ConocoPhillips (COP) 10-Q 30 Oct 18 2018 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information	9 Months Ended
	Sep. 30, 2018shares
Document and Entity Information [Abstract]
Entity Registrant Name	CONOCOPHILLIPS
Entity Central Index Key	1,163,165
Document Type	10-Q
Document Period End Date	Sep. 30, 2018
Amendment Flag	false
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding	1,151,241,888
Trading Symbol	COP
Entity Small Business	false
Entity Emerging Growth Company	false

Consolidated Income Statement

Consolidated Income Statement - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017		Sep. 30, 2018	Sep. 30, 2017
Revenues and Other Income
Sales and other operating revenues	$ 9,449	$ 6,688		$ 26,751	$ 20,987
Equity in earnings (losses) of affiliates	294	196		767	574
Gain on Dispositions	113	246		175	2,144
Other income	309	65		673	143
Total Revenues and Other Income	10,165	7,195		28,366	23,848
Costs and Expenses
Purchased commodities	3,530	2,926		10,308	9,040
Production and operating expenses	1,367	1,222	[1],[2]	3,851	3,838	[1],[2]
Selling, general and administrative expenses	119	110	[1],[2]	336	302	[1],[2]
Exploration expenses	103	73	[1],[2]	267	720	[1],[2]
Depreciation, depletion and amortization	1,494	1,608		4,344	5,212
Impairments	44	6		21	6,475
Taxes other than Income Taxes	312	175		768	604
Accretion on discounted liabilities	89	89		266	276
Interest and debt expense	186	251		547	872
Foreign currency transaction (gains) losses	5	5		7	28
Other Expense	10	77	[1]	350	421	[1]
Total Costs and Expenses	7,259	6,542		21,065	27,788
Income (Loss) before income taxes	2,906	653		7,301	(3,940)
Income tax provision (benefit)	1,033	217		2,874	(1,549)
Net income (loss)	1,873	436		4,427	(2,391)
Less: net income attributable to noncontrolling interests	(12)	(16)		(38)	(43)
Net Income (Loss) Attributable to ConocoPhillips	$ 1,861	$ 420		$ 4,389	$ (2,434)
Earnings Per Share, Basic [Abstract]
Earnings Per Share, Basic	$ 1.6	$ 0.35		$ 3.74	$ (1.98)
Earnings Per Share, Diluted [Abstract]
Earnings Per Share, Diluted	1.59	0.34		3.72	(1.98)
Dividends Paid Per Share of Common Stock (dollars)	$ 0.29	$ 0.27		$ 0.86	$ 0.8
Average Common Shares Outstanding (in thousands)
Basic	1,163,033	1,212,454		1,171,673	1,230,742
Diluted	1,172,694	1,215,341		1,180,774	1,230,742
[1]	*Certain amounts have been reclassified to conform to the current-period presentation resulting from the adoption of ASU No. 2017-07.
[2]	See Note 2—Changes in Accounting Principles, for additional information.

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017		Sep. 30, 2018	Sep. 30, 2017
Consolidated Statement of Comprehensive Income [Abstract]
Net income (loss)		$ 1,873	$ 436		$ 4,427	$ (2,391)
Defined benefit plans
Reclassification adjustment for amortization of prior service cost (credit) included in net income		(10)	(9)		(30)	(28)
Net actuarial gain (loss) arising during the period		187	13		145	(26)
Reclassification adjustment for amortization of net actuarial losses included in net income		33	49		228	205
Other Comprehensive Income Loss NonSponsored Plan	[1]	0	0		(1)	0
Income taxes on defined benefit plans		(74)	(18)		(102)	(52)
Defined benefit plans, net of tax		136	35		240	99
Unrealized holding gain (loss) on securities		0	551		0	127
Income taxes on unrealized holding gain on securities		0	(45)		0	(45)
Unrealized holding loss on securities, net of tax		0	506	[2]	0	82	[2]
Foreign currency translation adjustments		59	509		(222)	720
Foreign currency translation adjustments, net of tax		59	509		(222)	720
Other Comprehensive Income (Loss), Net of Tax		195	1,050		18	901
Comprehensive Income (Loss)		2,068	1,486		4,445	(1,490)
Less: comprehensive income attributable to noncontrolling interests		(12)	(16)		(38)	(43)
Comprehensive Income (Loss) Attributable to ConocoPhillips		$ 2,056	$ 1,470		$ 4,407	$ (1,533)	[3]
[1]	*Plans for which ConocoPhillips is not the primary obligor, primarily those administered by equity affiliates.
[2]	**See Note 2—Changes in Accounting Principles and Note 16—Accumulated Other Comprehensive Loss for additional information relating to the adoption of ASU 2016-01.
[3]	See Notes to Consolidated Financial Statements.

