,898	151
Other income	47	19	78	39
Total Revenues and Other Income	8,882	5,575	16,653	10,590
Costs and Expenses
Purchased commodities	2,922	2,002	6,114	4,227
Production and operating expenses	1,327	1,445	2,625	2,799
Selling, general and administrative expenses	134	167	291	353
Exploration expenses	98	610	649	1,115
Depreciation, depletion and amortization	1,625	2,329	3,604	4,576
Impairments	6,294	62	6,469	198
Taxes other than Income Taxes	198	197	429	377
Accretion on discounted liabilities	92	112	187	221
Interest and debt expense	306	312	621	593
Foreign currency transaction (gains) losses	13	(17)	23	(1)
Other Expense	234		234
Total Costs and Expenses	13,243	7,219	21,246	14,458
Income (Loss) before income taxes	(4,361)	(1,644)	(4,593)	(3,868)
Income tax provision (benefit)	(935)	(586)	(1,766)	(1,354)
Net income (loss)	(3,426)	(1,058)	(2,827)	(2,514)
Less: net income attributable to noncontrolling interests	(14)	(13)	(27)	(26)
Net Income (Loss) Attributable to ConocoPhillips	$ (3,440)	$ (1,071)	$ (2,854)	$ (2,540)
Earnings Per Share, Basic [Abstract]
Earnings Per Share, Basic	$ (2.78)	$ (0.86)	$ (2.3)	$ (2.04)
Earnings Per Share, Diluted [Abstract]
Earnings Per Share, Diluted	(2.78)	(0.86)	(2.3)	(2.04)
Dividends Paid Per Share of Common Stock (dollars)	$ 0.27	$ 0.25	$ 0.53	$ 0.5
Average Common Shares Outstanding (in thousands)
Basic	1,236,831,000	1,244,892,000	1,240,037	1,244,724
Diluted	1,236,831,000	1,244,892,000	1,240,037	1,244,724

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Consolidated Statement of Comprehensive Income [Abstract]
Net income (loss)	$ (3,426)	$ (1,058)	$ (2,827)	$ (2,514)
Defined benefit plans
Prior service credit (cost) arising during the period		0		0
Reclassification adjustment for amortization of prior service cost (credit) included in net income	(10)	(9)	(19)	(18)
Net actuarial gain (loss) arising during the period	(32)	(69)	(39)	(300)
Reclassification adjustment for amortization of net actuarial losses included in net income	66	74	156	182
Nonsponsored plans	0	0	0	0
Income taxes on defined benefit plans	(8)	3	(34)	53
Defined benefit plans, net of tax	16	(1)	64	(83)
Unrealized holding gain (loss) on securities	(424)	0	(424)	0
Unrealized gain (loss) on securities, net of tax	(424)	0	(424)	0
Foreign currency translation adjustments	27	(224)	211	959
Foreign currency translation adjustments, net of tax	27	(224)	211	959
Other Comprehensive Income (Loss), Net of Tax	(381)	(225)	(149)	876
Comprehensive Income (Loss)	(3,807)	(1,283)	(2,976)	(1,638)
Less: comprehensive income attributable to noncontrolling interests	(14)	(13)	(27)	(26)
Comprehensive Income (Loss) Attributable to ConocoPhillips	$ (3,821)	$ (1,296)	$ (3,003)	$ (1,664)

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Assets
Cash and cash equivalents	$ 7,534	$ 3,610
Short-term investments	2,733	50
Accounts and notes receivable (net of allowance of $4 million in 2017 and $5 million in 2016)	3,020	3,249
Accounts and notes receivable-related parties	143	165
Investment in Cenovus Energy	1,533	0
Inventories	1,019	1,018
Prepaid expenses and other current assets	3,897	517
Total Current Assets	19,879	8,609
Investments and long-term receiavables	9,681	21,091
Loans and advances-related parties	522	581
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $62,018 million in 2017 and $73,075 million in 2016)	46,846	58,331
Other assets	1,076	1,160
Total Assets	78,004	89,772
Liabilities
Accounts payable	3,401	3,631
Accounts payable-related parties	33	22
Short-term debt	3,798	1,089
Accrued income and other taxes	791	484
Employee benefit obligations	509	689
Other accruals	1,394	994
Total Current Liabilities	9,926	6,909
Long-term debt	19,670	26,186
Asset retirement obligations and accrued environmental costs	7,631	8,425
Deferred income taxes	6,335	8,949
Employee benefit obligations	2,499	2,552
Other liabilities and deferred credits	1,444	1,525
Total Liabilities	47,505	54,546
Equity
Common stock (2,500,000,000 shares authorized at $.01 par value) Issued (2017 - 1,784,927,181 shares; 2016 - 1,782,079,107 shares) Par value	18	18
Capital in excess of par	46,558	46,507
Treasury stock (at cost: 2017 - 567,977,950 shares; 2016 - 544,809,771 shares)	(37,981)	(36,906)
Accumulated other comprehensive income (loss)	(6,342)	(6,193)
Retained earnings	28,033	31,548
Total Common Stockholders' Equity	30,286	34,974
Noncontrolling interests	213	252
Total Equity	30,499	35,226
Total Liabilities and Equity	$ 78,004	$ 89,772

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Consolidated Balance Sheet [Abstract]
Allowance for accounts and notes receivable	$ 4	$ 5
Accumulated depreciation, depletion and amortization	$ 62,018	$ 73,075
Common stock, shares authorized	2,500,000,000	2,500,000,000
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares issued	1,784,927,181	1,782,079,107
Treasury stock, shares	567,977,950	544,809,771

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Cash Flows From Operating Activities
Net income (loss)	$ (2,827)	$ (2,514)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation, depletion and amortization	3,604	4,576
Impairments	6,469	198
Dry hole costs and leasehold impairments	428	823
Accretion on discounted liabilities	187	221
Deferred taxes	(2,548)	(1,457)
Distributions received greater than equity losses (undistributed equity earnings)	(121)	222
Gain on dispositions	(1,898)	(151)
Other	175	(17)
Working capital adjustments
Decrease (increase) in accounts and notes receivable	313	1,097
Decrease (increase) in inventories	(3)	(23)
Decrease (increase) in prepaid expenses and other current assets	(135)	(51)
Increase (decrease) in accounts payable	(178)	(454)
Increase (decrease) in taxes and other accruals	75	(790)
Net cash provided by operating activities	3,541	1,680
Cash Flows From Investing Activities
Capital expenditures and investments	(1,986)	(2,954)
Working capital changes associated with investing activities	(113)	(363)
Proceeds from asset dispositions	10,742	363
Net sales (purchases) of short-term investments	(2,653)	(1,292)
Collection of advances/loans-related parties	57	53
Other	176	6
Net cash used in continuing investing activities	6,223	(4,187)
Cash Flows From Financing Activities
Issuance of debt	0	4,594
Repayment of debt	(4,079)	(827)
Issuance of company common stock	(63)	(45)
Repurchase of company common stock	(1,075)
Dividends paid	(662)	(626)
Other	(64)	(79)
Net cash provided by (used in) continuing financing activities	(5,943)	3,017
Effect of Exchange Rate Changes on Cash and Cash Equivalents	103	(15)
Net Change in Cash and Cash Equivalents	3,924	495
Cash and cash equivalents at beginning of period	3,610	2,368
Cash and Cash Equivalents at End of Period	$ 7,534	$ 2,863

Basis of Presentation

Basis of Presentation	6 Months Ended
	Jun. 30, 2017
Basis of Presentation [Abstract]
Basis of Presentation	Note 1 —Basis of Presentation The interim-period financial information presented in the financial statements included in this report is unaudited and, in the opinion of management, includes all known accruals and adjustments 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 unless otherwise disclosed. Certain notes and other information have been condensed or omitted from the interim financial statements included in this report. Therefore, these financial statements should be read in conjunction with the consolidated financial statements and notes included in our 2016 Annual Report on Form 10-K.

Variable Interest Entities (VIE

Variable Interest Entities (VIEs)	6 Months Ended
	Jun. 30, 2017
Variable Interest Entities VIEs [Abstract]
Variable Interest Entities Disclosure [Text Block]	Note 2 — Variable Interest Entities (VIEs) We hold variable interests in VIEs that have not been consolidated because we are not considered the primary beneficiary. Information on our significant VIEs follows: Australia Pacific LNG Pty Ltd (APLNG) APLNG is considered a VIE, as it has entered into certain contractual arrangements that provide it with additional forms of subordinated financial support. We are not the primary beneficiary of APLNG because we share with Origin Energy and China Petrochem ical Corporation (Sinopec) the power to direct the key activities of APLNG that most significantly impact its economic performance, which involve activities related to the production and commercialization of coalbed methane, as well as liquefied natural ga s (LNG) processing and export marketing. As a result, we do not consolidate APLNG, and it is accounted for as an equity method investment. As of June 30, 2017 , we have not provided any financial support to APLNG other than amounts previously contractual ly required. Unless we elect otherwise, we have no requirement to provide liquidity or purchase the assets of APLNG. See Note 5 —Investments, Loans and Long-Term Receivables, and Note 11 —Guarantees, for additional information. Marine Well Con tainment Company, LLC (MWCC) MWCC provides well containment equipment and technology and related services in the deepwater U.S. Gulf of Mexico. Its principal activities involve the development and maintenance of rapid-response hydrocarbon well containment systems that are deployable in the Gulf of Mexico on a call-out basis. We have a 10 percent ownership interest in MWCC, and it is accounted for as an equity method investment because MWCC is a limited liability company in which we are a Founding Member and exercise significant influence through our permanent seat on the ten-member Executive Committee responsible for overseeing the affairs of MWCC. In 2016, MWCC executed a $ 154 million term loan financing arrangement with an external financial institution whose terms required the financing be secured by letters of credit provided by certain owners of MWCC, including ConocoPhillips. In connection with the financing transaction, we issued a letter of credit of $ 22 million which can be drawn upon in the event of a default by MWCC on its obligation to repay the proceeds of the term loan. The fair value of this letter of credit is immaterial and not recognized on our consolidated balance sheet. MWCC is considered a VIE, as it has entered into arrangements that provide it with additional forms of subordinated financial support. We are not the primary beneficiary and do not consolidate MWCC because we share the power to govern the business and operation of the company and to undertake certain obligations that most significantly impact its economic performance with nine other unaffiliated owners of MWCC. At June 30, 2017 , the carrying value of our equity method investment in MWCC was $ 143 million. We have not provided any financial support to MWCC other than amounts previously contractually required. Unless we elect otherwise, we have no requirement to provide liquidity or purchase the assets of MWCC.

Inventories

Inventories	6 Months Ended
	Jun. 30, 2017
Inventories [Abstract]
Inventories	Note 3—Inventories Inventories consisted of the following: Millions of Dollars June 30 December 31 2017 2016 Crude oil and natural gas $ 447 418 Materials and supplies 572 600 $ 1,019 1,018 Inventories valued on the last-in, first-out (LIFO) basis totaled $ 296 million and $ 269 million at June 30, 2017 and December 31, 2016 , respectively. The estimated excess of current replacement cost over LIFO cost of inventories was approximately $ 45 million and $ 104 million at June 30, 2017 and December 31, 2016 , respectively.

Assets Held for Sale or Sold

Assets Held for Sale or Sold	6 Months Ended
	Jun. 30, 2017
Disposal Group Excluding Discontinued Operation Additional Disclosures [Abstract]
Disposal Groups Exluding Discontinued Operations Disclosure [TextBlock]	Note 4 — Assets Held for Sale, Sold or Other Planned Dispositions Assets Held for Sale On April 12, 2017, we signed a definitive agreement with an affiliate of Hilcorp Energy Company to sell our interests in the San Juan Basin for up to $ 3.0 billion of total proceeds, comprised of $ 2.7 billion in cash and a contingent payment of up to $ 300 million. The six-year contingent payment is effective beginning January 1, 2018, and is due annually for the periods in which the monthly U.S. Henry Hub p rice is at or above $ 3.20 per million British thermal units. On the date of signing, we received a $ 135 million deposit, which is included in the “Cash Flows From Investing Activities” section of our consolidated statement of cash flows . The transaction closed on July 31, 2017 , with cash proceeds of $ 2.5 billion after customary adjustments. In the second quarter of 2017, we recorded a before-tax impairment of $ 3.3 billion to reduce the carrying value of our interests in the San Ju an Basin to fair value. As of June 30, 2017, our San Juan Basin interests had a net carrying value of approximately $ 2.5 billion and were considered held for sale , resulting in the reclassification of $ 2.9 billion of properties, plants and equipment (PP&E ) to “Prepaid expenses and other current assets” and $ 400 million of noncurrent liabilities, primarily asset retirement obligations, to “Other accruals” on our consolidated balance sheet. The b efore - tax loss associated with our interests in the San Juan B asin , including the $3.3 billion impairment noted above, was $ 3.3 b illion and $ 200 million for the six months ended June 30, 2017 and June 30, 2016, respectively. T he San Juan Basin results of operations are reported within our Lower 48 segment. On June 28 , 2017, we signed a definitive agreement with an affiliate of Miller Thomson & Pa rtners LLC to sell our interests in the Barnett for $ 305 million in cash, subject to customary adjustments. The transaction is subject to specific conditions precedent being satisfied, including regulatory approval, and is expected to close in the third quarter of 2017. We recorded a before-tax impairment of $ 566 million in the second quarter of 2017 to reduce the carrying value of our investment to fair value. As of June 30, 2017, our Barnett interests had a net carrying value of approximately $ 302 million and were considered held for sale resulting in the reclassification of $ 345 million of PP & E to “Prepaid expenses and other current assets” and $ 49 million of noncurrent liabilities, primarily asset retirement obligations, to “Other accruals” on our consolidated balance sheet. The before - tax loss associated with our interests in the Barnett , including the $566 million impairme nt noted above, was $ 585 million and $ 40 million for the six months ended June 30, 2017 and June 30, 2016, respectively. The Barnett results of operations are reported within our Lower 48 segment. Assets Sold On March 29, 2017 , we signed a definitive agreement with Cenovus Energy to sell our 50 percent nonoperated interest in the Foster Creek Christina Lake (FCCL) oil sands partnership, as well as the majority of our western Canada gas assets. The transaction closed o n May 17, 2017. As of closing, consideration for the transaction was $ 10.4 billion of cash, a five-year uncapped contingent payment and 208 million Cenovus Energy common shares. Subsequent to closing, we received $ 600 million related to environmental claims, $ 317 million of which was received in the second quarter of 2017 , and the remainder received in July 2017 . The cash proceeds are included in the “Cash Flows From Investing Activities” section of our consolidated statement of cash flows. The value of the shar es at closing was $ 1.96 billion based on a price of $ 9.41 per share on the New York Stock Exchange. The contingent payment, calculated and paid on a quarterly basis, is $ 6 million Canadian dollars (CAD) for every $1 CAD by which the Western Canada Select (WCS) quarterly average crude price exceeds $ 52 CAD per barrel. At closing, the carrying value of our equity investment in FCCL was $ 8. 9 billion. The carrying value of our interest in the western Canada gas assets was $ 1.9 billion consisting primarily of $ 2.6 billion of PP&E, partly offset by asset retirement obligations of $ 585 million and approximately $ 100 million of environmental and other accruals. A before-tax gain of $ 1.8 5 billion is included in the “Gain on disposition” li ne on our consolidated income statement for the second quarter of 2017. An additional before-tax gain of $ 283 million will be recognized in the third quarter of 2017. We reported before-tax losses of $ 30 million and $ 324 million for the western Canada ga s producing properties for the six- month period s ending June 30, 2017 and June 30, 2016 , respectively. We reported before-tax equity earnings of $ 19 7 million and a before-tax equity loss of $ 98 million for FCCL for th e same periods, respectively. Both FCCL and the western Canada gas assets were reported with in our Canada segment. For more information on the Canada disposition and our investment in Cenovus Energy see Note 6 — Investment in Cenovus Energy, Note 14 — Fair Value Measurement , and Note 15 — Accumulated Other Comprehensive L oss . Other Planned Dispositions On July 25, 2017, we signed a definitive agreement to sell our interest in the Panhandle assets for $ 18 4 million subject to customary adjustments. The transaction is expected to close in the third quarter of 2017. As of June 30, 2017, the net carrying value was approximately $ 207 million, consisting primarily of $ 280 million of PP&E and $ 72 million of asset retirement obligations. The assets met t he held for sale criteria in July 2017 and a noncash impairment will be recorded in the third quarter of 2017. The Panhandle results are reported within our Lower 48 segment.

Investments, Loans and Long-Ter

Investments, Loans and Long-Term Receivables	6 Months Ended
	Jun. 30, 2017
Investments, Loans and Long-Term Receivables [Abstract]
Investments, Loans and Long-Term Receivables	Note 5 —Investments, Loans and Long-Term Receivables APLNG APLNG’s $ 8.5 billion project finance facility consists of financing agreements executed by APLNG with the Export-Import Bank of the United States for approximately $ 2.9 billion, the Export-Import Bank of China for approximately $ 2.7 billion, and a syndicate of Australian and international commercial banks for approximately $ 2.9 billion. All amounts have been drawn from the facility. APLNG mad e its first principal and interest repayment in March 2017 and will continue to make bi-annual payments until March 2029. At June 30, 2017 , a balance of $ 8.2 billion was outstanding on the facility. In connection with the execution of the pro ject financing, we provided a completion guarantee for our pro-rata share of the project finance facility until the project achieves financial completion. In October 2016, we reached financial completion for Train 1, which reduced our associated guarantee by 60 percent . See Note 11 — Guarantees, for additional information. APLNG is considered a VIE, as it has entered into certain contractual arrangements that provide it with additional forms of subordinated financial support. See Note 2 — Variable Interest Entities (VIEs), for additional information. During the first and second quarters of 2017, the outlook for crude oil prices deteriorated , and as a result of significantly reduced price outlooks , the estimated fair value of our investment in APLNG declined to an amount below carrying value. Based on a review of the facts and circumstances surrounding this decline in fair value, we concluded in the second quarter of 2017 the impairment was other than temporary under the guidance of Financial Accounting Standards Board ( FASB ) Accounting Standards Codification (ASC) Topic 323, “Investments – E quity Method and Joint Ventures, ” and the recognition of an impairment of our investment to fair value was n ecessary. In reaching this conclusion, we primarily considered the length of time and the extent to which fair value has been less than carrying value, as well as the trend in market outlook. Fair value has been estimated based on an internal discounted cash flow model using estimated future production, an outlook of future prices from a combination of exchanges (short-term) and pricing service companies (long-term), costs, a market outlook of foreign exchange rates provided by a third party, and a discou nt rate believed to be consistent with those used by principal market participants . Accordingly, we recorded a noncash $ 2 , 3 8 4 million, before- and after-tax impairment, in our second-quarter 2017 results. The impairment, which is included in t he “Impairments” line on our consolidated income statement, had the effect of reducing our carrying value to $ 7,656 million, based on the present value of discounted expected future cash flows as of June 30, 2017 . This carrying value is included in the “Investments and long-term receivables” line on our consolidated balance sheet . FCCL On May 17, 2017, we closed on the sale of our 50 percent nonoperated interest in the FCCL oil sands partnership, as well as the majority of our wester n Canada gas assets to Cenovus Energy. For additional information on the Canada disposition and our investment in Cenovus Energy, s ee Note 4 — Assets Held for Sale, Sold or Other Planned Dispositions and Note 6 — Investment in Cenovus Energy . Loans and Long-Term Receivables As part of our normal ongoing business operations, and consistent with industry practice, we enter into numerous agreements with other parties to pursue business opportunities. Included in such activity are loans made to certain affiliated and non-affiliated companies. At June 30, 2017 , significant loans to affiliated companies included $ 639 million in project financing to Qatar Liquefied Gas Company Limited (3) (QG3). The long-term portion of these loans is included in t he “Loans and advances—related parties” line on our consolidated balance sheet, while the short-term portion is in “Accounts and notes receivable—related parties.”

Investment in Cenovus Energy

Investment in Cenovus Energy	6 Months Ended
	Jun. 30, 2017
Investment In Cenovus Energy [Abstract]
Investments in Debt and Marketable Equity Securities (and Certain Trading Assets) Disclosure [Text Block]	Note 6 -– Investment in Cenovus Energy On March 29, 2017 , we signed a definitive agreement with Cenovus Energy to sell our 50 percent nonoperated interest in the FCCL oil sands partnership, as well as the majority of our western Canada gas assets. The transaction closed on May 17, 2017. Con sideration for the transaction included 208 million Cenovus Energy common shares. See Note 4 — Assets Held for Sale, Sold or Other Planned Dispositions , for additional information on the Canada disposition . At closing, the fair value and cost basis of our investment in 208 million Cenovus Energy common shares was $ 1.96 billion based on a price of $ 9.41 per share on the New York Stock Exchange . Our ownership approximate s to 16.9 percent of issued and outstanding Cenovus common shares , and under an investor agreement with Cenovus Energy, we have agreed not to transfer any of our Cenovus Energy common shares until six months from the closing date (the “Lock-up Termination Date”). We have classified our investment as an available-for-sale equity security on our consolidated balance sheet and, as of June 30, 2017, our investment is carried at fair value of $ 1.53 billion , reflecting the closing price of Cenovus Energy shares on the New York Stock Exchange of $ 7.37 per share. The carrying value reflects a before- and after-tax unrealized loss of $ 424 million over our cost basis of $ 1 .96 billion . The unrealized loss is reported as a comp onent of accumu lated other comprehensive loss . See Note 14 —Fair Value Measurement , for additional information. Following the Lock-up Termination Date, we intend to decrease our investment over time through market transactions, private agreements or o therwise .