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions		Sep. 30, 2018	Dec. 31, 2017
Assets
Cash and cash equivalents		$ 3,716	$ 6,325
Short-term investments		875	1,873
Accounts and notes receivable (net of allowance of $11 million in 2018 and $4 million in 2017)		4,319	4,179
Accounts and notes receivable-related parties		180	141
Investment in Cenovus Energy		2,086	1,899
Inventories		1,239	1,060
Prepaid expenses and other current assets		2,308	1,035
Total Current Assets		14,723	16,512
Investments and long-term receiavables		9,553	9,599
Loans and advances-related parties		335	461
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $66,664 million in 2018 and $64,748 million in 2017)		44,736	45,683
Other assets		1,209	1,107
Total Assets		70,556	73,362
Liabilities
Accounts payable		3,887	4,009
Accounts payable-related parties		31	21
Short-term debt		95	2,575
Accrued income and other taxes		1,582	1,038
Employee benefit obligations		626	725
Other accruals		1,180	1,029
Total Current Liabilities		7,401	9,397
Long-term debt		14,902	17,128
Asset retirement obligations and accrued environmental costs		7,554	7,631
Deferred income taxes		5,535	5,282
Employee benefit obligations		1,755	1,854
Other liabilities and deferred credits		1,330	1,269
Total Liabilities		38,477	42,561
Equity
Common stock (2,500,000,000 shares authorized at $.01 par value) Issued (2018 - 1,790,924,215 shares; 2017 - 1,785,419,175 shares) Par value		18	18
Capital in excess of par		46,858	46,622
Treasury stock (at cost: 2018 - 639,682,327 shares; 2017 - 608,312,034 shares)		(41,979)	(39,906)
Accumulated other comprehensive income (loss)		(5,442)	(5,518)
Retained earnings		32,495	29,391
Total Common Stockholders' Equity		31,950	30,607
Noncontrolling interests		129	194
Total Equity		32,079	30,801
Total Liabilities and Equity	[1]	$ 70,556	$ 73,362
[1]	See Notes to Consolidated Financial Statements.

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($)	Sep. 30, 2018	Dec. 31, 2017
Consolidated Balance Sheet [Abstract]
Allowance for accounts and notes receivable	$ 11,000,000	$ 4,000,000
Accumulated depreciation, depletion and amortization	$ 66,664,000,000	$ 64,748,000,000
Common stock, shares authorized	2,500,000,000	2,500,000,000
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares issued	1,790,924,215	1,785,419,175
Treasury stock, shares	639,682,327	608,312,034

Consolidated Statement of Cash

Consolidated Statement of Cash Flows $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)		Sep. 30, 2017USD ($)
Cash Flows From Operating Activities
Net income (loss)	$ 4,427		$ (2,391)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation, depletion and amortization	4,344		5,212
Impairments	21		6,475
Dry hole costs and leasehold impairments	64		435
Accretion on discounted liabilities	266		276
Deferred taxes	398		(2,770)
Distributions received greater than equity losses (undistributed equity earnings)	(11)		(193)
Gain on dispositions	(175)		(2,144)
Other	(223)		(367)
Working capital adjustments
Decrease (increase) in accounts and notes receivable	(147)		65
Decrease (increase) in inventories	(165)		(15)
Decrease (increase) in prepaid expenses and other current assets	(51)		(12)
Increase (decrease) in accounts payable	(43)		(212)
Increase (decrease) in taxes and other accruals	446		237
Net cash provided by operating activities	9,151		4,596
Cash Flows From Investing Activities
Capital expenditures and investments	(5,133)		(3,074)
Working capital changes associated with investing activities	(57)		(18)
Proceeds from asset dispositions	394		13,740
Net sales (purchases) of short-term investments	996		(2,583)
Collection of advances/loans-related parties	119		115
Other	16		51
Net Cash Provided by (Used in) Investing Activities	(3,665)		8,231
Cash Flows From Financing Activities
Issuance of debt	0		0
Repayment of debt	(4,970)		(6,594)
Issuance of company common stock	121		(65)
Repurchase of company common stock	(2,073)		(2,045)
Dividends paid	(1,009)		(986)
Other	(111)		(80)
Net Cash Provided by (Used in) Financing Activities	(8,042)		(9,770)
Effect of Exchange Rate Changes on Cash and Cash Equivalents and Restricted Cash	(40)		244
Net Change in Cash and Cash Equivalents and Restricted Cash Increase (Decrease)	(2,596)		3,301
Cash and Cash Equivalents and Restricted Cash at beginning of period	6,536	[1]	3,610
Cash and Cash Equivalents and Restricted Cash at end of period	3,940	[2]	$ 6,911
Restricted Cash	$ 224
[1]	*Restated to include $211 million of restricted cash at January 1, 2018. See Note 2—Changes in Accounting Principles for additional information relating to the adoption of ASU No. 2016-18.
[2]	Restricted cash totaling $224 million is included in the "Other assets" line of our Consolidated Balance Sheet as of September 30, 2018.

Basis of Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2018
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 2017 Annual Report on Form 10-K.