Suspended Wells and Wells in Pr

Suspended Wells and Wells in Progress	6 Months Ended
	Jun. 30, 2017
Suspended Wells [Abstract]
Suspended Wells	Note 7 —Suspended Wells and Other Exploration Expenses The capitalized cost of suspended wells at June 30, 2017 , was $ 860 million, a decrease of $ 203 million from $ 1,063 million at year-end 2016 . Two suspended wells in Shenandoah in the Gulf of Mexico totaling $ 94 million, one suspended well in Alaska totaling $ 17 million , and one suspended well in Malaysia totaling $ 23 million were charged to dry hole expense during the first six months of 2017 relating to exploratory well costs capit alized for a period greater than one year as of December 31, 2016 . We reached a settlement agreement on our contract for the Athena drilling rig, initially secured for our four -well commitment program in Angola. As a result of the cancellation, we recorded a before-tax charge of $ 43 million net in the first quarter of 2017. This charge is included in the “Exploration expenses” line on our consolidated income statement.

Impairments

Impairments	6 Months Ended
	Jun. 30, 2017
Impairment Of Long Lived Assets [Abstract]
Impairments	Note 8—Impairments During the three- and six-month periods ended June 30, 2017 and 2016, we recognized before-tax impairment charges within the following segments: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Alaska $ 3 - 177 - Lower 48 3,885 51 3,885 60 Canada 18 - 18 - Europe and North Africa 4 10 5 137 Asia Pacific and Middle East 2,384 1 2,384 1 $ 6,294 62 6,469 198 In the three-month period ended June 30, 2017, our Lower 48 segment included impairments of $ 3,885 million primarily due to certain developed properties which were classified as held for sale at June 30, 2017, and were written down to fair value less costs to sell . See Note 4 — Assets Held for Sale, Sold or Other Planned Dispositions , for additional information on our dispositions. See the “APLNG” section of Note 5 —Investments, Loans and Long-Term Receivables , for information on the impairm ent of our APLNG investment included within the Asia Pacific and Middle East segment during the three-month period ended June 30, 2017. The six-month period of 2017 included an impairment in our Alaska segment in the first quarter of $ 174 million for the associated PP&E carrying value of our small interest in a nonoperated producing property. Our Europe and North Africa segment included impairments of $ 137 million in the si x-month period of 2016, primarily as a result of lower natural gas prices in the United Kingdom. Our Lower 48 segment included impairments of $ 51 million and $ 60 million respectively, in the three- and six-month periods of 2016, primarily as a result of l ower natural gas prices and increased asset retirement obligation estimates. The charges discussed below are included in the “Exploration expenses” line on our consolidated income statement and are not reflected in the table above. Exploration expenses i n the three- and six-month periods of 2017 and 2016 were aligned with our decision announced in 2015 to reduce deepwater exploration spending. In the first quarter of 2017, we recorded a before-tax impairment of $ 51 million for the associated carrying value of capitalized undeveloped leasehold costs of Shenandoah in deepwater Gulf of Mexico following the suspension of appraisal activity by the operator. In the second quarter of 2016, we recorded a $ 203 million befor e-tax impairment for the associated carrying value of our Gibson and Tiber undeveloped leaseholds in deepwater Gulf of Mexico. Additionally, in the first quarter of 2016, we recorded a $ 95 million before-tax impairment for the associated carrying value of capitalized undeveloped leasehold costs of the Melmar prospect, and a $ 73 million impairment in deepwater Gulf of Mexico, primarily as a result of changes in the estimated market value following the completion of an initial marketing effort.

Debt

Debt	6 Months Ended
	Jun. 30, 2017
Debt [Abstract]
Debt	Note 9 —Debt As of June 30, 2017, our revolving credit facility, expiring in June 2019, was $ 6.75 billion. The credit facility supports two commercial paper programs : the ConocoPhillips $ 6.25 billion program, primarily a funding source for short-term working capital needs, and the ConocoPhillips Qatar Funding Ltd. $ 500 million program, which is used to fund commitments relating to QG3. Commercial paper maturities are generally limited to 90 days. At June 30, 2017 and December 31, 2016 , we had no direct outstanding borrowings under the revolving credit facility and no letters of credit. We had no commercial paper outstanding at June 30, 2017 or December 31, 2016 , u nder both the ConocoPhillips and the ConocoPhillips Qatar Funding Ltd. commercial paper program s . Since we had no commercial paper outstanding and had issued no letters of credit, we had access to $ 6.75 billion in borrowing capacity under our re volving credit facility at June 30, 2017 . In the first quarter of 2017, we made a prepayment of $ 805 million on ou r floating rate term loan facility due in 2019 . We ha ve the right at any time and from time to time to prepay the term loan, in whole or in part, with out premium or penalty upon notic e to the Administrative Agent. The term loan facility contains customary covenants regarding, among other matters, material compliance with laws and restrictions against certain consolidations, mergers and asset sales , and creation of certain liens on our assets and consolidated subsidiaries. The term loan facility also contains financial covenants including a total debt to capitalization ratio, excluding the impacts of certain noncash impairments and foreign currency t ranslation adjustments as defined in the Term Loan Agreement, which may not exceed 65 percent. At June 30, 2017 , we were in compliance with this covenant. The term loan facility includes customary events of default (subject to specified cure periods, mat eriality qualifiers and exceptions), including the failure to pay any interest, principal or fees when due, the failure to perform or the violation of any covenant contained in the term loan facility, the making of materially inaccurate or false representa tions or warranties, a default on certain material indebtedness, insolvency or bankruptcy, a change of control and the occurrence of material Employee Retirement Income Security Act of 1974 (ERISA) events and certain judgments against us or our material su bsidiaries. O n July 5, 2017 , we prepaid the remaining balance of $ 645 million on our floating rate term loan facility. In the second quarter of 2017, we redeemed $ 3.0 billion of debt across the following instruments : 6.65 % Debenture s due 2018 with principal of $ 297 million 5.75 % Notes due 2019 with principal of $ 1.7 billion (partial redemption) 6.00 % Notes due 2020 with principal of $ 1.0 billion We incurred premiums above book value to redeem the debt instruments resulting in $ 234 million of expense which is reported in the “Other e xpense” line on our consolidated income statement. In the second quarter, we gave notice to redeem the following debt instruments totaling $ 1.8 billion. The prepayments will occur on August 1, 2017, and we expect to incur approximately $ 50 million in premiums above book value, subject to pricing, related to these redemptions when paid. 5.20 % Notes due 2018 with principal of $ 500 million 1.50 % Notes due 201 8 with principal of $ 750 million 5.75 % Note s due 20 19 with principal of $ 550 m illion At June 30, 2017, we reclassified $ 2.7 billion from long-term to short-term debt, including the $1.8 b illion of notes and the $645 million term loan facility discussed above. At June 30, 2017 , we had $ 283 million of certain variable rate demand bonds (VRDBs) outstanding with maturities ranging through 2035. The VRDBs are redeemable at the option of the bondholders on any business day. The VRDBs are included in the “Long-term debt” line on our consolidated balance sheet.

Noncontrolling Interests

Noncontrolling Interests	6 Months Ended
	Jun. 30, 2017
Noncontrolling Interests [Abstract]
Noncontrolling Interests	Note 10—Noncontrolling Interests Activity attributable to common stockholders’ equity and noncontrolling interests for the first six months of 2017 and 2016 was as follows: Millions of Dollars 2017 2016 Common Stockholders’ Equity Non-Controlling Interest Total Equity Common Stockholders’ Equity Non-Controlling Interest Total Equity Balance at January 1 $ 34,974 252 35,226 39,762 320 40,082 Net income (loss) (2,854) 27 (2,827) (2,540) 26 (2,514) Dividends (662) - (662) (626) - (626) Repurchase of company common stock (1,075) - (1,075) - - - Distributions to noncontrolling interests - (67) (67) - (59) (59) Other changes, net* (97) 1 (96) 948 - 948 Balance at June 30 $ 30,286 213 30,499 37,544 287 37,831 *Includes components of other comprehensive income (loss), which are disclosed separately in the Consolidated Statement of Comprehensive Income.

Guarantees

Guarantees	6 Months Ended
	Jun. 30, 2017
Guarantees [Abstract]
Guarantees	Note 11 —Guarantees At June 30, 2017 , 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 below, we have not recognized a liability because the fair value of the obligation is immaterial. In addition, unless otherwise stated, we are not currently performing wi th any significance under the guarantee and expect future performance to be either immaterial or have only a remote chance of occurrence. APLNG Guarantees At June 30, 2017 , we had outstanding multiple guarantees in connection with our 37.5 percent ownership interest in APLNG. The following is a description of the guarantees with values calculated utilizing June 2017 exchange rates: We have guaranteed APLNG’s performance with regard to a construction contract executed in connection with APLNG’s issuance of the Train 1 and Train 2 Notices to Proceed. Our maximum potential amount of future payments related to this guarantee became immaterial in the second quarter of 2017. We have issued a construction completion guarantee related to the t hird-party project financing secured by APLNG. In October 2016, we reached financial completion for Train 1, releasing a portion of our guarantee. Our remaining guarantee of the project financing will be released upon completi on of a two-train test with milestones which we estimate should occur in the third quarter of 2017. Our maximum exposure at June 30, 2017 , is $ 1.25 billion based upon our pro-rata share of the facility used at that date. At June 30, 2017 , the carrying value of this guarantee was approximately $ 46 million. During the third quarter of 2016, we issued a guarantee for our pro-rata portion of the funds in a project finance reserve account. We estimate the remaining term of this guarantee is 12 years . Our maximum exposure under this guarantee is approximately $ 100 million and may become payable if an enforcement action is commenced by the project finance lenders against APLNG. At June 30, 2017 , the carrying value of this guarantee was approximately $ 9 million. In conjunction with our original purchase of an ownership interest in APLNG from Origin Energy in October 2008, we agreed to reimburse Origin Energy for our share of the existing contingent liability arising under guarantees of an existing obligation of APLNG to deliver natural gas under several sales agreements with remaining terms of up to 25 years . Our maximum potential liability for future payments, or cost of volume delivery, under these guarantees is estimated to be $ 1 billion ($ 1.74 billion in the event of intentional or reckless breach), and would become payable if APLNG fails to meet its obligations under these agreements and the obligations cannot otherwise be mitigated. Future payments are considered unlikely, as the payments, or cost of volume delivery, would only be triggered if APLNG does not have enough natural gas to meet these sales commitments and if the co-venturers do not make necessary equity contributions into APLNG. We have guaranteed the performance of APLNG with regard to certain other contracts executed in connection with the project’s continued development. The guarantees have remaining terms of up to 28 years or the life of the venture . Our maximum potential amount of future payments related to these guarantees is approximately $ 160 million and would become payable if APLNG does not perform. Other Guarantees We have other guarantees with maximum future potential payment amounts totaling approximately $ 540 million, which consist primarily of a guarantee of the residual value of a leased office building, guarantees of the residual value of leased corporate aircraft, and a guarantee for our portion of a joint venture’s project finance reserve accounts. These guarantees have remaining terms o f up to six years and would become payable if, upon sale, certain asset values are lower than guaranteed amounts, business conditions decline at guaranteed entities, or as a result of nonperformance of contractual terms by guaranteed parties. Indemnifications Over the years, we have entered into agreements to sell ownership interests in certain corporations, joint ventures and assets that gave rise to qualifying indemnifications. These agreements include indemnifications for taxes, environment al liabilities, employee claims 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 ge nerally unlimited. The carrying amount recorded for these indemnifications at June 30, 2017 , was approximately $ 100 million. We amortize the indemnification liability over the relevant time period, if one exists, based on the facts and ci rcumstances surrounding each type of indemnity. In cases where the indemnification term is indefinite, we will reverse the liability when we have information the liability is essentially relieved or amortize the liability over an appropriate time period a s the fair value of our indemnification exposure declines. Although it is reasonably possible 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 recorded carrying amount at June 30, 2017 , were approximately $ 40 million of environmental accruals for known contamination that are included in the “Asset retirement obligations and accrued enviro nmental costs” line on our consolidated balance sheet. For additional information about environmental liabilities, see Note 12 —Contingencies and Commitments. On March 1, 2015, a supplier to one of the refineries included in Phillips 66 as part of the separation of our downstream businesses formally registered Phillips 66 as a party to the supply agreement, thereby triggering a guarantee we provided at the time of separation. Our maximum potential liability for future payments under this guarantee, which would become payable if Phillips 66 does not perform its contractual obligations under the supply agreement, is approximately $ 1.31 billion. At June 30, 2017 , the carrying value of this guarantee is approximately $ 98 million and the remaining term is seven years . Because Phillips 66 has indemnified us for losses incurred under this guarantee, we have recorded an indemnification asset from Phillips 66 of approximately $ 98 million. The recorded indemni fication asset amount represents the estimated fair value of the guarantee; however, if we are required to perform under the guarantee, we would expect to recover from Phillips 66 any amounts in excess of that value, provided Phillips 66 is a going concern .

Contingencies and Commitments

Contingencies and Commitments	6 Months Ended
	Jun. 30, 2017
Contingencies and Commitments [Abstract]
Contingencies and Commitments	Note 12 —Contingencies and Commitments A number of lawsuits involving a variety of claims arising in the ordinary course of business have been filed against ConocoPhillips. We also may be required 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 active and inactive sites. We regularly assess the need for accounting recognition or disclosure of these contingencies. In the ca se of all known contingencies (other than those related to income taxes), we accrue a liability when the loss is probable and the amount is reasonably estimable. If a range of amounts can be reasonably estimated but no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. 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. With respect to income-tax-related contingencies, we use a cumulative probability-weighted loss accrual in cases where sustaining a tax position is less than certain. Based on currently available information, we believe it is remote that future costs rela ted to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with re spect to accrued liabilities and other potential exposures. Estimates 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 factors such 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. Es timated 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 international, federal, state and local environmental laws and regulations. When we prepare our consolidated 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 account stakeholder and business considerations. Whe n 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 consider unasserted claims in our determination of environmental liabilities, and we accrue them in the period they are both probable and reasonably estimable. Although liability of those potentially responsible for environmental remediation costs is generally jo int and several for federal sites and frequently so for other 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 cleanup costs related to any site at which we have been designated as a potentially responsible party. 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 E PA or the agency 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 settle ment 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 we adjust our accruals accordingly. As a resu lt 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 limits an d time limits. We are currently participating in environmental assessments and cleanups at numerous federal Superfund and comparable state and international sites. After an assessment of environmental exposures for cleanup and other costs, we make accrua ls on an undiscounted basis (except those acquired in a purchase business combination, which we record on a discounted basis) for planned investigation and remediation activities for sites where it is probable future costs will be incurred and these costs can be reasonably estimated. At June 30, 2017 , our balance sheet included a total environmental accrual of $ 188 million, compared with $ 247 million at December 31, 2016 , for remediation activities in the United States and Canada. We expect to incur a substantial amount of these expenditures within the next 30 years . In the future, we may be involved in additional environmental assessments, cleanups and proceedings. Legal Proceedings We are subject to various lawsuits and claims including but not limited to matters involving oil and gas royalty and severance tax payments, gas measurement and valuation methods, contract disputes, environmental damages, personal injury, and property damage. Our primary exposures for such matters relate to alleged royalty and tax underpayments on certain federal, state and privately owned properties and claims of alleged environmental contamination from historic operations. We will conti nue to defend ourselves vigorously in these matters. Our legal organization applies its 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 those cases that have been scheduled for trial and/or mediation. Based on professi onal judgment and experience in using these litigation management tools and available information about current developments in all our cases, our legal organization regularly assesses the adequacy of current accruals and determines if adjustment of existi ng accruals, or establishment of new accruals, is required. 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 June 30, 2017 , we had performance obligations secured by letters of credit of $ 265 million (issued as direct bank letters of credit ) related to various purchase commitments for materials, supplies, commercial activities and services incident to the ordinary conduct of business. In 2007, we announced we had been unable to reach agreement with respect to our migration to an empresa mi xta structure mandated by the Venezuelan government’s Nationalization Decree. As a result, Venezuela’s national oil company, Petróleos de Venezuela S.A. (PDVSA), or its affiliates, directly assumed control over ConocoPhillips’ interests in the Petrozuata and Hamaca heavy oil ventures and the offshore Corocoro development project. In response to this expropriation, we filed a request for international arbitration on November 2, 2007, with the World Bank’s International Centre for Settlement of Investment D isputes (ICSID). An arbitration hearing was held before an ICSID tribunal during the summer of 2010. On September 3, 2013, an ICSID arbitration tribunal held that Venezuela unlawfully expropriated ConocoPhillips’ significant oil investments in June 2007. On January 17, 2017, the Tribunal reconfirmed the decision that the expropriation was unlawful. A separate arbitration phase is currently proceeding to determine the damages owed to ConocoPhillips for Venezuela’s actions. Separate arbitrations for cont ractual compensation against PDVSA are also pending before International Chamber of Commerce (ICC) arbitration tribunals. In addition, ConocoPhillips brought fraudulent transfer actions in the U.S. District Court of Delaware, alleging that PDVSA has taken actions to improperly expatriate assets from the United States to Venezuela in an effort to avoid judgment creditors. In 2008, Burlington Resources, Inc ., a wholly owned subsidiary of ConocoPhillips, initiated arbitration before ICSID against The Republi c of Ecuador , as a result of the newly enacted Windfall Profits Tax Law and government-mandated renegotiation of our production sharing contracts. Despite a restraining order issued by the ICSID tribunal, Ecuador confiscated the crude oil production of Bu rlington and its co-venturer and sold the seized crude oil. In 2009, Ecuador took over operations in Blocks 7 and 21, fully expropriating our assets. In June 2010, the ICSID tribunal concluded it has jurisdiction to hear the expropriation claim. On Apri l 24, 2012, Ecuador filed supplemental counterclaims asserting environmental damages, which we believe are not material. The ICSID tribunal issued a decision on liability on December 14, 2012, in favor of Burlington, finding that Ecuador's seizure of Bloc ks 7 and 21 was an unlawful expropriation in violation of the Ecuador-U.S. Bilateral Investment Treaty. In February 2017, the tribunal unanimously awarded Burlington $ 380 million for Ecuador’s unlawful expropriation and breach of the U.S.-Ec uador bilateral investment treaty. The tribunal also issued a separate decision finding Ecuador to be entitled to $ 42 million for limited environmental and infrastructure impacts associated with the operations of Burlington and its co -venturer. Ecuador filed a request for annulment of this decision with ICSID and the annulment phase is ongoing. In December 2016, ConocoPhillips Angola filed a notice of arbitration against Sonangol E.P. under the Block 36 Production Sharing Contract re lating to disputes arising thereunder. The arbitration is being conducted under the United Nations Commission on International Trade Laws (UNCITRAL) rules using a three-person tribunal. The arbitration is ongoing. In June 2017, FAR Ltd. initiated arbitra tion before the ICC against ConocoPhillips Senegal B.V. in connection with the sale of ConocoPhillips Senegal B.V. to Woodside Energy Holdings (Senegal) Limited in 2016. The arbitral tribunal has not yet been constitut ed.