Change in Accounting Principles

Change in Accounting Principles	9 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Changes in Accounting Principles [Text Block]	Note 2 — Changes in Accounting Principles We adopted the provisions of Financial Accounting Standards Board (FASB) Accounting Standards Update ( ASU ) No. 2014-09, “Revenue from Contracts with Customers , ” and its amendments issued by the provisions of ASU No. 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net) , ” ASU No. 2016-10, “Identifying Performance Obligations and Licensing , ” ASU No. 2016-12, “Narrow-Scope Improvements and Practical Expedients , ” and ASU No. 2016-20, “Technical Corrections and Improvements to Topic 606, Revenue From Contracts with Customers , ” collectively Accounting Standards Codification (ASC) Topic 606 , “Revenue from Contracts with Customers,” (ASC Topic 606) beginning January 1, 2018. ASC Topic 60 6 outlines a single comprehensive model for an entity to use in accounting for revenue arising from all contracts with customers except where revenues are in scope of another accounting standard. T he ASU superseded the revenue recognition requirements in ASC Topic 605, “Revenue Recognition , ” and most industry-specific guidance. ASC Topic 606 sets forth a five-step model for determining when and how revenue is recognized. Under the model, an entity is required to recognize revenue to depict the transfer o f goods or services to a customer at an amount reflecting the consideration it expects to receive in exchange for those goods and services. ASC Topic 606 also requires certain additional revenue-related disclosures. The adoption of ASC Topic 606 did not have a material impact on our consolidated financial statements. See Note 20 —S ales and Other Operating Revenues for additional information related to this ASC . We adopted the provisions of F ASB AS U No. 2016-01, “Recognition and Measurement of Financial Assets and Liabilities , ” (AS U No. 2016-01 ) beginning January 1, 2018. The ASU, among other things, requires an entit y to record the changes in fair value of equity investments, other than investments accounted for using the equity method, within net i ncome. Under this ASU, an entity is no longer able to recognize unrealized holding gains and losses on available-for-sale securities in other comprehensive income and instead must recognize them in the income statement . See Note 7 — Investment i n Cenovus Energy and Note 16 — Accumulated Other Comprehensive Loss for additional information relating to this ASU The cumulative effect of the changes made to our consolidated balance sheet at January 1, 2018, for the adoption of ASC Topic 606 and ASU No. 2016-01 were as follows: Millions of Dollars December 31 ASC Topic 606 ASU No. 2016-01 January 1 2017 Adjustments Adjustments 2018 Liabilities Other accruals $ 1,029 104 - 1,133 Total current liabilities 9,397 104 - 9,501 Deferred income taxes 5,282 (31) - 5,251 Other liabilities and deferred credits 1,269 147 - 1,416 Total liabilities 42,561 220 - 42,781 Equity Accumulated other comprehensive loss $ (5,518) - 58 (5,460) Retained earnings 29,391 (220) (58) 29,113 Total common stockholders' equity 30,607 (220) - 30,387 Total equity 30,801 (220) - 30,581 For discussion of adjustments for ASU No. 2016-01 and ASC Topic 606, see Note 7 — Investment in Cenovus Energy and Note 20—Sales and Other Operating Revenues, respectively. We adopted the provisions of FASB ASU No. 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” beginning January 1, 2018. We retrospectively applied the presentation of service cost separate from the other components of net periodic costs. The interest cost, expected return on plan assets, amortization of prior service cost/credit, recognized net actuarial loss/gain, settlement expense, curtailment loss/gain, and special termination benefits have been reclassified from the “ Production and operating expenses,” “Selling, general and administrative expenses,” and “Exploration expenses” lines to the “ Other expenses” line on our consolidated income statement. We elected to apply the prac tical expedient which allows us to reclassify amounts disclosed previously in the employee benefit plans footnote as the basis for applying retrospective presentation for prior comparative periods as it is impracticable to determine the disaggregation of t he cost components for amounts capitalized and amortized in those periods. On a prospective basis, the other components of net periodic benefit costs will not be included in amounts capitalized in inventory or properties, plants, and equipment (PP&E) The effect of the retrospective presentation change related to the net periodic benefit cost of our defined benefit pension and other postretirement employee benefits plans on our consolidated income statement was as follows: Millions of Dollars Previously Effect of Change As Reported Higher/(Lower) Revised Three Months Ended September 30, 2017 Production and operating expenses $ 1,224 (2) 1,222 Selling, general and administrative expenses 132 (22) 110 Exploration expenses 75 (2) 73 Other expenses 51 26 77 Nine Months Ended September 30, 2017 Production and operating expenses $ 3,849 (11) 3,838 Selling, general and administrative expenses 423 (121) 302 Exploration expenses 724 (4) 720 Other expenses 285 136 421 We adopted the provisions of FASB ASU No. 2016-15 , “Classification of Certain Cash Receipts and Cash Payments , ” beginning January 1, 2018. This ASU clarifies how certain cash receipts and cash payments should be classified and presented in the statement of cash flows. We have made an accounting policy election to classify distributions received from equity method investees using the nature of the distribution approach which classifies distributions received from investees as either cash inflows from operating activities or cash inflows from investing activities in the statement of cash flows based on the nature of the activ ities of the investee that generated the distribution. The impact of adopting this ASU was not material to prior presented periods. We adopted the provisions of FASB ASU No. 2016-18 , “Restricted Cash , ” beginning January 1, 2018. This ASU requires amount s deemed restricted cash to be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows, and presentation should permit a reconciliation when cash, cash equivalent s and restricted cash are presented in more than one line item on the balance sheet. We have amounts deposited in statutory bank accounts in certain countries to satisfy asset retirement obligations (ARO) . These amounts are deemed restricted cash and are included in the “ Other assets ” line of our consolidated balance sheet. This standard is required to be applied retrospectively to all periods presented, but the impact in those periods was not material .

Variable Interest Entities (VIE

Variable Interest Entities (VIEs)	9 Months Ended
	Sep. 30, 2018
Variable Interest Entity[Abstract]
Variable Interest Entity Disclosure [Text Block]	Note 3 — 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 September 30, 2018 , 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 6 —Investments, Loans and Long-Term Receivables, and Note 12 —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 September 30, 2018 , the carrying value of our equity method investment in MWCC was $ 132 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	9 Months Ended
	Sep. 30, 2018
Inventories [Abstract]
Inventories	Note 4—Inventories Inventories consisted of the following: Millions of Dollars September 30 December 31 2018 2017 Crude oil and natural gas $ 673 512 Materials and supplies 566 548 $ 1,239 1,060 Inventories valued on the last-in, first-out (LIFO) basis totaled $ 283 million and $ 341 million at September 30, 2018 and December 31, 2017 , respectively. The estimated excess of current replacement cost over LIFO cost of inventories was $ 100 million and $ 124 million at September 30, 2018 and December 31, 2017 , respectively. As of September 30, 2018, crude oil and natural gas inventory includes $ 139 million of inventory received a s part of a settlement agreement reache d with Petróleos de Venezuela, S.A . (PDVSA) under an International Chamber of Commerce arbitration award. As of the end of October 2018, substantially all of the inventory recognized during the third quarter related to this settlement has been sold. For information about the settlement, see Note 13 — Contingencies and Commitments.