Derivative and Financial Instru

Derivative and Financial Instruments	6 Months Ended
	Jun. 30, 2017
Derivative and Financial Instruments [Abstract]
Derivative and Financial Instruments	Note 13 —Derivative and Financial Instruments Derivative Instruments We use futures, forwards, swaps and options in various markets to meet our customer needs and capture market opportunities. Our commodity business primarily consists of natural gas, crude oil, bitumen, LNG and natural gas liquids. Our derivative instru ments are held at fair value on our consolidated balance sheet. Where these balances have the right of setoff, they are presented on a net basis. Related cash flows are recorded as operating activities on our consolidated statement of cash flows. On our consolidated income statement, realized and unrealized gains and losses are recognized either on a gross basis if directly related to our physical business or a net basis if held for trading. Gains and losses r elated to contracts that meet and are design ated with the normal purchase normal sale exception are recognized upon settlement. We generally apply this exception to eligible crude contracts. We do not use hedge accounting for our commodity derivatives. The following table presents the gross fair values of our commodity derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet: Millions of Dollars June 30 December 31 2017 2016 Assets Prepaid expenses and other current assets $ 196 268 Other assets 42 44 Liabilities Other accruals 182 300 Other liabilities and deferred credits 29 34 The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Sales and other operating revenues $ 52 (163) 103 (166) Other income (1) (3) - (2) Purchased commodities (31) 130 (69) 129 The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts: Open Position Long/(Short) June 30 December 31 2017 2016 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (41) (31) Basis 40 2 Foreign Currency Exchange Derivatives We have foreign currency exchange rate risk resulting from international operations. Our foreign currency exchange derivative activity primarily relates to managing our cash-related and foreign currency exchange rate exposures, such as firm commitments for capital programs or local currency tax payments, dividends, and cash returns from net investments in foreign affiliates. We do not elect hedge accounting on our foreign currency exchan ge derivatives. The following table presents the gross fair values of our foreign currency exchange derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet: Millions of Dollars June 30 December 31 2017 2016 Assets Prepaid expenses and other current assets $ 1 1 Liabilities Other accruals - 168 The (gains) losses from foreign currency exchange derivatives incurred, and the line item where they appear on our consolidated income statement were: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Foreign currency transaction (gains) losses $ (4) 86 3 183 We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency June 30 December 31 2017 2016 Sell U.S. dollar, buy other currencies* USD 28 13 Buy U.S. dollar, sell other currencies** USD - 25 Buy British pound, sell other currencies*** GBP 6 1,069 Sell British pound, buy Norwegian krone GBP - 51 *Primarily Canadian dollar. **Primarily British pound. ***Primarily Euro and Canadian dollar. Financial Instruments We invest excess cash in financial instruments with maturities based on our cash forecasts for the various currency pools we manage. The maturities of these investments may from time to time extend beyond 90 days. The types of financial instruments in which we currently invest include: Time deposits: Interest bearing deposits placed with approved financial institutions. Commercial paper: Unsecured promissory notes issued by a corporation, commercial bank, or government agency p urchased at a discount to mature at par. Government or government agency obligations: Short - term securities issued by the U.S. government or U.S. government agencies. These financial instruments appear in the “Cash and cash equivalents” line of our consol idated balance sheet if the maturities at the time we made the investments were 90 days or less; otherwise, these financial instruments are included in the “Short-term investments” line on our consolidated balance sheet . Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments June 30 December 31 June 30 December 31 2017 2016 2017 2016 Cash $ 779 623 - - Time deposits Remaining maturities from 1 to 90 days 5,316 2,987 1,510 39 Remaining maturities from 91 to 180 days - - 78 11 Commercial paper Remaining maturities from 1 to 90 days 999 - 524 - Remaining maturities from 91 to 180 days - - 621 - Government obligations Remaining maturities from 1 to 90 days 440 - - - $ 7,534 3,610 2,733 50 Credit Risk Financial instruments potentially exposed to concentrations of credit risk consist primarily of cash equivalents, short-term investments, over-the-counter (OTC) derivative contracts and trade receivables. Our cash equivalents and short-term investments are placed in high-quality commercial paper, money market funds, government debt securities and time deposits with major international banks and financial institutions. The credit risk from our OTC derivative contracts, such as forwards and swaps, derives from the counterparty to the transaction. Individual counterparty exposure is managed within predetermined credit limits and includes the use of cash-call margins when appropriate, thereby reducing the risk of significant nonperformance. W e also use futures, swaps and option contracts that have a negligible credit risk because these trades are cleared with an exchange clearinghouse and subject to mandatory margin requirements until settled; however, we are exposed to the credit risk of thos e exchange brokers for receivables arising from daily margin cash calls, as well as for cash deposited to meet initial margin requirements. Our trade receivables result primarily from our petroleum operations and reflect a broad national and internationa l customer base, which limits our exposure to concentrations of credit risk. The majority of these receivables have payment terms of 30 days or less , and we continually monitor this exposure and the creditworthiness of the counterparties. We do not gen erally require collateral to limit the exposure to loss; however, we will sometimes use letters of credit, prepayments and master netting arrangements to mitigate credit risk with counterparties that both buy from and sell to us, as these agreements permit the amounts owed by us or owed to others to be offset against amounts due to us. Certain of our derivative instruments contain provisions that require us to post collateral if the derivative exposure exceeds a threshold amount. We have contracts with fi xed threshold amounts and other contracts with variable threshold amounts that are contingent on our credit rating. The variable threshold amounts typically decline for lower credit ratings, while both the variable and fixed threshold amounts typically re vert to zero if we fall below investment grade. Cash is the primary collateral in all contracts; however, many also permit us to post letters of credit as collateral, such as transactions administered through the New York Mercantile Exchange. The aggrega te fair value of all derivative instruments with such credit-risk-related contingent features that were in a liability position on June 30, 2017 and December 31, 2016 , was $ 37 million and $ 42 million, respectively. For these instruments, no collateral was posted as of June 30, 2017 or D ecember 31, 2016 . If our credit rating had been downgraded below investment grade on June 30, 2017 , we would be required to post $ 37 million of addit ional collateral, either with cash or letters of credit.

Fair Value Measurement

Fair Value Measurement	6 Months Ended
	Jun. 30, 2017
Fair Value Measurement [Abstract]
Fair Value Measurement	Note 14 —Fair Value Measurement We carry a portion of our assets and liabilities at fair value that are measured at a reporting date using an exit price (i.e., the price that would be received to sell an asset or paid to transfer a liability) and disclosed according to the quality of valuation inputs under the following hierarchy: Level 1: Quoted prices (unadjusted) in an active market for identical assets or liabilities. Level 2: Inputs other than quoted prices that are directly or indirectly obs ervable. Level 3: Unobservable inputs that are significant to the fair value of assets or liabilities. The classification of an asset or liability is based on the lowest level of input significant to its fair value. Those that are initially classified as Level 3 are subsequently reported as Level 2 when the fair value derived from unobservable inputs is inconsequential to the overall fair value, or if corroborated market data becomes available. Assets and liabilities initially reported as Level 2 are subsequently reported as Level 3 if corroborated market data is no longer available. Transfers occur at the end of the reporting period. There were no material transfers in or out of Level 1 during 2017 or 2016 . Recurring Fair Value Measurement Financial assets and liabilities reported at fair value on a recurring basis primarily include commodity derivatives. Level 1 derivative assets and liabilities primarily represent exch ange-traded futures and options that are valued using unadjusted prices available from the underlying exchange. Level 2 derivative assets and liabilities primarily represent OTC swaps, options and forward purchase and sale contracts that are valued using adjusted exchange prices, prices provided by brokers or pricing service companies that are all corroborated by market data. This also includes our investment in common shares of Cenovus Energy, currently subject to a trading restriction, which is valued us ing quotes for shares on the New York Stock Exchange . Level 3 derivative assets and liabilities consist of OTC swaps, options and forward purchase and sale contracts where a significant portion of fair value is calculated from underlying market data that is not re adily available. The derived value uses industry standard methodologies that may consider the historical relationships among various commodities, modeled market prices, time value, volatility factors and other relevant economic measures. The use of these inputs results in management’s best estimate of fair value. Level 3 activity was not material for all periods presented. The following table summarizes the fair value hierarchy for gross financial assets and liabilities (i.e., unadjusted where the right of setoff exists for commodity derivatives accounted for at fair value on a recurring basis): Millions of Dollars June 30, 2017 December 31, 2016 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ - 1,533 - 1,533 - - - - Commodity derivatives 130 82 26 238 194 96 22 312 Total assets $ 130 1,615 26 1,771 194 96 22 312 Liabilities Commodity derivatives $ 131 69 11 211 207 105 22 334 Total liabilities $ 131 69 11 211 207 105 22 334 The following table summarizes those commodity derivative balances subject to the right of setoff as presented on our consolidated balance sheet. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements when a legal right of setoff exists. Millions of Dollars Gross Gross Net Gross Amounts Amounts Amounts Amounts Cash without Net Recognized Offset Presented Collateral Right of Setoff Amounts June 30, 2017 Assets $ 238 143 95 - 5 90 Liabilities 211 143 68 3 5 60 December 31, 2016 Assets $ 312 221 91 - 5 86 Liabilities 334 221 113 12 12 89 At June 30, 2017 and December 31, 2016, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff. Non-Recurring Fair Value Measurement The following table summarizes the fair value hierarchy by major category and date of remeasurement for assets accounted for at fair value on a non-recurring basis: Millions of Dollars Fair Value Measurements Using Fair Value Level 1 Inputs Level 3 Inputs Before-Tax Loss June 30, 2017 Net PP&E (held for sale) $ 2,830 2,830 - 3,882 Cost and equity method investments 7,656 - 7,656 2,384 During the second quarter of 2017, net PP&E held for sale was written down to fair value, less costs to sell. The fair value of each asset was determined by its negotiated selling price. For additional information see Note 4 — Assets Held for Sale, Sold or Other Planned Dispositions . During the second quarter of 2017, our equity method investment in APLNG was determined to have fair value below its carrying value, and the impairment was considered to be other than temporary. See the “APLNG” secti on of Note 5 — Investments, Loans and Long-Term Receivables, for information on the impairment of our APLNG investment. Reported Fair Values of Financial Instruments We used the following methods and assumptions to estimate the fair value of financial instruments: Cash and cash equivalents and short-term investments: The carrying amount reported on the balance sheet approximates fair value. Accounts and notes receivable (including long-term and related parties): The carrying amount reported on the balance sheet approximates fair value. The valuation technique and methods used to estimate the fair value of the current portion of fixed-rate related party loans is consistent with Loans and advances—related parties. Investment in Cenovus Energy shares: See Note 6 — Investment in Cenovus Energy for a discussion of the carrying value and fair value of our investment in Cenovus Energy shares. Loans and advances—related parties: The carrying amount of floating-rate loans approximates fair value. The fair value of fixed-rate loan activity is measured using market observable data and is categorized as Level 2 in the fair value hierarchy. See Note 5 —Investments, Loans and Long-Term Receivables, for additional information. Accounts payable (including related parties) and floating-rate debt: The carrying amount of accounts payable and floating-rate debt reported on the balance sheet approximates fair value. Fixed-rate debt: The estimated fair value of fixed-rate debt is measured using prices available from a pricing service that is corroborated by market data; therefore, these liabilities are categorized as Level 2 in the fair value hierarchy. The following table summarizes the net fair value of financial instruments (i.e., adjusted where the right of setoff exists for commodity derivatives): Millions of Dollars Carrying Amount Fair Value June 30 December 31 June 30 December 31 2017 2016 2017 2016 Financial assets Investment in Cenovus Energy $ 1,533 - 1,533 - Commodity derivatives 95 91 95 91 Total loans and advances—related parties 644 701 644 701 Financial liabilities Total debt, excluding capital leases 22,624 26,423 25,501 29,307 Commodity derivatives 65 101 65 101

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	6 Months Ended
	Jun. 30, 2017
Accumulated Other Comprehensive Income [Abstract]
Accumulated Other Comprehensive Income	Note 15—Accumulated Other Comprehensive Loss Accumulated other comprehensive loss in the equity section of our consolidated balance sheet included: Millions of Dollars Defined Benefit Plans Net Unrealized Loss on Securities Foreign Currency Translation Accumulated Other Comprehensive Loss December 31, 2016 $ (547) - (5,646) (6,193) Other comprehensive income (loss) 64 (424) 211 (149) June 30, 2017 $ (483) (424) (5,435) (6,342) There were no items within accumulated other comprehensive loss related to noncontrolling interests. The following table summarizes reclassifications out of accumulated other comprehensive loss: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Defined benefit plans $ 36 42 90 105 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 20 23 47 59 See Note 17 — Employee Benefit Plans, for additional information.

Cash Flow Information

Cash Flow Information	6 Months Ended
	Jun. 30, 2017
Cash Flow Information [Abstract]
Cash Flow Information	Note 16—Cash Flow Information Millions of Dollars Six Months Ended June 30 2017 2016 Cash Payments (Receipts) Interest $ 676 526 Income taxes* 337 (366) Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ (2,952) (1,599) Short-term investments sold 299 307 $ (2,653) (1,292) *Net of $569 million in 2016 related to refunds received from the Internal Revenue Service. During the first quarter of 2017, we recognized a $ 180 million adverse cash impact from the settlement of cross-currency swap transactions which is included in the “Cash Flows From Operating Activities” section of our consolidated statement of cash flows. In April 2017, we received a $ 135 million deposit from an affiliate of Hilcorp Energy Company on the date of signing the definitive agreement to sell our interests in the San Juan Basin . This deposit is included in the “Other” line of the “Cash Flows Fr om Investing Activities” section of our consolidated statement of cash flows. S ee Note 4 — Assets Held for Sale, Sold or Other Planned Dispositions , for additional information on our dispositions.

Employee Benefit Plans

Employee Benefit Plans	6 Months Ended
	Jun. 30, 2017
Employee Benefit Plans [Abstract]
Employee Benefit Plans	Note 17 — Employee Benefit Plans Pension and Postretirement Plans Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int'l. U.S. Int'l. Components of Net Periodic Benefit Cost Three Months Ended June 30 Service cost $ 23 20 28 20 1 - Interest cost 29 25 32 32 2 4 Expected return on plan assets (31) (39) (35) (41) - - Amortization of prior service cost (credit) 1 (2) 1 (2) (9) (8) Recognized net actuarial loss (gain) 17 12 23 7 - (1) Settlements 37 - 45 - - - Net periodic benefit cost $ 76 16 94 16 (6) (5) Six Months Ended June 30 Service cost $ 46 39 55 40 1 1 Interest cost 61 51 72 63 4 7 Expected return on plan assets (65) (78) (78) (82) - - Amortization of prior service cost (credit) 2 (3) 2 (3) (18) (17) Recognized net actuarial loss (gain) 36 24 42 14 (1) (1) Settlements 97 - 127 - - - Net periodic benefit cost $ 177 33 220 32 (14) (10) During the first six months of 2017 , we contributed $ 119 million to our domestic benefit plans and $ 62 million to our international benefit plans. In 2017 , we expect to contribute approximately $ 460 million to our domestic qualified and nonqualified pension and postretirement benefit plans and $ 120 million to our international qualified and nonqualified pension and postretirement benefit plans. W e recognized a proportionate share of prior actuarial losses from ot her comprehensive loss as pension settlement expense of $ 37 million and $ 97 million during the three- and six- month periods ended June 30, 2017 , respectively. Severance Accrual As a result of selling our 50 percent nonoperated interest in the FCCL Partnership as well as the majority of our western Canada gas assets, and entering into a definitive agreement to sell our interests in the San Juan Basin, a reduction in our overall employee workforce began during the second quarter of 2017. Severance accruals of $ 16 million and $ 55 million were recorded during th e three- and six- month period s ended June 30 , 2017. The following table summarizes our severan ce accrual activity for the six - month period ended June 30, 2017 : Millions of Dollars Balance at December 31, 2016 $ 80 Accruals 55 Benefit payments (68) Balance at June 30, 2017 $ 67 Of the remaining balance at June 30, 2017 , $ 43 million is classified as short-term.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2017
Related Party Transactions [Abstract]
Related Party Transactions	Note 18—Related Party Transactions Our related parties primarily include equity method investments and certain trusts for the benefit of employees. Significant transactions with our equity affiliates were: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Operating revenues and other income $ 30 28 59 55 Purchases 25 25 48 49 Operating expenses and selling, general and administrative expenses 14 12 26 28 Net interest (income) expense* (3) (3) (6) (6) *We paid interest to, or received interest from, various affiliates. See Note 5—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Segment Disclosures and Related

Segment Disclosures and Related Information	6 Months Ended
	Jun. 30, 2017
Segment Disclosures and Related Information [Abstract]
Segment Disclosures and Related Information	Note 19 —Segment Disclosures and Related Information We explore for, produce, transport and market crude oil, bitumen, natural gas, LNG and natural gas liquids on a worldwide basis. We manage our operations through six operating segments, which are primarily defined by geographic region: Alaska, Lower 48, Canada, Europe and North Africa, Asia Pacific and Middle East, and Other International. Corporate and Other represents costs not directly associated with an operating segment, such as most interest expense, corporate overhead and certain technology activities, including licensing revenues. Corporate assets include all cas h and cash equivalents and short-term investments. We evaluate performance and allocate resources based on net income (loss) attributable to ConocoPhillips. Intersegment sales are at prices that approximate market. Analysis of Results by Operating Segment Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Sales and Other Operating Revenues Alaska $ 1,071 936 2,078 1,714 Lower 48 3,090 2,395 6,320 4,540 Intersegment eliminations (2) (5) (5) (12) Lower 48 3,088 2,390 6,315 4,528 Canada 788 391 1,658 816 Intersegment eliminations (89) (30) (175) (65) Canada 699 361 1,483 751 Europe and North Africa 1,011 736 2,454 1,659 Asia Pacific and Middle East 896 897 1,918 1,734 Corporate and Other 16 28 51 83 Consolidated sales and other operating revenues $ 6,781 5,348 14,299 10,469 Net Income (Loss) Attributable to ConocoPhillips Alaska $ 199 147 188 145 Lower 48 (2,536) (771) (2,898) (1,591) Canada 1,379 (175) 2,327 (469) Europe and North Africa 123 20 294 (31) Asia Pacific and Middle East (2,172) 72 (1,936) 67 Other International (9) (29) (57) (53) Corporate and Other (424) (335) (772) (608) Consolidated net loss attributable to ConocoPhillips $ (3,440) (1,071) (2,854) (2,540) Millions of Dollars June 30 December 31 2017 2016 Total Assets Alaska $ 12,163 12,314 Lower 48 17,637 22,673 Canada 6,122 17,548 Europe and North Africa 11,564 11,727 Asia Pacific and Middle East 17,389 20,451 Other International 116 97 Corporate and Other 13,013 4,962 Consolidated total assets $ 78,004 89,772

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2017
Income Taxes [Abstract]
Income Taxes	Note 20 —Income Taxes Our effective tax rates for the second quarter and six -month period ended June 30, 2017 , were 21 percent and 38 percent, respectively, compared with 36 percent and 35 percent for the same periods of 2016 . The amounts of U.S. and foreign income (loss) from continuing operations before income taxes, with a reconciliation of tax at the federal statutory rate with the provision for income taxes were: Millions of Dollars Percent of Pre-Tax Income (Loss) Three Months Ended June 30 Six Months Ended June 30 Three Months Ended June 30 Six Months Ended June 30 2017 2016 2017 2016 2017 2016 2017 2016 Income (loss) from continuing operations before income taxes United States $ (4,269) (1,373) (5,063) (2,964) 97.9 % 83.5 110.2 76.6 Foreign (92) (271) 470 (904) 2.1 16.5 (10.2) 23.4 $ (4,361) (1,644) (4,593) (3,868) 100.0 % 100.0 100.0 100.0 Federal statutory income tax $ (1,526) (575) (1,608) (1,354) 35.0 % 35.0 35.0 35.0 Non-U.S. effective tax rates 69 104 335 173 (1.6) (6.3) (7.3) (4.5) Canada disposition (172) - (1,168) - 3.9 - 25.4 - Recovery of outside basis (4) (12) (839) (23) 0.1 0.7 18.3 0.6 Adjustment to tax reserves - - 822 - - - (17.9) - APLNG impairment 834 - 834 - (19.1) - (18.2) - State income tax (99) (78) (88) (110) 2.3 4.7 1.9 2.8 Enhanced oil recovery credit (29) (17) (45) (34) 0.7 1.0 1.0 0.9 Other (8) (8) (9) (6) 0.1 0.5 0.2 0.2 $ (935) (586) (1,766) (1,354) 21.4 % 35.6 38.4 35.0 The impairment of our APLNG investment did not generate a tax benefit. See the “APLNG” section of Note 5 —Investments, Loans and Long-Term Receivables, for information on the impairment of our APLNG investment. Our effective tax rate for the second quarter and six -month period ended June 30, 2017 , was favorably impacted by tax benefits of $ 172 million and $ 1,168 million , respectively, associated with our Canada disposition. The benefit was primarily associated with a deferred ta x recovery related to the Canadian capital gains exclusion component of the transaction and the recognition of previously unrealizable Canadian capital asset tax basis. The disposition, along with the associated restructuring of our Canadian operations, m ay generate an additional tax benefit of $ 822 million related to the recovery of outside basis . However, since we believe it is not likely we will receive a corresponding cash tax savings of this amount, the benefit has been offset by a full reserve. See Note 4 — Assets Held for Sale, Sold or Other Planned Dispositions , for additional information on our Canada disposition . During the second quarter of 2016, previously unrecognized state deferred tax assets were recognized. As a result, a $68 million tax benefit is reflected in the “Income tax benefit” line on our consolidated income statement.

New Accounting Standards

New Accounting Standards	6 Months Ended
	Jun. 30, 2017
New Accounting Standards [Abstract]
Description of New Accounting Pronouncements Not yet Adopted [Text Block]	Note 21 — New Accounting Standards In May 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers” (ASU No. 2014-09), which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers. This ASU supersedes the revenue recognition requirements in FASB ASC Topic 605, “Revenue Recognition,” and most industry-specific guidance. This ASU sets forth a five-step model for determining when and how revenue is recognized. Under the model, an entity will be required to recognize revenue to depict the transfer of goods or services to a customer at an amount reflecting the consideration it expects to receive in exchange for those goods or services. Add itional disclosures will be required to describe the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. In August 2015, the FASB issued ASU No. 2015-14, “Deferral of the Effective Date,” which defers the ef fective date of ASU No. 2014-09. The ASU is now effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted for interim and annual periods beginning after December 15, 2016. Entities may choose to adopt the st andard using either a full retrospective approach or a modified retrospective approach. ASU No. 2014-09 was amended in March 2016 by the provisions of ASU No. 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” in Apr il 2016 by the provisions of ASU No. 2016-10, “Identifying Performance Obligations and Licensing,” in May 2016 by the provisions of ASU No. 2016-12, “Narrow-Scope Improvements and Practical Expedients,” and in December 2016 by the provisions of ASU No. 201 6-20, “Technical Corrections and Improvements to Topic 606, Revenue From Contracts With Customers.” We will adopt the provisions of ASU No. 2014-09, as amended, with effect from January 1, 2018, and have elected not to early adopt the standard. We inten d to adopt the new standard using the modified retrospective approach which we will apply only to contracts within the scope of the standard that are not complete at the date of initial application. Under this approach, we will apply the guidance retrospe ctively only to the most current period presented in the financial statements. We continue to assess the impact of adoption of the standard on our current accounting policies and revenue-related disclosures. The impact to our financial statements is expe cted to be immaterial. In January 2016, the FASB issued ASU No. 2016-01, “Recognition and Measurement of Financial Assets and Financial Liabilities” (ASU No. 2016-01), to meet its objective of providing more decision-useful information about financial ins truments. The ASU, among other things, requires entities to record the changes in fair value of equity investments, other than investments accounted for using the equity method, within net income. Under this ASU, entities will no longer be able to recogn ize unrealized holding gains and losses on available-for-sale securities in other comprehensive income. The ASU also requires additional disclosures relating to fair value measurement categories for financial assets and liabilities and eliminates certain disclosure requirements related to financial instruments measured at amortized cost. ASU No. 2016-01 is effective for interim and annual periods beginning after December 15, 2017 , and the ASU should be adopted using a cumulative-effect adjustment to retai ned earnings as of the date of adoption. Upon adoption of the standard, we will make a cumulative-effect adjustment to reclassify the accumulated unrealized holding gains and losses related to our investment in Cenovus Energy from other comprehensive inc ome to retained earnings, and from the date of adoption, we will begin reporting the changes in the fair value of our investment within net income. The impact on our consolidated financial statements and disclosures will depend on the amount of accumulate d unrealized holding gains and losses recognized in other comprehensive income at December 31, 2017, and changes in the fair value of our investment in Cenovus Energy subsequent to that date. For additional information on our investment in Cenovus Energy, see Note 6 — Investment in Cenovus Energy , Note 14 — Fair Value Measurement, and Note 15 — Accumulated Other Comprehensive Loss. In February 2016, the FASB issued ASU No. 2016-02, “Leases” (ASU No. 2016-02), which establishes comprehensive accounting and financial reporting requirements for leasing arrangements. This ASU supersedes the existing requirements in FASB ASC Topic 840, “Leases,” and requires lessees to recognize substantially all lease assets and lease liabilities on the balance sheet. The provisions of ASU No. 2016-02 also modify the definition of a lease and outline requirements for recognition, measurement, presentation and disclosure of leasing arrangements by both lessees and lessors. The ASU is effective for interim and an nual periods beginning after December 15, 2018, and early adoption of the standard is permitted. Entities are required to adopt the ASU using a modified retrospective approach, subject to certain optional practical expedients, and apply the provisions of ASU No. 2016-02 to leasing arrangements existing at or entered into after the earliest comparative period presented in the financial statements. While we continue to evaluate the ASU, we expect the adoption of the ASU to have a material impact on our con solidated financial statements and disclosures. In June 2016, the FASB issued ASU No. 2016-13, “Measurement of Credit Losses on Financial Instruments” (ASU No. 2016-13), which sets forth the current expected credit loss model, a new forward-looking impa irment model for certain financial instruments based on expected losses rather than incurred losses. The ASU is effective for interim and annual periods beginning after December 15, 2019, and early adoption of the standard is permitted. Entities are requ ired to adopt ASU No. 2016-13 using a modified retrospective approach, subject to certain limited exceptions. We are currently evaluating the impact of the adoption of this ASU.

Supplementary Information - Con

Supplementary Information - Condensed Consolidating Financial Information	6 Months Ended
	Jun. 30, 2017
Supplementary Information - Condensed Consolidating Financial Information [Abstract]
Supplementary Information - Condensed Consolidating Financial Information	Supplementary Information —Condensed Consolidating Financial Information We have various cross guarantees among ConocoPhillips, ConocoPhillips Company and ConocoPhillips Canada Funding Company I, with respect to publicly held debt securities. ConocoPhillips Company is 100 percent owned by ConocoPhillips. ConocoPhillips Canada Funding Company I is an indirect, 100 percent owned subsidiary of ConocoPhillips Company. ConocoPhillips and /or ConocoPhill ips Company have fully and unconditionally guaranteed the payment obligations of ConocoPhillips Canada Funding Company I, with respect to its publicly held debt securities. Similarly, ConocoPhillips has fully and unconditionally guaranteed the payment obl igations of ConocoPhillips Company with respect to its publicly held debt securities. In addition, ConocoPhillips Company has fully and unconditionally guaranteed the payment obligations of ConocoPhillips with respect to its publicly held debt securities. All guarantees are joint and several. The following condensed consolidating financial information presents the results of operations, financial position and cash flows for: ConocoPhillips, ConocoPhillips Company and ConocoPhillips Canada Funding Compan y I (in each case, reflecting investments in subsidiaries utilizing the equity method of accounting). All other nonguarantor subsidiaries of ConocoPhillips. The consolidating adjustments necessary to present ConocoPhillips’ results on a consolidated basis. In May 2017, ConocoPhillips Company received a $9.8 billion return of capital from a nonguarantor subsidiary to settle certain accumulated intercompany balances. The transaction had no impact on our consolidated financial statements. This condensed consolidating financial information should be read in conjunction with the accompanying consolidated financial statements and notes. Millions of Dollars Three Months Ended June 30, 2017 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 2,954 - 3,827 - 6,781 Equity in earnings (losses) of affiliates (3,235) (2,297) - 153 5,557 178 Gain on dispositions - 16 - 1,860 - 1,876 Other income 1 13 - 33 - 47 Intercompany revenues 12 74 41 792 (919) - Total Revenues and Other Income (3,222) 760 41 6,665 4,638 8,882 Costs and Expenses Purchased commodities - 2,637 - 1,038 (753) 2,922 Production and operating expenses - 139 - 1,189 (1) 1,327 Selling, general and administrative expenses 2 110 - 22 - 134 Exploration expenses - 33 - 65 - 98 Depreciation, depletion and amortization - 204 - 1,421 - 1,625 Impairments - 1,074 - 5,220 - 6,294 Taxes other than income taxes - 36 - 162 - 198 Accretion on discounted liabilities - 10 - 82 - 92 Interest and debt expense 125 171 36 139 (165) 306 Foreign currency transaction (gains) losses (15) 2 19 7 - 13 Other expenses 217 17 - - - 234 Total Costs and Expenses 329 4,433 55 9,345 (919) 13,243 Loss before income taxes (3,551) (3,673) (14) (2,680) 5,557 (4,361) Income tax provision (benefit) (111) (438) 11 (397) - (935) Net loss (3,440) (3,235) (25) (2,283) 5,557 (3,426) Less: net income attributable to noncontrolling interests - - - (14) - (14) Net Loss Attributable to ConocoPhillips $ (3,440) (3,235) (25) (2,297) 5,557 (3,440) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (3,821) (3,616) 30 (2,263) 5,849 (3,821) Income Statement Three Months Ended June 30, 2016 Revenues and Other Income Sales and other operating revenues $ - 2,284 - 3,064 - 5,348 Equity in earnings (losses) of affiliates (1,003) (21) - 145 959 80 Gain on dispositions - 63 - 65 - 128 Other income - 1 - 18 - 19 Intercompany revenues 26 68 60 928 (1,082) - Total Revenues and Other Income (977) 2,395 60 4,220 (123) 5,575 Costs and Expenses Purchased commodities - 1,998 - 682 (678) 2,002 Production and operating expenses - 488 - 1,191 (234) 1,445 Selling, general and administrative expenses 2 136 - 29 - 167 Exploration expenses - 551 - 59 - 610 Depreciation, depletion and amortization - 306 - 2,023 - 2,329 Impairments - 37 - 25 - 62 Taxes other than income taxes - 39 - 158 - 197 Accretion on discounted liabilities - 12 - 100 - 112 Interest and debt expense 126 164 57 135 (170) 312 Foreign currency transaction (gains) losses 2 - (79) 60 - (17) Total Costs and Expenses 130 3,731 (22) 4,462 (1,082) 7,219 Income (Loss) before income taxes (1,107) (1,336) 82 (242) 959 (1,644) Income tax provision (benefit) (36) (333) 19 (236) - (586) Net income (loss) (1,071) (1,003) 63 (6) 959 (1,058) Less: net income attributable to noncontrolling interests - - - (13) - (13) Net Income (Loss) Attributable to ConocoPhillips $ (1,071) (1,003) 63 (19) 959 (1,071) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (1,296) (1,228) 51 (215) 1,392 (1,296) Millions of Dollars Six Months Ended June 30, 2017 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 6,069 - 8,230 - 14,299 Equity in earnings (losses) of affiliates (2,578) (1,124) - 313 3,767 378 Gain on dispositions - 29 - 1,869 - 1,898 Other income 1 15 - 62 - 78 Intercompany revenues 29 145 83 1,586 (1,843) - Total Revenues and Other Income (2,548) 5,134 83 12,060 1,924 16,653 Costs and Expenses Purchased commodities - 5,402 - 2,228 (1,516) 6,114 Production and operating expenses - 280 - 2,347 (2) 2,625 Selling, general and administrative expenses 6 246 - 44 (5) 291 Exploration expenses - 405 - 244 - 649 Depreciation, depletion and amortization - 455 - 3,149 - 3,604 Impairments - 1,074 - 5,395 - 6,469 Taxes other than income taxes - 85 - 344 - 429 Accretion on discounted liabilities - 20 - 167 - 187 Interest and debt expense 254 336 73 278 (320) 621 Foreign currency transaction (gains) losses (22) 2 68 (25) - 23 Other expense 217 17 - - - 234 Total Costs and Expenses 455 8,322 141 14,171 (1,843) 21,246 Loss before income taxes (3,003) (3,188) (58) (2,111) 3,767 (4,593) Income tax provision (benefit) (149) (610) 6 (1,013) - (1,766) Net loss (2,854) (2,578) (64) (1,098) 3,767 (2,827) Less: net income attributable to noncontrolling interests - - - (27) - (27) Net Loss Attributable to ConocoPhillips $ (2,854) (2,578) (64) (1,125) 3,767 (2,854) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (3,003) (2,727) 17 (901) 3,611 (3,003) Income Statement Six Months Ended June 30, 2016 Revenues and Other Income Sales and other operating revenues $ - 4,356 - 6,113 - 10,469 Equity in earnings of affiliates (2,430) (771) - (299) 3,431 (69) Gain on dispositions - 85 - 66 - 151 Other income (loss) - (5) - 44 - 39 Intercompany revenues 44 149 116 1,453 (1,762) - Total Revenues and Other Income (2,386) 3,814 116 7,377 1,669 10,590 Costs and Expenses Purchased commodities - 3,846 - 1,561 (1,180) 4,227 Production and operating expenses - 741 - 2,295 (237) 2,799 Selling, general and administrative expenses 5 290 - 64 (6) 353 Exploration expenses - 982 - 133 - 1,115 Depreciation, depletion and amortization - 563 - 4,013 - 4,576 Impairments - 41 - 157 - 198 Taxes other than income taxes - 96 - 281 - 377 Accretion on discounted liabilities - 24 - 197 - 221 Interest and debt expense 250 298 112 272 (339) 593 Foreign currency transaction (gains) losses (42) 2 233 (194) - (1) Total Costs and Expenses 213 6,883 345 8,779 (1,762) 14,458 Loss before income taxes (2,599) (3,069) (229) (1,402) 3,431 (3,868) Income tax provision (benefit) (59) (639) 1 (657) - (1,354) Net loss (2,540) (2,430) (230) (745) 3,431 (2,514) Less: net income attributable to noncontrolling interests - - - (26) - (26) Net Loss Attributable to ConocoPhillips $ (2,540) (2,430) (230) (771) 3,431 (2,540) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (1,664) (1,554) 4 230 1,320 (1,664) Millions of Dollars June 30, 2017 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Assets Cash and cash equivalents $ - 1,162 34 6,338 - 7,534 Short-term investments - - - 2,733 - 2,733 Accounts and notes receivable 82 1,656 35 3,608 (2,218) 3,163 Investment in Cenovus Energy - 1,533 - - - 1,533 Inventories - 112 - 907 - 1,019 Prepaid expenses and other current assets 1 436 7 3,480 (27) 3,897 Total Current Assets 83 4,899 76 17,066 (2,245) 19,879 Investments, loans and long-term receivables* 34,470 56,453 2,377 18,838 (101,935) 10,203 Net properties, plants and equipment - 4,330 - 42,516 - 46,846 Other assets 43 2,906 203 1,235 (3,311) 1,076 Total Assets $ 34,596 68,588 2,656 79,655 (107,491) 78,004 Liabilities and Stockholders’ Equity Accounts payable $ - 2,357 2 3,293 (2,218) 3,434 Short-term debt 1,688 2,000 6 104 - 3,798 Accrued income and other taxes - 76 - 715 - 791 Employee benefit obligations - 382 - 127 - 509 Other accruals 102 680 45 594 (27) 1,394 Total Current Liabilities 1,790 5,495 53 4,833 (2,245) 9,926 Long-term debt 3,784 11,338 1,706 2,842 - 19,670 Asset retirement obligations and accrued environmental costs - 560 - 7,071 - 7,631 Deferred income taxes - - - 9,111 (2,776) 6,335 Employee benefit obligations - 1,874 - 625 - 2,499 Other liabilities and deferred credits* 5,298 8,972 824 15,285 (28,935) 1,444 Total Liabilities 10,872 28,239 2,583 39,767 (33,956) 47,505 Retained earnings 21,510 11,437 (605) 10,852 (15,161) 28,033 Other common stockholders’ equity 2,214 28,912 678 28,823 (58,374) 2,253 Noncontrolling interests - - - 213 - 213 Total Liabilities and Stockholders’ Equity $ 34,596 68,588 2,656 79,655 (107,491) 78,004 *Includes intercompany loans. Balance Sheet December 31, 2016 Assets Cash and cash equivalents $ - 358 13 3,239 - 3,610 Short-term investments - - - 50 - 50 Accounts and notes receivable 22 1,968 23 6,103 (4,702) 3,414 Inventories - 84 - 934 - 1,018 Prepaid expenses and other current assets 2 116 8 415 (24) 517 Total Current Assets 24 2,526 44 10,741 (4,726) 8,609 Investments, loans and long-term receivables* 37,901 64,434 2,296 31,643 (114,602) 21,672 Net properties, plants and equipment - 6,301 - 52,030 - 58,331 Other assets 40 2,194 220 1,240 (2,534) 1,160 Total Assets $ 37,965 75,455 2,560 95,654 (121,862) 89,772 Liabilities and Stockholders’ Equity Accounts payable $ - 4,683 1 3,671 (4,702) 3,653 Short-term debt (10) 999 6 94 - 1,089 Accrued income and other taxes - 85 - 399 - 484 Employee benefit obligations - 489 - 200 - 689 Other accruals 171 271 40 536 (24) 994 Total Current Liabilities 161 6,527 47 4,900 (4,726) 6,909 Long-term debt 8,975 12,635 1,710 2,866 - 26,186 Asset retirement obligations and accrued environmental costs - 925 - 7,500 - 8,425 Deferred income taxes - - - 10,972 (2,023) 8,949 Employee benefit obligations - 1,901 - 651 - 2,552 Other liabilities and deferred credits* 417 10,391 748 17,832 (27,863) 1,525 Total Liabilities 9,553 32,379 2,505 44,721 (34,612) 54,546 Retained earnings 25,025 14,015 (541) 12,883 (19,834) 31,548 Other common stockholders’ equity 3,387 29,061 596 37,798 (67,416) 3,426 Noncontrolling interests - - - 252 - 252 Total Liabilities and Stockholders’ Equity $ 37,965 75,455 2,560 95,654 (121,862) 89,772 *Includes intercompany loans. Millions of Dollars Six Months Ended June 30, 2017 Statement of Cash Flows ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (137) (1,475) 21 5,926 (794) 3,541 Cash Flows From Investing Activities Capital expenditures and investments - (1,125) - (1,729) 868 (1,986) Working capital changes associated with investing activities - 39 - (152) - (113) Proceeds from asset dispositions - 9,909 - 10,716 (9,883) 10,742 Purchases of short-term investments - - - (2,653) - (2,653) Long-term advances/loans—related parties - (63) - (20) 83 - Collection of advances/loans—related parties 658 63 - 2,138 (2,802) 57 Intercompany cash management 4,882 (4,214) - (668) - - Other - 43 - 133 - 176 Net Cash Provided by Investing Activities 5,540 4,652 - 7,765 (11,734) 6,223 Cash Flows From Financing Activities Issuance of debt - 20 - 63 (83) - Repayment of debt (3,717) (2,394) - (770) 2,802 (4,079) Issuance of company common stock 49 - - - (112) (63) Repurchase of company common stock (1,075) - - - - (1,075) Dividends paid (662) - - (906) 906 (662) Other 2 - - (9,081) 9,015 (64) Net Cash Used in Financing Activities (5,403) (2,374) - (10,694) 12,528 (5,943) Effect of Exchange Rate Changes on Cash and Cash Equivalents - 1 - 102 - 103 Net Change in Cash and Cash Equivalents - 804 21 3,099 - 3,924 Cash and cash equivalents at beginning of period - 358 13 3,239 - 3,610 Cash and Cash Equivalents at End of Period $ - 1,162 34 6,338 - 7,534 Statement of Cash Flows Six Months Ended June 30, 2016 Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (153) 572 (5) 2,229 (963) 1,680 Cash Flows From Investing Activities Capital expenditures and investments - (823) - (2,532) 401 (2,954) Working capital changes associated with investing activities - (76) - (287) - (363) Proceeds from asset dispositions 2,300 160 - 227 (2,324) 363 Purchases of short-term investments - - - (1,292) - (1,292) Long-term advances/loans—related parties - (803) - - 803 - Collection of advances/loans—related parties - - - 1,626 (1,573) 53 Intercompany cash management (3,190) 2,127 - 1,063 - - Other - 2 - 4 - 6 Net Cash Provided by (Used in) Investing Activities (890) 587 - (1,191) (2,693) (4,187) Cash Flows From Financing Activities Issuance of debt 1,600 2,994 - 803 (803) 4,594 Repayment of debt - (1,573) - (827) 1,573 (827) Issuance of company common stock 70 - - - (115) (45) Dividends paid (626) - - (1,078) 1,078 (626) Other (1) (2,319) - 318 1,923 (79) Net Cash Provided by (Used in) Financing Activities 1,043 (898) - (784) 3,656 3,017 Effect of Exchange Rate Changes on Cash and Cash Equivalents - - - (15) - (15) Net Change in Cash and Cash Equivalents - 261 (5) 239 - 495 Cash and cash equivalents at beginning of period - 4 15 2,349 - 2,368 Cash and Cash Equivalents at End of Period $ - 265 10 2,588 - 2,863

Inventories (Tables)

Inventories (Tables)	6 Months Ended
	Jun. 30, 2017
Inventories [Abstract]
Inventories	Note 3—Inventories Inventories consisted of the following: Millions of Dollars June 30 December 31 2017 2016 Crude oil and natural gas $ 447 418 Materials and supplies 572 600 $ 1,019 1,018

Impairments (Tables)

Impairments (Tables)	6 Months Ended
	Jun. 30, 2017
Impairment Of Long Lived Assets [Abstract]
Impairment charges by segment before tax.	Note 8—Impairments During the three- and six-month periods ended June 30, 2017 and 2016, we recognized before-tax impairment charges within the following segments: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Alaska $ 3 - 177 - Lower 48 3,885 51 3,885 60 Canada 18 - 18 - Europe and North Africa 4 10 5 137 Asia Pacific and Middle East 2,384 1 2,384 1 $ 6,294 62 6,469 198

Noncontrolling Interests (Table

Noncontrolling Interests (Tables)	6 Months Ended
	Jun. 30, 2017
Noncontrolling Interests [Abstract]
Change in equity attributable to non-controlling interests	Note 10—Noncontrolling Interests Activity attributable to common stockholders’ equity and noncontrolling interests for the first six months of 2017 and 2016 was as follows: Millions of Dollars 2017 2016 Common Stockholders’ Equity Non-Controlling Interest Total Equity Common Stockholders’ Equity Non-Controlling Interest Total Equity Balance at January 1 $ 34,974 252 35,226 39,762 320 40,082 Net income (loss) (2,854) 27 (2,827) (2,540) 26 (2,514) Dividends (662) - (662) (626) - (626) Repurchase of company common stock (1,075) - (1,075) - - - Distributions to noncontrolling interests - (67) (67) - (59) (59) Other changes, net* (97) 1 (96) 948 - 948 Balance at June 30 $ 30,286 213 30,499 37,544 287 37,831 *Includes components of other comprehensive income (loss), which are disclosed separately in the Consolidated Statement of Comprehensive Income.