Assets Held for Sale or Sold

Assets Held for Sale or Sold	9 Months Ended
	Sep. 30, 2018
Disposal Group Excluding Discontinued Operation Additional Disclosures [Abstract]
Disposal Groups Exluding Discontinued Operations Disclosure [TextBlock]	Note 5 — Assets Held for Sale, Dispositions, Acquisitions and Other Planned Transactions Assets Held for Sale and Other Planned Acquisition s In the second quarter of 2017, we signed a definitive agreement to sell our interests in the Barnett, and the assets met the asset held for sale criteria. As of September 30, 2017, we had recorded before-tax impairments of $ 5 68 million to reduce our carrying value of these assets to fair value. The agreement was terminated in the fourth quarter of 2017, and we continued to market the asset in 2018. In the first quarter of 201 8, we recorded a before-tax impairment of $ 44 million to reduce the net carrying value to fair value of $ 250 million based on information gathered during marketing efforts. Marketing efforts ceased in April 2018, and the assets were reclassified as held for use in the second quarter of 2018 . In the third quarter of 2018, we signed a definitive agreement to sell our interest in the Barnett to Lime Rock Resources for approximately $ 230 million, subject to customary adjustments. The transaction is expected to close by year-end 2018. In the third quarter of 2018, we recorded a before-tax impairment of $ 43 million to reduce the carrying value to fair value less costs to sell. As of September 30, 2018 , our Barnett asset had a net carrying value of $ 201 million and was considered held for sale resulting in the reclassification of $ 250 million of PP&E to “Prepaid expenses and other current assets” and $ 4 9 million of noncurrent liabilities, primar ily ARO, to “Other accruals” on our consolidated balance sheet. The before-tax loss associated with our interests in the Barnett, including the impairments noted above, was $ 59 million and $ 575 million for the nine - month periods of 2018 and 2017, respectively. T he Barnett results of operations are reported in our Lower 48 segment . In July 2018, we entered into an agreement to sell a ConocoPhillips subsidiary to BP. The subsidiary will hold a 16.5 percent interest in the BP-operated Clair Field in the United Kingdom and we will retain a 7.5 percent interest in the field. At the same time, we entered into an agreement with BP to acquire their 39.2 percent nonoperated interest in the Greater Kuparuk Area in Alaska, including their 38 percent inter est in the Kuparuk Transportation Company (Kuparuk Assets). Both transactions are subject to regulatory approval s and are expected to close simultaneously in late 2018. Excluding customary adjustments, the transactions are expected to be cash neutral. D epending on the timing of regulatory approvals, we anticipate recognizing a noncash gain between $ 0.5 billion to $ 1.0 billion on completion of the sale of the ConocoPhillips subsidiary holding 16.5 percent of the Clair Field, after customary adjustments an d foreign exchange impacts. As of September 30, 2018 , our 16.5 percent interest in the Clair Field had a net carrying value of approximately $ 945 million consisting primarily of $ 1.552 billion of PP&E, $ 544 million of deferred tax liabilities , and $ 63 million o f ARO . As of September 30, 2018 , o ur 16.5 percent interest in the Clair Field was considered held for sale resulting in the reclassification of the $ 1.552 billion of PP&E to “Prepaid expenses and other current assets” and $ 63 million of ARO to “Other accruals” on our consolidated balance sheet. The before-tax earnings associated with our 16.5 percent interest in the Clair Field was $ 1 3 million and $ 1 million for the nine months ended September 30, 2018 and 2017, respectively. Results of operations for our interest in the Clair Field are reported within our Europe and North Africa segment and the Kuparuk Assets are included in our Alaska segment. Asset Dispositions In the first quarter of 2018 , we completed the sale of certai n properties in the Lower 48 segment for net proceeds of $ 112 million. No gain or loss was recognized on the sale. In the second quarter of 2018, we completed the sale of a package of largely undeveloped acreage in the Lower 48 segment for net proceeds o f $ 105 million. No gain or loss was recognized on the sale . In September 2018, we completed a noncash exchange of undeveloped acreage in the Lower 48 segment. The transaction was recorded at fair value resulting in the recognition of a $ 56 million before-tax gain which is r eflected as “Gain on dispositions” in our consolidated income statement. In the first nine months of 2018, we completed several other dispositions. In the second quarter of 2017, we completed the sale of our 50 percent nonopera ted interest in the Foster Creek Christina Lake (FCCL) Partnership, as well as the majority of our western Canada gas assets to Cenovus Energy. C onsideration for the transaction included a five-year uncapped contingent payment. The contingent payment, ca lculated on a quarterly basis, is $ 6 million Canadian dollars (CAD) for every $1 CAD by which the Western Canada Select quarterly average crude price exceeds $52 CAD per barrel. Contingent payments received during the five-year period will be reflected as “Gain on dispositions” in our consolidated income statement. In 2018, we recorded gains on dispositions for these contingent payments of $ 50 million in the second quarter and $ 45 million in the third quarter. In the third quarter of 2017 , we completed the sale of our interests in the San Juan Basin to an affiliate of Hilcorp Energy Company for $ 2.5 billion in cash after customary adjustments and recognized a loss on disposition of $ 22 million. The transaction includes 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 price is at or above $ 3.20 per million British thermal units . The San Juan Basin results of operatio ns were reported within our Lower 48 segment. Acquisition In the second quarter of 2018, we obtained regulatory approvals for the agreement with Anadarko Petroleum Corporation to acquire its 22 percent nonoperated interest in the Western North Slope of Alaska, as well as its interest in the Alpine Pipeline. The transaction was completed in May 2018 for $ 38 6 million , after customary adjustments. These assets are included in our Alaska segment. Other Planned Disposition On October 1, 2018, we entered into an agreement to sell our 30 percent interest in Greater Sunrise Fields to the government of Timor-Leste for $ 350 million, subject to customary adjustments. The transaction is conditional on the funding approval from the Timor-Leste Council of Ministers and National Parliament, as well as regulatory approvals and partner pre-emption rights. We expect it to close in early 2019. These assets are included in our Asia Pacific and Middle East segment.