Derivative and Financial Inst32

Derivative and Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2017
Derivative and Financial Instruments [Abstract]
Balance sheet location and fair value amounts of derivatives	The following table presents the gross fair values of our commodity derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet: Millions of Dollars June 30 December 31 2017 2016 Assets Prepaid expenses and other current assets $ 196 268 Other assets 42 44 Liabilities Other accruals 182 300 Other liabilities and deferred credits 29 34 The following table presents the gross fair values of our foreign currency exchange derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet: Millions of Dollars June 30 December 31 2017 2016 Assets Prepaid expenses and other current assets $ 1 1 Liabilities Other accruals - 168
Income statement location and gain/loss amounts of derivatives	The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Sales and other operating revenues $ 52 (163) 103 (166) Other income (1) (3) - (2) Purchased commodities (31) 130 (69) 129 The (gains) losses from foreign currency exchange derivatives incurred, and the line item where they appear on our consolidated income statement were: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Foreign currency transaction (gains) losses $ (4) 86 3 183
Net exposures from outstanding commodity derivative contracts	The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts: Open Position Long/(Short) June 30 December 31 2017 2016 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (41) (31) Basis 40 2 We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency June 30 December 31 2017 2016 Sell U.S. dollar, buy other currencies* USD 28 13 Buy U.S. dollar, sell other currencies** USD - 25 Buy British pound, sell other currencies*** GBP 6 1,069 Sell British pound, buy Norwegian krone GBP - 51 *Primarily Canadian dollar. **Primarily British pound. ***Primarily Euro and Canadian dollar.
Balances of financial instruments	Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments June 30 December 31 June 30 December 31 2017 2016 2017 2016 Cash $ 779 623 - - Time deposits Remaining maturities from 1 to 90 days 5,316 2,987 1,510 39 Remaining maturities from 91 to 180 days - - 78 11 Commercial paper Remaining maturities from 1 to 90 days 999 - 524 - Remaining maturities from 91 to 180 days - - 621 - Government obligations Remaining maturities from 1 to 90 days 440 - - - $ 7,534 3,610 2,733 50

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	6 Months Ended
	Jun. 30, 2017
Fair Value Measurement [Abstract]
Fair value hierarchy for gross financial assets and liabilities	Millions of Dollars June 30, 2017 December 31, 2016 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ - 1,533 - 1,533 - - - - Commodity derivatives 130 82 26 238 194 96 22 312 Total assets $ 130 1,615 26 1,771 194 96 22 312 Liabilities Commodity derivatives $ 131 69 11 211 207 105 22 334 Total liabilities $ 131 69 11 211 207 105 22 334
Commodity derivative balances subject to right of setoff	The following table summarizes those commodity derivative balances subject to the right of setoff as presented on our consolidated balance sheet. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements when a legal right of setoff exists. Millions of Dollars Gross Gross Net Gross Amounts Amounts Amounts Amounts Cash without Net Recognized Offset Presented Collateral Right of Setoff Amounts June 30, 2017 Assets $ 238 143 95 - 5 90 Liabilities 211 143 68 3 5 60 December 31, 2016 Assets $ 312 221 91 - 5 86 Liabilities 334 221 113 12 12 89 At June 30, 2017 and December 31, 2016, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff.
Values of assets, by major category, measured at fair value on a nonrecurring basis	Non-Recurring Fair Value Measurement The following table summarizes the fair value hierarchy by major category and date of remeasurement for assets accounted for at fair value on a non-recurring basis: Millions of Dollars Fair Value Measurements Using Fair Value Level 1 Inputs Level 3 Inputs Before-Tax Loss June 30, 2017 Net PP&E (held for sale) $ 2,830 2,830 - 3,882 Cost and equity method investments 7,656 - 7,656 2,384
Net fair value of financial instruments	The following table summarizes the net fair value of financial instruments (i.e., adjusted where the right of setoff exists for commodity derivatives): Millions of Dollars Carrying Amount Fair Value June 30 December 31 June 30 December 31 2017 2016 2017 2016 Financial assets Investment in Cenovus Energy $ 1,533 - 1,533 - Commodity derivatives 95 91 95 91 Total loans and advances—related parties 644 701 644 701 Financial liabilities Total debt, excluding capital leases 22,624 26,423 25,501 29,307 Commodity derivatives 65 101 65 101

Accumulated Other Comprehensi34

Accumulated Other Comprehensive Income (Tables)	6 Months Ended
	Jun. 30, 2017
Accumulated Other Comprehensive Income [Abstract]
Components of accumulated other comprehensive income in the equity section of the balance sheet	Note 15—Accumulated Other Comprehensive Loss Accumulated other comprehensive loss in the equity section of our consolidated balance sheet included: Millions of Dollars Defined Benefit Plans Net Unrealized Loss on Securities Foreign Currency Translation Accumulated Other Comprehensive Loss December 31, 2016 $ (547) - (5,646) (6,193) Other comprehensive income (loss) 64 (424) 211 (149) June 30, 2017 $ (483) (424) (5,435) (6,342)
Items reclassified out of accumulated other comprehensive income (loss)	The following table summarizes reclassifications out of accumulated other comprehensive loss: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Defined benefit plans $ 36 42 90 105 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 20 23 47 59 See Note 17 — Employee Benefit Plans, for additional information.

Cash Flow Information (Tables)

Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2017
Cash Flow Information [Abstract]
Cash Flow Information	Note 16—Cash Flow Information Millions of Dollars Six Months Ended June 30 2017 2016 Cash Payments (Receipts) Interest $ 676 526 Income taxes* 337 (366) Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ (2,952) (1,599) Short-term investments sold 299 307 $ (2,653) (1,292) *Net of $569 million in 2016 related to refunds received from the Internal Revenue Service.

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	6 Months Ended
	Jun. 30, 2017
Employee Benefit Plans [Abstract]
Pension and Postretirement Plans	Note 17 — Employee Benefit Plans Pension and Postretirement Plans Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int'l. U.S. Int'l. Components of Net Periodic Benefit Cost Three Months Ended June 30 Service cost $ 23 20 28 20 1 - Interest cost 29 25 32 32 2 4 Expected return on plan assets (31) (39) (35) (41) - - Amortization of prior service cost (credit) 1 (2) 1 (2) (9) (8) Recognized net actuarial loss (gain) 17 12 23 7 - (1) Settlements 37 - 45 - - - Net periodic benefit cost $ 76 16 94 16 (6) (5) Six Months Ended June 30 Service cost $ 46 39 55 40 1 1 Interest cost 61 51 72 63 4 7 Expected return on plan assets (65) (78) (78) (82) - - Amortization of prior service cost (credit) 2 (3) 2 (3) (18) (17) Recognized net actuarial loss (gain) 36 24 42 14 (1) (1) Settlements 97 - 127 - - - Net periodic benefit cost $ 177 33 220 32 (14) (10)
Severance accrual	Millions of Dollars Balance at December 31, 2016 $ 80 Accruals 55 Benefit payments (68) Balance at June 30, 2017 $ 67

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2017
Related Party Transactions [Abstract]
Significant transactions with related parties	Note 18—Related Party Transactions Our related parties primarily include equity method investments and certain trusts for the benefit of employees. Significant transactions with our equity affiliates were: Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Operating revenues and other income $ 30 28 59 55 Purchases 25 25 48 49 Operating expenses and selling, general and administrative expenses 14 12 26 28 Net interest (income) expense* (3) (3) (6) (6) *We paid interest to, or received interest from, various affiliates. See Note 5—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Segment Disclosures and Relat38

Segment Disclosures and Related Information (Tables)	6 Months Ended
	Jun. 30, 2017
Segment Disclosures and Related Information [Abstract]
Analysis of Results by Operating Segment	Analysis of Results by Operating Segment Millions of Dollars Three Months Ended Six Months Ended June 30 June 30 2017 2016 2017 2016 Sales and Other Operating Revenues Alaska $ 1,071 936 2,078 1,714 Lower 48 3,090 2,395 6,320 4,540 Intersegment eliminations (2) (5) (5) (12) Lower 48 3,088 2,390 6,315 4,528 Canada 788 391 1,658 816 Intersegment eliminations (89) (30) (175) (65) Canada 699 361 1,483 751 Europe and North Africa 1,011 736 2,454 1,659 Asia Pacific and Middle East 896 897 1,918 1,734 Corporate and Other 16 28 51 83 Consolidated sales and other operating revenues $ 6,781 5,348 14,299 10,469 Net Income (Loss) Attributable to ConocoPhillips Alaska $ 199 147 188 145 Lower 48 (2,536) (771) (2,898) (1,591) Canada 1,379 (175) 2,327 (469) Europe and North Africa 123 20 294 (31) Asia Pacific and Middle East (2,172) 72 (1,936) 67 Other International (9) (29) (57) (53) Corporate and Other (424) (335) (772) (608) Consolidated net loss attributable to ConocoPhillips $ (3,440) (1,071) (2,854) (2,540) Millions of Dollars June 30 December 31 2017 2016 Total Assets Alaska $ 12,163 12,314 Lower 48 17,637 22,673 Canada 6,122 17,548 Europe and North Africa 11,564 11,727 Asia Pacific and Middle East 17,389 20,451 Other International 116 97 Corporate and Other 13,013 4,962 Consolidated total assets $ 78,004 89,772

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2017
Income Taxes [Abstract]
Schedule Of Effective Income Tax Rate Reconciliation [Table Text Block]	Millions of Dollars Percent of Pre-Tax Income (Loss) Three Months Ended June 30 Six Months Ended June 30 Three Months Ended June 30 Six Months Ended June 30 2017 2016 2017 2016 2017 2016 2017 2016 Income (loss) from continuing operations before income taxes United States $ (4,269) (1,373) (5,063) (2,964) 97.9 % 83.5 110.2 76.6 Foreign (92) (271) 470 (904) 2.1 16.5 (10.2) 23.4 $ (4,361) (1,644) (4,593) (3,868) 100.0 % 100.0 100.0 100.0 Federal statutory income tax $ (1,526) (575) (1,608) (1,354) 35.0 % 35.0 35.0 35.0 Non-U.S. effective tax rates 69 104 335 173 (1.6) (6.3) (7.3) (4.5) Canada disposition (172) - (1,168) - 3.9 - 25.4 - Recovery of outside basis (4) (12) (839) (23) 0.1 0.7 18.3 0.6 Adjustment to tax reserves - - 822 - - - (17.9) - APLNG impairment 834 - 834 - (19.1) - (18.2) - State income tax (99) (78) (88) (110) 2.3 4.7 1.9 2.8 Enhanced oil recovery credit (29) (17) (45) (34) 0.7 1.0 1.0 0.9 Other (8) (8) (9) (6) 0.1 0.5 0.2 0.2 $ (935) (586) (1,766) (1,354) 21.4 % 35.6 38.4 35.0

Supplementary Information - C40

Supplementary Information - Condensed Consolidating Financial Information (Tables)	6 Months Ended
	Jun. 30, 2017
Supplementary Information - Condensed Consolidating Financial Information [Abstract]
Condensed Consolidated Income Statement	Millions of Dollars Three Months Ended June 30, 2017 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 2,954 - 3,827 - 6,781 Equity in earnings (losses) of affiliates (3,235) (2,297) - 153 5,557 178 Gain on dispositions - 16 - 1,860 - 1,876 Other income 1 13 - 33 - 47 Intercompany revenues 12 74 41 792 (919) - Total Revenues and Other Income (3,222) 760 41 6,665 4,638 8,882 Costs and Expenses Purchased commodities - 2,637 - 1,038 (753) 2,922 Production and operating expenses - 139 - 1,189 (1) 1,327 Selling, general and administrative expenses 2 110 - 22 - 134 Exploration expenses - 33 - 65 - 98 Depreciation, depletion and amortization - 204 - 1,421 - 1,625 Impairments - 1,074 - 5,220 - 6,294 Taxes other than income taxes - 36 - 162 - 198 Accretion on discounted liabilities - 10 - 82 - 92 Interest and debt expense 125 171 36 139 (165) 306 Foreign currency transaction (gains) losses (15) 2 19 7 - 13 Other expenses 217 17 - - - 234 Total Costs and Expenses 329 4,433 55 9,345 (919) 13,243 Loss before income taxes (3,551) (3,673) (14) (2,680) 5,557 (4,361) Income tax provision (benefit) (111) (438) 11 (397) - (935) Net loss (3,440) (3,235) (25) (2,283) 5,557 (3,426) Less: net income attributable to noncontrolling interests - - - (14) - (14) Net Loss Attributable to ConocoPhillips $ (3,440) (3,235) (25) (2,297) 5,557 (3,440) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (3,821) (3,616) 30 (2,263) 5,849 (3,821) Income Statement Three Months Ended June 30, 2016 Revenues and Other Income Sales and other operating revenues $ - 2,284 - 3,064 - 5,348 Equity in earnings (losses) of affiliates (1,003) (21) - 145 959 80 Gain on dispositions - 63 - 65 - 128 Other income - 1 - 18 - 19 Intercompany revenues 26 68 60 928 (1,082) - Total Revenues and Other Income (977) 2,395 60 4,220 (123) 5,575 Costs and Expenses Purchased commodities - 1,998 - 682 (678) 2,002 Production and operating expenses - 488 - 1,191 (234) 1,445 Selling, general and administrative expenses 2 136 - 29 - 167 Exploration expenses - 551 - 59 - 610 Depreciation, depletion and amortization - 306 - 2,023 - 2,329 Impairments - 37 - 25 - 62 Taxes other than income taxes - 39 - 158 - 197 Accretion on discounted liabilities - 12 - 100 - 112 Interest and debt expense 126 164 57 135 (170) 312 Foreign currency transaction (gains) losses 2 - (79) 60 - (17) Total Costs and Expenses 130 3,731 (22) 4,462 (1,082) 7,219 Income (Loss) before income taxes (1,107) (1,336) 82 (242) 959 (1,644) Income tax provision (benefit) (36) (333) 19 (236) - (586) Net income (loss) (1,071) (1,003) 63 (6) 959 (1,058) Less: net income attributable to noncontrolling interests - - - (13) - (13) Net Income (Loss) Attributable to ConocoPhillips $ (1,071) (1,003) 63 (19) 959 (1,071) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (1,296) (1,228) 51 (215) 1,392 (1,296) Millions of Dollars Six Months Ended June 30, 2017 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 6,069 - 8,230 - 14,299 Equity in earnings (losses) of affiliates (2,578) (1,124) - 313 3,767 378 Gain on dispositions - 29 - 1,869 - 1,898 Other income 1 15 - 62 - 78 Intercompany revenues 29 145 83 1,586 (1,843) - Total Revenues and Other Income (2,548) 5,134 83 12,060 1,924 16,653 Costs and Expenses Purchased commodities - 5,402 - 2,228 (1,516) 6,114 Production and operating expenses - 280 - 2,347 (2) 2,625 Selling, general and administrative expenses 6 246 - 44 (5) 291 Exploration expenses - 405 - 244 - 649 Depreciation, depletion and amortization - 455 - 3,149 - 3,604 Impairments - 1,074 - 5,395 - 6,469 Taxes other than income taxes - 85 - 344 - 429 Accretion on discounted liabilities - 20 - 167 - 187 Interest and debt expense 254 336 73 278 (320) 621 Foreign currency transaction (gains) losses (22) 2 68 (25) - 23 Other expense 217 17 - - - 234 Total Costs and Expenses 455 8,322 141 14,171 (1,843) 21,246 Loss before income taxes (3,003) (3,188) (58) (2,111) 3,767 (4,593) Income tax provision (benefit) (149) (610) 6 (1,013) - (1,766) Net loss (2,854) (2,578) (64) (1,098) 3,767 (2,827) Less: net income attributable to noncontrolling interests - - - (27) - (27) Net Loss Attributable to ConocoPhillips $ (2,854) (2,578) (64) (1,125) 3,767 (2,854) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (3,003) (2,727) 17 (901) 3,611 (3,003) Income Statement Six Months Ended June 30, 2016 Revenues and Other Income Sales and other operating revenues $ - 4,356 - 6,113 - 10,469 Equity in earnings of affiliates (2,430) (771) - (299) 3,431 (69) Gain on dispositions - 85 - 66 - 151 Other income (loss) - (5) - 44 - 39 Intercompany revenues 44 149 116 1,453 (1,762) - Total Revenues and Other Income (2,386) 3,814 116 7,377 1,669 10,590 Costs and Expenses Purchased commodities - 3,846 - 1,561 (1,180) 4,227 Production and operating expenses - 741 - 2,295 (237) 2,799 Selling, general and administrative expenses 5 290 - 64 (6) 353 Exploration expenses - 982 - 133 - 1,115 Depreciation, depletion and amortization - 563 - 4,013 - 4,576 Impairments - 41 - 157 - 198 Taxes other than income taxes - 96 - 281 - 377 Accretion on discounted liabilities - 24 - 197 - 221 Interest and debt expense 250 298 112 272 (339) 593 Foreign currency transaction (gains) losses (42) 2 233 (194) - (1) Total Costs and Expenses 213 6,883 345 8,779 (1,762) 14,458 Loss before income taxes (2,599) (3,069) (229) (1,402) 3,431 (3,868) Income tax provision (benefit) (59) (639) 1 (657) - (1,354) Net loss (2,540) (2,430) (230) (745) 3,431 (2,514) Less: net income attributable to noncontrolling interests - - - (26) - (26) Net Loss Attributable to ConocoPhillips $ (2,540) (2,430) (230) (771) 3,431 (2,540) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (1,664) (1,554) 4 230 1,320 (1,664)
Schedule of Condensed Balance Sheet	Millions of Dollars June 30, 2017 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Assets Cash and cash equivalents $ - 1,162 34 6,338 - 7,534 Short-term investments - - - 2,733 - 2,733 Accounts and notes receivable 82 1,656 35 3,608 (2,218) 3,163 Investment in Cenovus Energy - 1,533 - - - 1,533 Inventories - 112 - 907 - 1,019 Prepaid expenses and other current assets 1 436 7 3,480 (27) 3,897 Total Current Assets 83 4,899 76 17,066 (2,245) 19,879 Investments, loans and long-term receivables* 34,470 56,453 2,377 18,838 (101,935) 10,203 Net properties, plants and equipment - 4,330 - 42,516 - 46,846 Other assets 43 2,906 203 1,235 (3,311) 1,076 Total Assets $ 34,596 68,588 2,656 79,655 (107,491) 78,004 Liabilities and Stockholders’ Equity Accounts payable $ - 2,357 2 3,293 (2,218) 3,434 Short-term debt 1,688 2,000 6 104 - 3,798 Accrued income and other taxes - 76 - 715 - 791 Employee benefit obligations - 382 - 127 - 509 Other accruals 102 680 45 594 (27) 1,394 Total Current Liabilities 1,790 5,495 53 4,833 (2,245) 9,926 Long-term debt 3,784 11,338 1,706 2,842 - 19,670 Asset retirement obligations and accrued environmental costs - 560 - 7,071 - 7,631 Deferred income taxes - - - 9,111 (2,776) 6,335 Employee benefit obligations - 1,874 - 625 - 2,499 Other liabilities and deferred credits* 5,298 8,972 824 15,285 (28,935) 1,444 Total Liabilities 10,872 28,239 2,583 39,767 (33,956) 47,505 Retained earnings 21,510 11,437 (605) 10,852 (15,161) 28,033 Other common stockholders’ equity 2,214 28,912 678 28,823 (58,374) 2,253 Noncontrolling interests - - - 213 - 213 Total Liabilities and Stockholders’ Equity $ 34,596 68,588 2,656 79,655 (107,491) 78,004 *Includes intercompany loans. Balance Sheet December 31, 2016 Assets Cash and cash equivalents $ - 358 13 3,239 - 3,610 Short-term investments - - - 50 - 50 Accounts and notes receivable 22 1,968 23 6,103 (4,702) 3,414 Inventories - 84 - 934 - 1,018 Prepaid expenses and other current assets 2 116 8 415 (24) 517 Total Current Assets 24 2,526 44 10,741 (4,726) 8,609 Investments, loans and long-term receivables* 37,901 64,434 2,296 31,643 (114,602) 21,672 Net properties, plants and equipment - 6,301 - 52,030 - 58,331 Other assets 40 2,194 220 1,240 (2,534) 1,160 Total Assets $ 37,965 75,455 2,560 95,654 (121,862) 89,772 Liabilities and Stockholders’ Equity Accounts payable $ - 4,683 1 3,671 (4,702) 3,653 Short-term debt (10) 999 6 94 - 1,089 Accrued income and other taxes - 85 - 399 - 484 Employee benefit obligations - 489 - 200 - 689 Other accruals 171 271 40 536 (24) 994 Total Current Liabilities 161 6,527 47 4,900 (4,726) 6,909 Long-term debt 8,975 12,635 1,710 2,866 - 26,186 Asset retirement obligations and accrued environmental costs - 925 - 7,500 - 8,425 Deferred income taxes - - - 10,972 (2,023) 8,949 Employee benefit obligations - 1,901 - 651 - 2,552 Other liabilities and deferred credits* 417 10,391 748 17,832 (27,863) 1,525 Total Liabilities 9,553 32,379 2,505 44,721 (34,612) 54,546 Retained earnings 25,025 14,015 (541) 12,883 (19,834) 31,548 Other common stockholders’ equity 3,387 29,061 596 37,798 (67,416) 3,426 Noncontrolling interests - - - 252 - 252 Total Liabilities and Stockholders’ Equity $ 37,965 75,455 2,560 95,654 (121,862) 89,772 *Includes intercompany loans.
Condensed Consolidated Statement of Cash Flows	Millions of Dollars Six Months Ended June 30, 2017 Statement of Cash Flows ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (137) (1,475) 21 5,926 (794) 3,541 Cash Flows From Investing Activities Capital expenditures and investments - (1,125) - (1,729) 868 (1,986) Working capital changes associated with investing activities - 39 - (152) - (113) Proceeds from asset dispositions - 9,909 - 10,716 (9,883) 10,742 Purchases of short-term investments - - - (2,653) - (2,653) Long-term advances/loans—related parties - (63) - (20) 83 - Collection of advances/loans—related parties 658 63 - 2,138 (2,802) 57 Intercompany cash management 4,882 (4,214) - (668) - - Other - 43 - 133 - 176 Net Cash Provided by Investing Activities 5,540 4,652 - 7,765 (11,734) 6,223 Cash Flows From Financing Activities Issuance of debt - 20 - 63 (83) - Repayment of debt (3,717) (2,394) - (770) 2,802 (4,079) Issuance of company common stock 49 - - - (112) (63) Repurchase of company common stock (1,075) - - - - (1,075) Dividends paid (662) - - (906) 906 (662) Other 2 - - (9,081) 9,015 (64) Net Cash Used in Financing Activities (5,403) (2,374) - (10,694) 12,528 (5,943) Effect of Exchange Rate Changes on Cash and Cash Equivalents - 1 - 102 - 103 Net Change in Cash and Cash Equivalents - 804 21 3,099 - 3,924 Cash and cash equivalents at beginning of period - 358 13 3,239 - 3,610 Cash and Cash Equivalents at End of Period $ - 1,162 34 6,338 - 7,534 Statement of Cash Flows Six Months Ended June 30, 2016 Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (153) 572 (5) 2,229 (963) 1,680 Cash Flows From Investing Activities Capital expenditures and investments - (823) - (2,532) 401 (2,954) Working capital changes associated with investing activities - (76) - (287) - (363) Proceeds from asset dispositions 2,300 160 - 227 (2,324) 363 Purchases of short-term investments - - - (1,292) - (1,292) Long-term advances/loans—related parties - (803) - - 803 - Collection of advances/loans—related parties - - - 1,626 (1,573) 53 Intercompany cash management (3,190) 2,127 - 1,063 - - Other - 2 - 4 - 6 Net Cash Provided by (Used in) Investing Activities (890) 587 - (1,191) (2,693) (4,187) Cash Flows From Financing Activities Issuance of debt 1,600 2,994 - 803 (803) 4,594 Repayment of debt - (1,573) - (827) 1,573 (827) Issuance of company common stock 70 - - - (115) (45) Dividends paid (626) - - (1,078) 1,078 (626) Other (1) (2,319) - 318 1,923 (79) Net Cash Provided by (Used in) Financing Activities 1,043 (898) - (784) 3,656 3,017 Effect of Exchange Rate Changes on Cash and Cash Equivalents - - - (15) - (15) Net Change in Cash and Cash Equivalents - 261 (5) 239 - 495 Cash and cash equivalents at beginning of period - 4 15 2,349 - 2,368 Cash and Cash Equivalents at End of Period $ - 265 10 2,588 - 2,863

Variable Interest Entities (V41

Variable Interest Entities (VIEs) (Details) - Marine Well Containment Company, LLC [Member] - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Variable Interest Entity [Line Items]
Variable Interest Entity, Ownership Percentage	10.00%
Book value of investment	$ 143
Letter of Credit [Member]
Variable Interest Entity [Line Items]
Term Loan		$ 154
Letter of Credit [Member] | ConocoPhillips [Member]
Variable Interest Entity [Line Items]
Line of Credit		$ 22

Inventories (Details)

Inventories (Details) - USD ($) $ in Thousands	Jun. 30, 2017	Dec. 31, 2016
Inventories
Crude oil and petroleum products	$ 447,000	$ 418,000
Materials and supplies	572,000	600,000
Total Inventories	1,019,000	1,018,000
Inventories (Textual) [Abstract]
Inventories valued on the LIFO basis	296,000	269,000
Excess of current replacement cost over LIFO cost of inventories	$ 45,000	$ 104,000

Assets Held for Sale or Sold (D

Assets Held for Sale or Sold (Details) $ / shares in Units, shares in Millions, CAD in Millions, $ in Millions

1 Months Ended

3 Months Ended

5 Months Ended

6 Months Ended

7 Months Ended

Jul. 28, 2017USD ($)

Apr. 30, 2017USD ($)

Jun. 30, 2017USD ($)

Apr. 12, 2017USD ($)$ / MMBTU

Mar. 29, 2017CADCAD / bbl

Jun. 30, 2016USD ($)

May 17, 2017USD ($)$ / sharesshares

Jun. 30, 2017USD ($)

Jun. 28, 2017USD ($)

Jun. 30, 2016USD ($)

Jul. 31, 2017USD ($)

Jul. 25, 2017USD ($)

Long Lived Assets Held For Sale [Line Items]

Payments for (Proceeds from) Other Investing Activities

$ (135)

$ (176)

$ (6)

Income (Loss) from Equity Method Investments

$ 178

$ 80

378

(69)

Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]

Long Lived Assets Held For Sale [Line Items]

Gain (Loss) On Disposition Of Assets

1,850

Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]

Long Lived Assets Held For Sale [Line Items]

Proceeds from asset dispositions

$ 600

317

$ 10,400

Shares Exchange for Assets Held for Sale | shares

208

Investment Owned, Common Stock, price per share | $ / shares

$ 9.41

Available For Sale Equity Securities Amortized Cost Basis

$ 1,960

Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member] | Contingent Payment, Maximum [Member]

Long Lived Assets Held For Sale [Line Items]

Assets Held for Sale, Contigent Consinderation, Contingent Payment Based on Crude Oil Price per Barrel Trigger | CAD

CAD 6

Assets Held for Sale, Contingent Consideration Term

5 years

Assets Held for Sale, Contigent Consideration, Crude Oil Price per Barrel Trigger | CAD / bbl

52

Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member] | Scenario, Plan [Member]

Long Lived Assets Held For Sale [Line Items]

Gain (Loss) On Disposition Of Assets

$ 283

Foster Creek Christina Lake (FCCL) [Member]

Long Lived Assets Held For Sale [Line Items]

Investment Owned Percent Of Net Assets

50.00%

Foster Creek Christina Lake (FCCL) [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]

Long Lived Assets Held For Sale [Line Items]

Equity Method Investments

8,900

Profit before taxes

197

(98)

Western Canada Gas Properties [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]

Long Lived Assets Held For Sale [Line Items]

Net carrying value

1,900

Assets Held for Sale, Property, Plant and Equipment Reclassification to Prepaid Expenses and Other Current Assets

2,600

Assets Held for Sale Long term liabilties reclassed to Other Accruals

585

Enviornmental and Other Accruals for Assets Held for Sale moved to Other Accruals until sold

$ 100

Profit before taxes

(30)

(324)

San Juan Basin [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]

Long Lived Assets Held For Sale [Line Items]

Net carrying value

2,500

2,500

Profit before taxes

(3,300)

(200)

San Juan Basin [Member] | Disposal Group Held for sale Not Discontinued Operations [Member] | Scenario, Plan [Member] | Contingent Payment, Maximum [Member]

Long Lived Assets Held For Sale [Line Items]

Assets Held for Sale, Contingent Consideration Term

6 years

Assets Held for Sale, Contingent Consideration, Effective Date

Jan. 1, 2018

Assets Held for Sale, Contingent Consideration, Henry Hub Price per Unit | $ / MMBTU

3.2

San Juan Basin [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]

Long Lived Assets Held For Sale [Line Items]

Proceeds from asset dispositions

$ 2,500

Payments for (Proceeds from) Other Investing Activities

$ 135

Impairment Of Long Lived Assets To Be Disposed Of

3,300

San Juan Basin [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member] | Scenario, Plan [Member]

Long Lived Assets Held For Sale [Line Items]

Total Consideration Estimate

3,000

Proceeds from asset dispositions

2,700

Assets Held for Sale, Property, Plant and Equipment Reclassification to Prepaid Expenses and Other Current Assets

2,900

Assets Held for Sale Long term liabilties reclassed to Other Accruals

400

San Juan Basin [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member] | Scenario, Plan [Member] | Contingent Payment, Maximum [Member]

Long Lived Assets Held For Sale [Line Items]

Proceeds from asset dispositions

$ 300

Barnett [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]

Long Lived Assets Held For Sale [Line Items]

Profit before taxes

(585)

$ (40)

Barnett [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]

Long Lived Assets Held For Sale [Line Items]

Net carrying value

302

302

Assets Held for Sale, Property, Plant and Equipment Reclassification to Prepaid Expenses and Other Current Assets

345

Assets Held for Sale Long term liabilties reclassed to Other Accruals

49

Impairment Of Long Lived Assets To Be Disposed Of

566

Barnett [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member] | Scenario, Plan [Member]

Long Lived Assets Held For Sale [Line Items]

Total Consideration Estimate

$ 305

Panhandle [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member] | Scenario, Plan [Member]

Long Lived Assets Held For Sale [Line Items]

Net carrying value

207

207

Total Consideration Estimate

$ 184

Disposition of Assets Property Plant Equipment

280

280

Disposition of Asset Asset Retirement Obligation

$ 72

$ 72

Investments, Loans and Long-T44

Investments, Loans and Long-Term Receivables (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Mar. 29, 2017	Dec. 31, 2016	Oct. 31, 2016
Equity method investments
Cumulative foreign currency translation adjustment	$ (5,435)		$ (5,435)			$ (5,646)
Income (Loss) from Equity Method Investments	178	$ 80	378	$ (69)
Australia Pacific LNG [Member]
Equity method investments
Book value of investment	7,656		7,656
Project finance facility	8,500		$ 8,500
Line of Credit Facility, Frequency of Payments			bi-annual
Line of Credit Facility, Expiration Date			Mar. 31, 2029
Amount drawn from project finance facility	8,200		$ 8,200
Fair value of investment	7,656		7,656
Percent decrease in guarantee							60.00%
Non Cash Impairment of Equity Investment Other than Temporary	2,384
Australia Pacific LNG [Member] | Export-Import Bank of the US [Member]
Equity method investments
Project finance facility	2,900		2,900
Australia Pacific LNG [Member] | Export-Import Bank of China [Member]
Equity method investments
Project finance facility	2,700		2,700
Australia Pacific LNG [Member] | Australian and International Commercial Bank Syndicate [Member]
Equity method investments
Project finance facility	2,900		2,900
Deferred Tax Effect [Member] | Australian and International Commercial Bank Syndicate [Member]
Equity method investments
Income (Loss) from Equity Method Investments			0
Qatar Liquefied Gas Company Limited (3) (QG3) [Member]
Equity method investments
Loan balance with affiliated company	639		639
Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member]
Equity method investments
Book value of investment	0		0
Cumulative foreign currency translation adjustment	$ 0		$ 0
Distribution from equity affiliate				$ 0
Foster Creek Christina Lake (FCCL) [Member]
Equity method investments
Percent interest					50.00%

Investment in Cenovus Energy (D

Investment in Cenovus Energy (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	5 Months Ended	6 Months Ended
	May 17, 2017	Jun. 30, 2017	Mar. 29, 2017
Foster Creek Christina Lake (FCCL) [Member]
Schedule Of Available For Sale Securities [Line Items]
Investment Owned Percent Of Net Assets			50.00%
Cenovus Energy [Member]
Schedule Of Available For Sale Securities [Line Items]
Available For Sale Securities Current	$ 1,960	$ 1,530
Available For Sale Equity Securities Amortized Cost Basis	$ 1,960
Common Stock [Member] | Cenovus Energy [Member]
Schedule Of Available For Sale Securities [Line Items]
Shares Exchange for Assets Held for Sale	208
Investment Owned, Common Stock, price per share	$ 9.41	$ 7.37
Investment Owned, Common Stock, percent of Issued and Outstanding	16.90%
Available-for-sale Securities, Gross Unrealized Gain (Loss)		$ (424)

Suspended Wells and Wells in 46

Suspended Wells and Wells in Progress (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended			6 Months Ended
	Feb. 28, 2017	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Dec. 31, 2016
Suspended Wells (Textual) [Abstract]
Capitalized cost of suspended wells		$ 860			$ 860		$ 1,063
Increase (decrease) in capitalized cost of suspended wells					(203)
Exploration Expense		$ 98		$ 610	649	$ 1,115
Gulf of Mexico, Shenandoah [Member]
Suspended Wells (Textual) [Abstract]
Dollar value of wells charged to dry hole expense					$ 94
Number of wells charged to dry hole expense					2
Exploration Expense			$ 51
Alaska [Member]
Suspended Wells (Textual) [Abstract]
Dollar value of wells charged to dry hole expense					$ 17
Number of wells charged to dry hole expense					1
Angola [Member]
Suspended Wells (Textual) [Abstract]
Exploration Expense	$ 43
Malaysia [Member]
Suspended Wells (Textual) [Abstract]
Dollar value of wells charged to dry hole expense					$ 23
Number of wells charged to dry hole expense					1

Impairments (Details)

Impairments (Details) - USD ($) $ in Millions	3 Months Ended				6 Months Ended
	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2016	Mar. 31, 2016	Jun. 30, 2017	Jun. 30, 2016
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 6,294		$ 62		$ 6,469	$ 198
Exploration Expense	98		610		649	1,115
Alaska State [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	3	$ 174	0		177	0
Lower Forty Eight [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	3,885		51		3,885	60
Exploration Expense				$ 73
Gibson and Tiber [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			203
Melmar [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense				$ 95
Canada [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	18		0		18	0
Europe and North Africa [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	4		10		5	137
Asia Pacific and Middle East [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 2,384		$ 1		$ 2,384	$ 1
Gulf of Mexico, Shenandoah [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense		$ 51

Debt (Details Textual)

Debt (Details Textual) $ in Thousands	3 Months Ended		6 Months Ended			7 Months Ended
	Jun. 30, 2017USD ($)	Mar. 31, 2017USD ($)	Jul. 05, 2017USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2016USD ($)	Aug. 01, 2017USD ($)
Debt Instrument [Line Items]
Repayments of Debt	$ 3,000,000			$ 4,079,000	$ 827,000
Debt Instrument Make-Whole Provision	234,000
ShortTermBorrowings [Abstract]
Maturity period of commercial paper (in days)				P90D
Letters of credit issued	$ 265,000			$ 265,000
Debt (Textual) [Abstract]
Classification of short-term debt as long-term debt				$ 0
Debt to capital ratio	0.65			0.65
Debt, reclassification from long term debt to short term debt per payment dates	$ 2,700,000			$ 2,700,000
Scenario, Plan [Member]
Debt Instrument [Line Items]
Repayments of Debt						$ 1,800,000
Debt Instrument Make-Whole Provision						$ 50,000
Floating Rate Notes due 2019 [Member]
Debt Instrument [Line Items]
Repayments of Debt		$ 805,000	$ 645,000
Remaining Amount of Debt	645,000			$ 645,000
Debt Instrument, Maturity Date				Mar. 18, 2019
Marine Terminal Revenue Refunding Bonds due through 2035
Debt Instrument [Line Items]
Debt at face value	$ 283,000			$ 283,000
Debt Instrument, Maturity Date				Dec. 31, 2035
6.65% Debenture due 2018 [Member]
Debt Instrument [Line Items]
Stated percentage of debt	6.65%			6.65%
Repayments of Debt	$ 297,000
5.75% Note due 2019 [Member]
Debt Instrument [Line Items]
Stated percentage of debt	5.75%			5.75%
Repayments of Debt	$ 1,700,000
5.75% Note due 2019 [Member] | Scenario, Plan [Member]
Debt Instrument [Line Items]
Stated percentage of debt						5.75%
Repayments of Debt						$ 550,000
6.00% Note due 2020 [Member]
Debt Instrument [Line Items]
Stated percentage of debt	6.00%			6.00%
Repayments of Debt	$ 1,000,000
5.20% Note due 2018 [Member] | Scenario, Plan [Member]
Debt Instrument [Line Items]
Stated percentage of debt						5.20%
Repayments of Debt						$ 500,000
1.50% Note Due 2018 [Member] | Scenario, Plan [Member]
Debt Instrument [Line Items]
Stated percentage of debt						1.50%
Repayments of Debt						$ 750,000
Revolving Credit Facilities [Member]
ShortTermBorrowings [Abstract]
Total amount under revolving credit facilities	6,750,000			$ 6,750,000
Letters of credit issued	0			0
Credit facilities remaining after commercial paper outstanding and issuance of letters of credit	6,750,000			6,750,000
ConocoPhillips [Member]
Debt Instrument [Line Items]
Repayments of Debt				3,717,000	$ 0
ShortTermBorrowings [Abstract]
Commercial paper program	6,250,000			6,250,000
ConocoPhillips Qatar Funding Ltd. [Member]
ShortTermBorrowings [Abstract]
Commercial paper program	500,000			500,000
Commercial paper outstanding	$ 0			$ 0

Noncontrolling Interests (Detai

Noncontrolling Interests (Details) - USD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Activity for equity attributable to noncontrolling interests
Beginning Balance				$ 35,226	$ 40,082
Net income (loss)		$ (3,426)	$ (1,058)	(2,827)	(2,514)
Dividends paid				(662)	(626)
Repurchase of company common stock				(1,075)	0
Distributions to noncontrolling interests				(67)	(59)
Other	[1]			(96)	948
Ending Balance		30,499	37,831	30,499	37,831
Common Stockholders' Equity [Member]
Activity for equity attributable to noncontrolling interests
Beginning Balance				34,974	39,762
Net income (loss)				(2,854)	(2,540)
Dividends paid				(662)	(626)
Repurchase of company common stock				(1,075)	0
Distributions to noncontrolling interests				0	0
Other	[1]			(97)	948
Ending Balance		30,286	37,544	30,286	37,544
Noncontrolling Interest [Member]
Activity for equity attributable to noncontrolling interests
Beginning Balance				252	320
Net income (loss)				27	26
Dividends paid				0	0
Repurchase of company common stock				0	0
Distributions to noncontrolling interests				(67)	(59)
Other	[1]			1	0
Ending Balance		$ 213	$ 287	$ 213	$ 287
[1]	*Includes components of other comprehensive income (loss), which are disclosed separately in the Consolidated Statement of Comprehensive

Guarantees (Details)

Guarantees (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Guarantees (Textual) [Abstract]
Environmental accruals for known contamination in carrying amount recorded for indemnifications	$ 188	$ 247
Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Ownership percentage in equity investment	37.50%
Construction completion guarantee [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments based on current pro-rata share	$ 1,250
Carrying value of the guarantee to third-party lenders	46
Continued development [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 160
Terms of guarantees outstanding	up to 28 years or the life of the venture
Other Guarantees [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 540
Terms of guarantees outstanding	up to six years
Indemnifications [Member]
Guarantees (Textual) [Abstract]
Carrying value of the guarantee to third-party lenders	$ 100
Environmental accruals for known contamination in carrying amount recorded for indemnifications	40
Indemnifications [Member] | Refinery Supplier [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 1,310
Terms of guarantees outstanding	seven years
Carrying value of the guarantee to third-party lenders	$ 98
Carrying value of indemnification asset	98
Guarantee existing sales agreement of natural gas delivery | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	1,000
Maximum potential amount of future payments under the guarantees in the event of intentional or reckless breach	$ 1,740
Terms of guarantees outstanding	up to 25 years
Finance Reserve Guarantee [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 100
Terms of guarantees outstanding	12 years
Carrying value of the guarantee to third-party lenders	$ 9

Contingencies and Commitments (

Contingencies and Commitments (Details) - USD ($) $ in Millions	1 Months Ended	6 Months Ended
	Feb. 28, 2017	Jun. 30, 2017	Dec. 31, 2016
Contingencies and Commitments (Textual) [Abstract]
Total environmental accrual included in balance sheet		$ 188	$ 247
Expected years to incur the majority of expenditures		30 years
Letters of credit that secure performance obligations		$ 265
Burlington Resources, Inc [Member] | ECUADOR | Oil and Gas Properties [Member] | Confiscated Crude Oil Production [Member]
Loss Contingencies [Line Items]
Loss Contingency, Name of Plaintiff		Burlington Resources, Inc
Loss Contingency, Name of Defendant		The Republic of Ecuador
Litigation Settlement Amount	$ 380
Litigation Settlement Amount, Seperate Seetlement to Defendent, Environemental and Infrastructure Impacts	$ 42

Derivative and Financial Inst52

Derivative and Financial Instruments - Commodity Balance Sheet (Details) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	$ 196	$ 268
Other assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	42	44
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	182	300
Other liabilities and deferred credits [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	$ 29	$ 34

Derivative and Financial Inst53

Derivative and Financial Instruments - Commodity GainLoss (Details 1) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Sales and other operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ 52	$ (163)	$ 103	$ (166)
Other Income [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	(1)	(3)	0	(2)
Purchased commodities [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ (31)	$ 130	$ (69)	$ 129

Derivative and Financial Inst54

Derivative and Financial Instruments - Commodity Notional (Details 2) - ft3 / D ft3 / D in Billions	Jun. 30, 2017	Dec. 31, 2016
Natural gas and power, Fixed price [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	(41)	(31)
Natural gas and power, Basis [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	40	2

Derivative and Financial Inst55

Derivative and Financial Instruments - FX Balance Sheet (Details 3) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Prepaid Expenses and Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	$ 1	$ 1
Other Accruals [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative liabilities	$ 0	$ 168

Derivative and Financial Inst56

Derivative and Financial Instruments - FX GainLoss (Details 4) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Foreign currency transaction gains (losses) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Foreign currency transaction (gains) losses	$ (4)	$ 86	$ 3	$ 183

Derivative and Financial Inst57

Derivative and Financial Instruments - FX Notional (Details 5) £ in Millions, $ in Millions		Jun. 30, 2017GBP (£)	Jun. 30, 2017USD ($)	Dec. 31, 2016GBP (£)	Dec. 31, 2016USD ($)
Sell US Dollar Buy Other Currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives | $	[1]		$ 28		$ 13
Buy U.S. dollar, sell other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives | $	[2]		$ 0		$ 25
Buy British pound, sell other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives | £	[3]	£ 6		£ 1,069
Sell British pound, buy Norwegian krone [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives | £		£ 0		£ 51
[1]	*Primarily Canadian dollar.
[2]	**Primarily British pound.
[3]	***Primarily Euro and Canadian dollar.

Derivative and Financial Inst58

Derivative and Financial Instruments - Financial Instruments (Details 6) - USD ($)	Jun. 30, 2017	Dec. 31, 2016	Jun. 30, 2016	Dec. 31, 2015
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents Total	$ 7,534,000,000	$ 3,610,000,000	$ 2,863,000,000	$ 2,368,000,000
Short-term Investment [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash	0	0
Cash and cash equivalents Total	2,733,000,000	50,000,000
Remaining maturities from 1 to 90 days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Time Deposits	1,510,000,000	39,000,000
Commercial Paper	524,000,000	0
Remaining maturities from 91 to 180 days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Time Deposits	78,000,000	11,000,000
Commercial Paper	621,000,000	0
Cash and Cash Equivalents [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash	779,000,000	623,000,000
Cash and cash equivalents Total	7,534,000,000	3,610,000,000
Remaining maturities from 1 to 90 days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Time Deposits	5,316,000,000	2,987,000,000
Commercial Paper	999,000,000	0
US Government Securities At Carrying Value	440,000,000	0
Remaining maturities from 91 to 180 days [Member] [Member]
Schedule of Held-to-maturity Securities [Line Items]
Time Deposits	0	0
Commercial Paper	$ 0	$ 0

Derivative and Financial Inst59

Derivative and Financial Instruments (Details Textual) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2017	Dec. 31, 2016
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Aggregate fair value of all derivative instruments in a liability position	$ 37	$ 42
Collateral was posted for derivative instruments in a liability position	0	$ 0
In event of downgrade below investment grade [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Additional collateral, either in the form of cash or letters of credit	$ 37
Financial instruments [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Terms of financial instruments and trade receivables	90 days
Trade receivables [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Terms of financial instruments and trade receivables	30 days

Fair Value Measurement - FV Hie

Fair Value Measurement - FV Hierarchy (Details) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available For Sale Securities Current	$ 1,533	$ 0
Commodity derivative asset, gross	238	312
Total assets	1,771	312
Commodity derivative liability, gross	211	334
Total liabilities	211	334
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available For Sale Securities Current	0	0
Commodity derivative asset, gross	130	194
Total assets	130	194
Commodity derivative liability, gross	131	207
Total liabilities	131	207
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available For Sale Securities Current	1,533	0
Commodity derivative asset, gross	82	96
Total assets	1,615	96
Commodity derivative liability, gross	69	105
Total liabilities	69	105
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Available For Sale Securities Current	0	0
Commodity derivative asset, gross	26	22
Total assets	26	22
Commodity derivative liability, gross	11	22
Total liabilities	$ 11	$ 22

Fair Value Measurement - FV of

Fair Value Measurement - FV of Commodity Derivatives (Details 1) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Offsetting Derivative Assets[Abstract]
Assets - gross amounts recognized	$ 238	$ 312
Assets - gross amounts offset	143	221
Assets - net amounts presented	95	91
Assets - cash collateral	0	0
Assets - amounts without right of setoff	5	5
Assets - net amounts	90	86
Offsetting Derivative Liabilities [Abstract]
Liabilities - gross amounts recognized	211	334
Liabilities - gross amounts offset	143	221
Liabilities - net amounts presented	68	113
Liabilities - cash collateral	3	12
Liabilities - amounts without right of setoff	5	12
Liabilities - net amounts	$ 60	$ 89

Fair Value Measurement - Nonrec

Fair Value Measurement - Nonrecurring (Details) - Fair Value Measurements Nonrecurring [Member] $ in Millions	6 Months Ended
	Jun. 30, 2017USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for sale)	$ 2,830
Cost and equity method investments	7,656
Before Tax Loss Net PPE Held for Sale	3,882
Before-Tax Loss - Cost and equity method investment	2,384
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for sale)	2,830
Cost and equity method investments	0
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for sale)	0
Cost and equity method investments	$ 7,656

Fair Value Measurement - FV o63

Fair Value Measurement - FV of Fin. Instruments (Details 2) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Financial Assets [Abstract]
Investment in Cenovus Energy	$ 1,533	$ 0
Commodity derivatives, assets	95	91
Financial Liabilities [Abstract]
Commodity derivatives, liabilities	68	113
Carrying Amount [Member]
Financial Assets [Abstract]
Investment in Cenovus Energy	1,533	0
Commodity derivatives, assets	95	91
Total loans and advances - related parties	644	701
Financial Liabilities [Abstract]
Total debt, excluding capital leases, carrying amount	22,624	26,423
Total debt, excluding capital leases, fair value	22,624	26,423
Commodity derivatives, liabilities	65	101
Fair Value [Member]
Financial Assets [Abstract]
Investment in Cenovus Energy	1,533	0
Commodity derivatives, assets	95	91
Total loans and advances - related parties	644	701
Financial Liabilities [Abstract]
Total debt, excluding capital leases, fair value	25,501	29,307
Commodity derivatives, liabilities	$ 65	$ 101

Accumulated Other Comprehensi64

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Accumulated other comprehensive income in the equity section of the balance sheet included
Defined Benefit Plans, Beginning Balance			$ (547)
Defined Benefit Plans	$ 16	$ (1)	64	$ (83)
Defined Benefit Plans, Ending Balance	(483)		(483)
Avaialbe for Sale Securities, Begninng Balance			0
Net Unrealized Gain (Loss) on Securities	(424)	0	(424)	0
Avaialbe for Sale Securities, Ending Balance	(424)		(424)
Foreign Currency Translation, Beginning Balance			(5,646)
Foreign Currency Translation	27	(224)	211	959
Foreign Currency Translation, Ending Balance	(5,435)		(5,435)
Accumulated Other Comprehensive Income, Beginning Balance			(6,193)
Other Comprehensive Income (Loss), Net of Tax	(381)	$ (225)	(149)	$ 876
Accumulated Other Comprehensive Income, Ending Balance	$ (6,342)		$ (6,342)

Accumulated Other Comprehensi65

Accumulated Other Comprehensive Income (Loss) (Details 1) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Reclassification out of Accumulated Other Comprehensive Income [Abstract]
Defined Benefit Plans	$ 36	$ 42	$ 90	$ 105
Tax expense of defined benefit plans	$ 20	$ 23	$ 47	$ 59

Cash Flow Information (Details)

Cash Flow Information (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	6 Months Ended
	Apr. 30, 2017	Mar. 31, 2017	Jun. 30, 2017	Jun. 30, 2016
Cash payments (receipts)
Interest			$ 676	$ 526
Income taxes			337	(366)
Net Purchases of Short-Term Investments
Short-term investments purchased			(2,952)	(1,599)
Short-term investments sold			299	307
Net sale (purchases) of short-term investments			(2,653)	(1,292)
Derivative Instruments, Gain (Loss) [Line Items]
Payments for Foreign Currency Derivative Instruments Not Designated as Hedging Instruments		$ 180
Long Lived Assets Held For Sale [Line Items]
Payments for (Proceeds from) Other Investing Activities	$ (135)		$ (176)	$ (6)

Employee Benefit Plans (Details

Employee Benefit Plans (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
U.S. (Pension Benefits) [Member]
Components of Net Periodic Benefit Cost
Service cost	$ 23	$ 28	$ 46	$ 55
Interest cost	29	32	61	72
Expected return on plan assets	(31)	(35)	(65)	(78)
Amortization of prior service cost (credit)	1	1	2	2
Recognized net actuarial (gain) loss	17	23	36	42
Settlements	37	45	97	127
Net periodic benefit cost	76	94	177	220
Int'l (Pension Benefits) [Member]
Components of Net Periodic Benefit Cost
Service cost	20	20	39	40
Interest cost	25	32	51	63
Expected return on plan assets	(39)	(41)	(78)	(82)
Amortization of prior service cost (credit)	(2)	(2)	(3)	(3)
Recognized net actuarial (gain) loss	12	7	24	14
Net periodic benefit cost	16	16	33	32
Other Benefits [Member]
Components of Net Periodic Benefit Cost
Service cost	1	0	1	1
Interest cost	2	4	4	7
Amortization of prior service cost (credit)	(9)	(8)	(18)	(17)
Recognized net actuarial (gain) loss		(1)	(1)	(1)
Net periodic benefit cost	$ (6)	$ (5)	$ (14)	$ (10)

Employee Benefit Plans (Detai68

Employee Benefit Plans (Details Textual) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
U.S. (Pension Benefits) [Member]
Employee Benefit Plans (Textual) [Abstract]
Company contributions			$ 119
Expected company contributions			460
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements	$ (37)	$ (45)	(97)	$ (127)
Int'l (Pension Benefits) [Member]
Employee Benefit Plans (Textual) [Abstract]
Company contributions			62
Expected company contributions			$ 120

Employee Benefit Plans (Severan

Employee Benefit Plans (Severances) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Mar. 29, 2017
Supplemental Unemployment Benefits [Line Items]
Foreign currency translation adjustments	$ 27	$ (224)	$ 211	$ 959
Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member]
Supplemental Unemployment Benefits [Line Items]
Severance accrual current period change	16		55
Foster Creek Christina Lake (FCCL) [Member]
Supplemental Unemployment Benefits [Line Items]
Investment Owned Percent Of Net Assets					50.00%
Employee Severance
Supplemental Unemployment Benefits [Line Items]
Severance Accrual, Beginning Balance			80
Severance accrual current period change			55
Payments For Postemployment Benefits			(68)
Severance Accrual, Ending Balance	67		67
Short term portion of severance accrual	$ 43		$ 43

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Significant transactions with related parties
Operating revenues and other income	$ 30	$ 28	$ 59	$ 55
Purchases	25	25	48	49
Operating expenses and selling, general and administrative expenses	14	12	26	28
Net interest (income) expense	$ (3)	$ (3)	$ (6)	$ (6)

Segment Disclosures and Relat71

Segment Disclosures and Related Information - Sales (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 6,781	$ 5,348	$ 14,299	$ 10,469
Alaska [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	1,071	936	2,078	1,714
Lower 48 Before Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	3,090	2,395	6,320	4,540
Intersegment Eliminations before Lower 48 [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	(2)	(5)	(5)	(12)
Lower 48 [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	3,088	2,390	6,315	4,528
Canada before Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	788	391	1,658	816
Intersegment Eliminations before Canada [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	(89)	(30)	(175)	(65)
Canada [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	699	361	1,483	751
Europe and North Africa [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	1,011	736	2,454	1,659
Asia Pacific and Middle East [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	896	897	1,918	1,734
Corporate and Other [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 16	$ 28	$ 51	$ 83

Segment Disclosures and Relat72

Segment Disclosures and Related Information - Net Income (Details 1) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Net Income Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	$ (3,440)	$ (1,071)	$ (2,854)	$ (2,540)
Alaska [Member]
Net Income Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	199	147	188	145
Lower 48 [Member]
Net Income Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(2,536)	(771)	(2,898)	(1,591)
Canada [Member]
Net Income Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	1,379	(175)	2,327	(469)
Europe and North Africa [Member]
Net Income Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	123	20	294	(31)
Asia Pacific and Middle East [Member]
Net Income Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(2,172)	72	(1,936)	67
Other International [Member]
Net Income Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(9)	(29)	(57)	(53)
Corporate and Other [Member]
Net Income Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	$ (424)	$ (335)	$ (772)	$ (608)

Segment Disclosures and Relat73

Segment Disclosures and Related Information (Details Textual)	6 Months Ended
	Jun. 30, 2017
Segment Disclosures and Related Information (Textual) [Abstract]
Number of operating segments	6

Segment Disclosures and Relat74

Segment Disclosures and Related Information - Assets (Details 2) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016
Assets [Abstract]
Consolidated total assets	$ 78,004	$ 89,772
Alaska [Member]
Assets [Abstract]
Consolidated total assets	12,163	12,314
Lower 48 [Member]
Assets [Abstract]
Consolidated total assets	17,637	22,673
Canada [Member]
Assets [Abstract]
Consolidated total assets	6,122	17,548
Europe and North Africa [Member]
Assets [Abstract]
Consolidated total assets	11,564	11,727
Asia Pacific and Middle East [Member]
Assets [Abstract]
Consolidated total assets	17,389	20,451
Other International [Member]
Assets [Abstract]
Consolidated total assets	116	97
Corporate and Other [Member]
Assets [Abstract]
Consolidated total assets	$ 13,013	$ 4,962

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016	Mar. 29, 2017
Income Taxes (Textual) [Abstract]
Effective tax rate	21.40%	35.60%	38.40%	35.00%
Domestic federal statutory rate	35.00%	35.00%	35.00%	35.00%
Current Income Tax Expense Benefit [Line Items]
Income Tax Expense (Benefit)	$ (935)	$ (586)	$ (1,766)	$ (1,354)
Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member] | Oil and Gas Properties [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]
Current Income Tax Expense Benefit [Line Items]
Current Foreign Tax Expense (Benefit)	172		1,168
Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member] | Oil and Gas Properties [Member] | Scenario, Plan [Member] | Disposal Group Held for sale Not Discontinued Operations [Member]
Current Income Tax Expense Benefit [Line Items]
Current Foreign Tax Expense (Benefit)		$ (68)
Income Tax Expense (Benefit)	(822)
Deferred Tax Assets, Valuation Allowance	$ 822		822
Foster Creek Christina Lake (FCCL) [Member]
Current Income Tax Expense Benefit [Line Items]
Percent interest					50.00%
CANADA | Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member]
Current Income Tax Expense Benefit [Line Items]
Current Foreign Tax Expense (Benefit)			$ 0

Income Taxes (Tax Reconciliatio

Income Taxes (Tax Reconciliation) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Income Loss Before Income Taxes Domestic	$ (4,269)	$ (1,373)	$ (5,063)	$ (2,964)
Income Loss Before Income Taxes Foreign	(92)	(271)	470	(904)
Income (Loss) before income taxes	(4,361)	(1,644)	(4,593)	(3,868)
Effective Income Tax Rate Reconciliation at Federal Statutory Income Tax Rate, Amount	(1,526)	(575)	(1,608)	(1,354)
Effective Income Tax Rate Reconciliation, Foreign Income Tax Rate Differential, Amount	69	104	335	173
Effective Income Tax Rate Reconciliation, Disposition of Asset, Amount	(172)	0	(1,168)	0
Income Tax Reconciliation Recovery of outside basis	(4)	(12)	(839)	(23)
ffective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Amount	0	0	822	0
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Impairment Losses, Amount	834	0	834	0
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount	(99)	(78)	(88)	(110)
Effective Income Tax Rate Reconciliation, Tax Credit, Amount, Total	(29)	(17)	(45)	(34)
Effective Income Tax Rate Reconciliation, Other Reconciling Items, Amount	(8)	(8)	(9)	(6)
Income Tax Expense (Benefit)	$ (935)	$ (586)	$ (1,766)	$ (1,354)
Effective Income Tax Rate Continuing Operations Tax Rate Reconciliation Abstract
Income (Loss) Before Income Taxes Domestic Percentage	97.90%	83.50%	110.20%	76.60%
Income (Loss) Before Income Taxes Foreign Percentage	2.10%	16.50%	(10.20%)	23.40%
Income (Loss) Before Income Taxes In Percent	100.00%	100.00%	100.00%	100.00%
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate	35.00%	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, Foreign Income Tax Rate Differential, Percent	(1.60%)	(6.30%)	(7.30%)	(4.50%)
Effective Income Tax Rate Reconciliation, Disposition of Asset, Percent	3.90%	0.00%	25.40%	0.00%
Income Tax Reconciliation Recovery of outside basis, percent	0.10%	0.70%	18.30%	0.60%
Effective Income Tax Rate Reconciliation, Change in Deferred Tax Assets Valuation Allowance, Percent	0.00%	0.00%	(17.90%)	0.00%
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Impairment Losses, Percent	(19.10%)	0.00%	(18.20%)	0.00%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Percent	2.30%	4.70%	1.90%	2.80%
Effective Income Tax Rate Reconciliation, Tax Credit, Percent	0.70%	1.00%	1.00%	0.90%
Effective Income Tax Rate Reconciliation,Other Reconciling Items, Percent	0.10%	0.50%	0.20%	0.20%
Effective Income Tax Rate, Continuing Operations	21.40%	35.60%	38.40%	35.00%

Supplementary Information - C77

Supplementary Information - Condensed Consolidating Financial Information - Inc Stmt (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2017	Jun. 30, 2016	Jun. 30, 2017	Jun. 30, 2016
Revenues and Other Income
Sales and other operating revenues	$ 6,781	$ 5,348	$ 14,299	$ 10,469
Equity in earnings (losses) of affiliates	178	80	378	(69)
Gain (loss) on dispositions	1,876	128	1,898	151
Other income	47	19	78	39
Intercompany revenues	0	0	0
Total Revenues and Other Income	8,882	5,575	16,653	10,590
Costs and Expenses
Purchased commodities	2,922	2,002	6,114	4,227
Production and operating expenses	1,327	1,445	2,625	2,799
Selling, general and administrative expenses	134	167	291	353
Exploration expenses	98	610	649	1,115
Depreciation, depletion and amortization	1,625	2,329	3,604	4,576
Impairments	6,294	62	6,469	198
Taxes other than income taxes	198	197	429	377
Accretion on discounted liabilities	92	112	187	221
Interest and debt expense	306	312	621	593
Foreign currency transaction (gains) losses	13	(17)	23	(1)
Other Non Operating Expense	234		234
Total Costs and Expenses	13,243	7,219	21,246	14,458
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	(4,361)	(1,644)	(4,593)	(3,868)
Income tax provision (benefit)	(935)	(586)	(1,766)	(1,354)
Net income (loss)	(3,426)	(1,058)	(2,827)	(2,514)
Less: net income attributable to noncontrolling interests	(14)	(13)	(27)	(26)
Net Income (Loss)	(3,440)	(1,071)	(2,854)	(2,540)
Comprehensive Income (Loss) Attributable to ConocoPhillips	(3,821)	(1,296)	(3,003)	(1,664)
Consolidating Adjustments [Member]
Revenues and Other Income
Sales and other operating revenues	0	0	0	0
Equity in earnings (losses) of affiliates	5,557	959	3,767	3,431
Gain (loss) on dispositions	0	0	0	0
Other income	0	0	0	0
Intercompany revenues	(919)	(1,082)	(1,843)	(1,762)
Total Revenues and Other Income	4,638	(123)	1,924	1,669
Costs and Expenses
Purchased commodities	(753)	(678)	(1,516)	(1,180)
Production and operating expenses	(1)	(234)	(2)	(237)
Selling, general and administrative expenses	0	0	(5)	(6)
Exploration expenses	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairments	0	0	0	0
Taxes other than income taxes	0	0	0	0
Accretion on discounted liabilities	0	0	0	0
Interest and debt expense	(165)	(170)	(320)	(339)
Foreign currency transaction (gains) losses	0	0	0	0
Other Non Operating Expense	0		0
Total Costs and Expenses	(919)	(1,082)	(1,843)	(1,762)
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	5,557	959	3,767	3,431
Income tax provision (benefit)	0	0	0	0
Net income (loss)	5,557	959	3,767	3,431
Less: net income attributable to noncontrolling interests	0	0	0	0
Net Income (Loss)	5,557	959	3,767	3,431
Comprehensive Income (Loss) Attributable to ConocoPhillips	5,849	1,392	3,611	1,320
ConocoPhillips [Member]
Revenues and Other Income
Sales and other operating revenues	0	0	0	0
Equity in earnings (losses) of affiliates	(3,235)	(1,003)	(2,578)	(2,430)
Gain (loss) on dispositions	0	0	0	0
Other income	1	0	1	0
Intercompany revenues	12	26	29	44
Total Revenues and Other Income	(3,222)	(977)	(2,548)	(2,386)
Costs and Expenses
Purchased commodities	0	0	0	0
Production and operating expenses	0	0	0	0
Selling, general and administrative expenses	2	2	6	5
Exploration expenses	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairments	0	0	0	0
Taxes other than income taxes	0	0	0	0
Accretion on discounted liabilities	0	0	0	0
Interest and debt expense	125	126	254	250
Foreign currency transaction (gains) losses	(15)	2	(22)	(42)
Other Non Operating Expense	217		217
Total Costs and Expenses	329	130	455	213
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	(3,551)	(1,107)	(3,003)	(2,599)
Income tax provision (benefit)	(111)	(36)	(149)	(59)
Net income (loss)	(3,440)	(1,071)	(2,854)	(2,540)
Less: net income attributable to noncontrolling interests	0	0	0	0
Net Income (Loss)	(3,440)	(1,071)	(2,854)	(2,540)
Comprehensive Income (Loss) Attributable to ConocoPhillips	(3,821)	(1,296)	(3,003)	(1,664)
ConocoPhillips Company [Member]
Revenues and Other Income
Sales and other operating revenues	2,954	2,284	6,069	4,356
Equity in earnings (losses) of affiliates	(2,297)	(21)	(1,124)	(771)
Gain (loss) on dispositions	16	63	29	85
Other income	13	1	15	(5)
Intercompany revenues	74	68	145	149
Total Revenues and Other Income	760	2,395	5,134	3,814
Costs and Expenses
Purchased commodities	2,637	1,998	5,402	3,846
Production and operating expenses	139	488	280	741
Selling, general and administrative expenses	110	136	246	290
Exploration expenses	33	551	405	982
Depreciation, depletion and amortization	204	306	455	563
Impairments	1,074	37	1,074	41
Taxes other than income taxes	36	39	85	96
Accretion on discounted liabilities	10	12	20	24
Interest and debt expense	171	164	336	298
Foreign currency transaction (gains) losses	2	0	2	2
Other Non Operating Expense	17		17
Total Costs and Expenses	4,433	3,731	8,322	6,883
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	(3,673)	(1,336)	(3,188)	(3,069)
Income tax provision (benefit)	(438)	(333)	(610)	(639)
Net income (loss)	(3,235)	(1,003)	(2,578)	(2,430)
Less: net income attributable to noncontrolling interests	0	0	0	0
Net Income (Loss)	(3,235)	(1,003)	(2,578)	(2,430)
Comprehensive Income (Loss) Attributable to ConocoPhillips	(3,616)	(1,228)	(2,727)	(1,554)
ConocoPhillips Canada Funding Company I [Member]
Revenues and Other Income
Sales and other operating revenues	0	0	0	0
Equity in earnings (losses) of affiliates	0	0	0	0
Gain (loss) on dispositions	0	0	0	0
Other income	0	0	0	0
Intercompany revenues	41	60	83	116
Total Revenues and Other Income	41	60	83	116
Costs and Expenses
Purchased commodities	0	0	0	0
Production and operating expenses	0	0	0	0
Selling, general and administrative expenses	0	0	0	0
Exploration expenses	0	0	0	0
Depreciation, depletion and amortization	0	0	0	0
Impairments	0	0	0	0
Taxes other than income taxes	0	0	0	0
Accretion on discounted liabilities	0	0	0	0
Interest and debt expense	36	57	73	112
Foreign currency transaction (gains) losses	19	(79)	68	233
Other Non Operating Expense	0		0
Total Costs and Expenses	55	(22)	141	345
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	(14)	82	(58)	(229)
Income tax provision (benefit)	11	19	6	1
Net income (loss)	(25)	63	(64)	(230)
Less: net income attributable to noncontrolling interests	0	0	0	0
Net Income (Loss)	(25)	63	(64)	(230)
Comprehensive Income (Loss) Attributable to ConocoPhillips	30	51	17	4
All Other Subsidiaries [Member]
Revenues and Other Income
Sales and other operating revenues	3,827	3,064	8,230	6,113
Equity in earnings (losses) of affiliates	153	145	313	(299)
Gain (loss) on dispositions	1,860	65	1,869	66
Other income	33	18	62	44
Intercompany revenues	792	928	1,586	1,453
Total Revenues and Other Income	6,665	4,220	12,060	7,377
Costs and Expenses
Purchased commodities	1,038	682	2,228	1,561
Production and operating expenses	1,189	1,191	2,347	2,295
Selling, general and administrative expenses	22	29	44	64
Exploration expenses	65	59	244	133
Depreciation, depletion and amortization	1,421	2,023	3,149	4,013
Impairments	5,220	25	5,395	157
Taxes other than income taxes	162	158	344	281
Accretion on discounted liabilities	82	100	167	197
Interest and debt expense	139	135	278	272
Foreign currency transaction (gains) losses	7	60	(25)	(194)
Other Non Operating Expense	0		0
Total Costs and Expenses	9,345	4,462	14,171	8,779
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest	(2,680)	(242)	(2,111)	(1,402)
Income tax provision (benefit)	(397)	(236)	(1,013)	(657)
Net income (loss)	(2,283)	(6)	(1,098)	(745)
Less: net income attributable to noncontrolling interests	(14)	(13)	(27)	(26)
Net Income (Loss)	(2,297)	(19)	(1,125)	(771)
Comprehensive Income (Loss) Attributable to ConocoPhillips	$ (2,263)	$ (215)	$ (901)	$ 230

Supplementary Information - C78

Supplementary Information - Condensed Consolidating Financial Information - Bal Sheet (Details 1) - USD ($) $ in Millions	Jun. 30, 2017	Dec. 31, 2016	Jun. 30, 2016	Dec. 31, 2015
Assets
Cash and cash equivalents	$ 7,534	$ 3,610	$ 2,863	$ 2,368
Short-term investments	2,733	50
Accounts and notes receivable	3,163	3,414
Investment in Cenovus Energy	1,533	0
Inventories	1,019	1,018
Prepaid expenses and other current assets	3,897	517
Total Current Assets	19,879	8,609
Investments, loans and long-term receivables	10,203	21,672
Net properties, plants and equipment	46,846	58,331
Other assets	1,076	1,160
Total Assets	78,004	89,772
Liabilities and Stockholders' Equity
Accounts payable and related party accounts payable	3,434	3,653
Short-term debt	3,798	1,089
Accrued income and other taxes	791	484
Employee benefit obligations	509	689
Other accruals	1,394	994
Total Current Liabilities	9,926	6,909
Long-term debt	19,670	26,186
Asset retirement obligations and accrued environmental costs	7,631	8,425
Deferred income taxes	6,335	8,949
Employee benefit obligations	2,499	2,552
Other liabilities and deferred credits	1,444	1,525
Total Liabilities	47,505	54,546
Retained earnings	28,033	31,548
Other common stockholders' equity	2,253	3,426
Noncontrolling interests	213	252
Total Liabilities and Stockholders' Equity	78,004	89,772
Consolidating Adjustments [Member]
Assets
Cash and cash equivalents	0	0	0	0
Short-term investments	0	0
Accounts and notes receivable	(2,218)	(4,702)
Investment in Cenovus Energy	0
Inventories	0	0
Prepaid expenses and other current assets	(27)	(24)
Total Current Assets	(2,245)	(4,726)
Investments, loans and long-term receivables	(101,935)	(114,602)
Net properties, plants and equipment	0	0
Other assets	(3,311)	(2,534)
Total Assets	(107,491)	(121,862)
Liabilities and Stockholders' Equity
Accounts payable and related party accounts payable	(2,218)	(4,702)
Short-term debt	0	0
Accrued income and other taxes	0	0
Employee benefit obligations	0	0
Other accruals	(27)	(24)
Total Current Liabilities	(2,245)	(4,726)
Long-term debt	0	0
Asset retirement obligations and accrued environmental costs	0	0
Deferred income taxes	(2,776)	(2,023)
Employee benefit obligations	0	0
Other liabilities and deferred credits	(28,935)	(27,863)
Total Liabilities	(33,956)	(34,612)
Retained earnings	(15,161)	(19,834)
Other common stockholders' equity	(58,374)	(67,416)
Noncontrolling interests	0	0
Total Liabilities and Stockholders' Equity	(107,491)	(121,862)
ConocoPhillips [Member]
Assets
Cash and cash equivalents	0		0	0
Short-term investments	0	0
Accounts and notes receivable	82	22
Investment in Cenovus Energy	0
Inventories	0	0
Prepaid expenses and other current assets	1	2
Total Current Assets	83	24
Investments, loans and long-term receivables	34,470	37,901
Net properties, plants and equipment	0	0
Other assets	43	40
Total Assets	34,596	37,965
Liabilities and Stockholders' Equity
Accounts payable and related party accounts payable	0	0
Short-term debt	1,688	(10)
Accrued income and other taxes	0	0
Employee benefit obligations	0	0
Other accruals	102	171
Total Current Liabilities	1,790	161
Long-term debt	3,784	8,975
Asset retirement obligations and accrued environmental costs	0	0
Deferred income taxes	0	0
Employee benefit obligations	0	0
Other liabilities and deferred credits	5,298	417
Total Liabilities	10,872	9,553
Retained earnings	21,510	25,025
Other common stockholders' equity	2,214	3,387
Noncontrolling interests	0	0
Total Liabilities and Stockholders' Equity	34,596	37,965
ConocoPhillips Company [Member]
Assets
Cash and cash equivalents	1,162	358	265	4
Short-term investments	0	0
Accounts and notes receivable	1,656	1,968
Investment in Cenovus Energy	1,533
Inventories	112	84
Prepaid expenses and other current assets	436	116
Total Current Assets	4,899	2,526
Investments, loans and long-term receivables	56,453	64,434
Net properties, plants and equipment	4,330	6,301
Other assets	2,906	2,194
Total Assets	68,588	75,455
Liabilities and Stockholders' Equity
Accounts payable and related party accounts payable	2,357	4,683
Short-term debt	2,000	999
Accrued income and other taxes	76	85
Employee benefit obligations	382	489
Other accruals	680	271
Total Current Liabilities	5,495	6,527
Long-term debt	11,338	12,635
Asset retirement obligations and accrued environmental costs	560	925
Deferred income taxes	0	0
Employee benefit obligations	1,874	1,901
Other liabilities and deferred credits	8,972	10,391
Total Liabilities	28,239	32,379
Retained earnings	11,437	14,015
Other common stockholders' equity	28,912	29,061
Noncontrolling interests	0	0
Total Liabilities and Stockholders' Equity	68,588	75,455
ConocoPhillips Canada Funding Company I [Member]
Assets
Cash and cash equivalents	34	13	10	15
Short-term investments	0	0
Accounts and notes receivable	35	23
Investment in Cenovus Energy	0
Inventories	0	0
Prepaid expenses and other current assets	7	8
Total Current Assets	76	44
Investments, loans and long-term receivables	2,377	2,296
Net properties, plants and equipment	0	0
Other assets	203	220
Total Assets	2,656	2,560
Liabilities and Stockholders' Equity
Accounts payable and related party accounts payable	2	1
Short-term debt	6	6
Accrued income and other taxes	0	0
Employee benefit obligations	0	0
Other accruals	45	40
Total Current Liabilities	53	47
Long-term debt	1,706	1,710
Asset retirement obligations and accrued environmental costs	0	0
Deferred income taxes	0	0
Employee benefit obligations	0	0
Other liabilities and deferred credits	824	748
Total Liabilities	2,583	2,505
Retained earnings	(605)	(541)
Other common stockholders' equity	678	596
Noncontrolling interests	0	0
Total Liabilities and Stockholders' Equity	2,656	2,560
All Other Subsidiaries [Member]
Assets
Cash and cash equivalents	6,338	3,239	$ 2,588	$ 2,349
Short-term investments	2,733	50
Accounts and notes receivable	3,608	6,103
Investment in Cenovus Energy	0
Inventories	907	934
Prepaid expenses and other current assets	3,480	415
Total Current Assets	17,066	10,741
Investments, loans and long-term receivables	18,838	31,643
Net properties, plants and equipment	42,516	52,030
Other assets	1,235	1,240
Total Assets	79,655	95,654
Liabilities and Stockholders' Equity
Accounts payable and related party accounts payable	3,293	3,671
Short-term debt	104	94
Accrued income and other taxes	715	399
Employee benefit obligations	127	200
Other accruals	594	536
Total Current Liabilities	4,833	4,900
Long-term debt	2,842	2,866
Asset retirement obligations and accrued environmental costs	7,071	7,500
Deferred income taxes	9,111	10,972
Employee benefit obligations	625	651
Other liabilities and deferred credits	15,285	17,832
Total Liabilities	39,767	44,721
Retained earnings	10,852	12,883
Other common stockholders' equity	28,823	37,798
Noncontrolling interests	213	252
Total Liabilities and Stockholders' Equity	$ 79,655	$ 95,654

Supplementary Information - C79

Supplementary Information - Condensed Consolidating Financial Information - Cash Flow (Details 2) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	6 Months Ended
	Apr. 30, 2017	Jun. 30, 2017	Jun. 30, 2017	Jun. 30, 2016
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities			$ 3,541	$ 1,680
Cash Flows From Investing Activities
Capital expenditures and investments			(1,986)	(2,954)
Working capital changes associated with investing activities			(113)	(363)
Proceeds from asset dispositions			10,742	363
Net sales (purchases) of short-term investments			(2,653)	(1,292)
Long-term advances/loans-related parties			0	0
Collection of advances/loans-related parties			57	53
Intercompany cash management			0	0
Other	$ 135		176	6
Net cash used in continuing investing activities			6,223	(4,187)
Cash Flows From Financing Activities
Issuance of debt			0	4,594
Repayment of debt		$ (3,000)	(4,079)	(827)
Change in restricted cash			0
Issuance of company common stock			(63)	(45)
Repurchase of company common stock			(1,075)
Dividends paid			(662)	(626)
Other			(64)	(79)
Net cash provided by (used in) continuing financing activities			(5,943)	3,017
Effect of Exchange Rate Changes on Cash and Cash Equivalents			103	(15)
Net Change in Cash and Cash Equivalents			3,924	495
Cash and cash equivalents at beginning of period			3,610	2,368
Cash and Cash Equivalents at End of Period		7,534	7,534	2,863
Consolidating Adjustments [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities			(794)	(963)
Cash Flows From Investing Activities
Capital expenditures and investments			868	401
Working capital changes associated with investing activities			0	0
Proceeds from asset dispositions			(9,883)	(2,324)
Net sales (purchases) of short-term investments			0	0
Long-term advances/loans-related parties			83	803
Collection of advances/loans-related parties			(2,802)	(1,573)
Intercompany cash management			0	0
Other			0	0
Net cash used in continuing investing activities			(11,734)	(2,693)
Cash Flows From Financing Activities
Issuance of debt			(83)	(803)
Repayment of debt			2,802	1,573
Change in restricted cash			0
Issuance of company common stock			(112)	(115)
Repurchase of company common stock			0
Dividends paid			906	1,078
Other			9,015	1,923
Net cash provided by (used in) continuing financing activities			12,528	3,656
Effect of Exchange Rate Changes on Cash and Cash Equivalents			0	0
Net Change in Cash and Cash Equivalents			0	0
Cash and cash equivalents at beginning of period			0	0
Cash and Cash Equivalents at End of Period		0	0	0
ConocoPhillips [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities			(137)	(153)
Cash Flows From Investing Activities
Capital expenditures and investments			0	0
Working capital changes associated with investing activities			0	0
Proceeds from asset dispositions			0	2,300
Net sales (purchases) of short-term investments			0	0
Long-term advances/loans-related parties			0	0
Collection of advances/loans-related parties			658	0
Intercompany cash management			4,882	(3,190)
Other			0	0
Net cash used in continuing investing activities			5,540	(890)
Cash Flows From Financing Activities
Issuance of debt			0	1,600
Repayment of debt			(3,717)	0
Change in restricted cash			0
Issuance of company common stock			49	70
Repurchase of company common stock			(1,075)
Dividends paid			(662)	(626)
Other			2	(1)
Net cash provided by (used in) continuing financing activities			(5,403)	1,043
Effect of Exchange Rate Changes on Cash and Cash Equivalents			0	0
Net Change in Cash and Cash Equivalents			0	0
Cash and cash equivalents at beginning of period				0
Cash and Cash Equivalents at End of Period		0	0	0
ConocoPhillips Company [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities			(1,475)	572
Cash Flows From Investing Activities
Capital expenditures and investments			(1,125)	(823)
Working capital changes associated with investing activities			39	(76)
Proceeds from asset dispositions			9,909	160
Net sales (purchases) of short-term investments			0	0
Long-term advances/loans-related parties			(63)	(803)
Collection of advances/loans-related parties			63	0
Intercompany cash management			(4,214)	2,127
Other			43	2
Net cash used in continuing investing activities			4,652	587
Cash Flows From Financing Activities
Issuance of debt			20	2,994
Repayment of debt			(2,394)	(1,573)
Change in restricted cash			0
Issuance of company common stock			0	0
Repurchase of company common stock			0
Dividends paid			0	0
Other			0	(2,319)
Net cash provided by (used in) continuing financing activities			(2,374)	(898)
Effect of Exchange Rate Changes on Cash and Cash Equivalents			1	0
Net Change in Cash and Cash Equivalents			804	261
Cash and cash equivalents at beginning of period			358	4
Cash and Cash Equivalents at End of Period		1,162	1,162	265
ConocoPhillips Canada Funding Company I [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities			21	(5)
Cash Flows From Investing Activities
Capital expenditures and investments			0	0
Working capital changes associated with investing activities			0	0
Proceeds from asset dispositions			0	0
Net sales (purchases) of short-term investments			0	0
Long-term advances/loans-related parties			0	0
Collection of advances/loans-related parties			0	0
Intercompany cash management			0	0
Other			0	0
Net cash used in continuing investing activities			0	0
Cash Flows From Financing Activities
Issuance of debt			0	0
Repayment of debt			0	0
Change in restricted cash			0
Issuance of company common stock			0	0
Repurchase of company common stock			0
Dividends paid			0	0
Other			0	0
Net cash provided by (used in) continuing financing activities			0	0
Effect of Exchange Rate Changes on Cash and Cash Equivalents			0	0
Net Change in Cash and Cash Equivalents			21	(5)
Cash and cash equivalents at beginning of period			13	15
Cash and Cash Equivalents at End of Period		34	34	10
All Other Subsidiaries [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities			5,926	2,229
Cash Flows From Investing Activities
Capital expenditures and investments			(1,729)	(2,532)
Working capital changes associated with investing activities			(152)	(287)
Proceeds from asset dispositions			10,716	227
Net sales (purchases) of short-term investments			(2,653)	(1,292)
Long-term advances/loans-related parties			(20)	0
Collection of advances/loans-related parties			2,138	1,626
Intercompany cash management			(668)	1,063
Other			133	4
Net cash used in continuing investing activities			7,765	(1,191)
Cash Flows From Financing Activities
Issuance of debt			63	803
Repayment of debt			(770)	(827)
Change in restricted cash			0
Issuance of company common stock			0	0
Repurchase of company common stock			0
Dividends paid			(906)	(1,078)
Other			(9,081)	318
Net cash provided by (used in) continuing financing activities			(10,694)	(784)
Effect of Exchange Rate Changes on Cash and Cash Equivalents			102	(15)
Net Change in Cash and Cash Equivalents			3,099	239
Cash and cash equivalents at beginning of period			3,239	2,349
Cash and Cash Equivalents at End of Period		$ 6,338	$ 6,338	$ 2,588