Investments, Loans and Long-Ter

Investments, Loans and Long-Term Receivables	9 Months Ended
	Sep. 30, 2018
Investments, Loans and Long-Term Receivables [Abstract]
Investments, Loans and Long-Term Receivables	Note 6 —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 payment in March 2017 and will continue to make bi-annual payments until March 2029. APLNG made a voluntary repayment of $ 1.4 billion to the Export-Import Bank of China in September 2018. At the same time, APLNG was successful in obtaining a United States Private Placement (USPP) bond facility of $ 1.4 billion. Interest payments will commence in March 2019 and principal payments in September 2023, with bi-annual payments due on the facility until September 2030. At September 30, 2018 , a balance of $ 7.2 billion was outstanding on the facilities. See Note 12 — 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 3 — Variable Interest Entities (VIEs), for additional information. During the first half 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 circumstan ces surrounding this decline in fair value, we concluded in the second quarter of 2017 the impairment was other than temporary under the guidance of FASB ASC Topic 323, “Investments — Equity Method and Joint Ventures,” and the recognition of an impairment of our investment to fair value was necessary. Accordingly, we recorded a noncash $ 2,384 million before- and after-tax impairment in our second-quarter 2017 results. Fair value was estimated based on an internal discounted cash flow model us ing 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 discount rate believed t o be consistent with those used by principal market participants. The impairment was included in the “Impairments” line on our consolidated income statement. At September 30, 2018 , the carrying value of our equity method investment in APLNG was $ 7,676 million. The balance is included in the “Investments and long-term receivables” line on our consolidated balance sheet. Distributions from APLNG commenced in April 2018. FCCL On May 17, 2017, we completed the sale of our 50 percent no noperated interest in the FCCL Partnership, as well as the majority of our western Canada gas assets, to Cenovus Energy. For additional information on the Canada disposition and our investment in Cenovus Energy, s ee Note 5 — Assets Held for Sale, Dispositions, Acquisitions and Other Planned Transactions and Note 7 — Investment in Cenovus Energy . Loans and Long-Term Receivables As part of our normal ongoing business operations, and consistent with industry practice, we enter int o numerous agree ments with other parties to pursue business opportunities. Included in such activity are loans made to certain affiliated and non-affiliated companies. At September 30, 2018 , significant loans to affiliated companies included $ 461 million in project fi nancing to Qatar Liquefied Gas Company Limited (3) (QG3). On our consolidated balance sheet, the long-term portion of these loans is included in the “Loans and advances—related parties” line, while the short-term portion is in the “Accounts and notes rece ivable—related parties” line.

Investment in Cenovus Energy

Investment in Cenovus Energy	9 Months Ended
	Sep. 30, 2018
Investment In Cenovus Energy [Abstract]
Investments in Debt and Marketable Equity Securities (and Certain Trading Assets) Disclosure [Text Block]	Note 7 -– Investment in Cenovus Energy On May 17, 2017, we completed the sale of our 50 percent nonoperated interest in the FCCL P artnership, as well as the majority of our western Canada gas assets , to Cenovus Energy. Con sideration for the transaction included 208 million Cenovus Energy common shares , which approximated 16.9 percent of issued and outstanding Cenovus Energy common stock at closing . See Note 5 — Assets Held for Sale, Dispositions, Acquisitions and Other Planned Transactions for additional information on the Canada disposition. At closing of the sale , 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 . We adopted the provisions of ASU No. 2016-01 , beginning January 1, 2018 , using the cumulative-effect approach. Results for reporting periods beginning J anuary 1, 2018 , are presented under ASU No. 2016-01 with all changes in the fair value of our equity securities reflected within the “Other i ncome ” line of our consolidated income statement and within the “Other” line in the “Cash Flows F rom Operating Activities” section of our consolidated statement of cash flows. Prior period amounts are not adjusted under the cumulative-effect method of adopting ASU No. 2016-01. See Note 2 — Change s in Accounting Principles and Note 16 — Accumulated Other Comprehensive Loss for the effect on our consolidated balance sheet and the line items that have been impacted by the adoption of this standard. The cumulative effect of applying the standard was the reclassification of accumulated unrealized holding losses of $ 58 million , recognized in 2017, related to our investment in Cenovus Energy from accumulated other comprehensive loss to retained earnings . Our investment is carried at fair value of $ 2. 09 billion as of September 30, 2018 , reflecting the closing price of Cenovus Energy shares on the New York Stock Exchange of $ 10. 03 per share , an increase from its fair value of $ 1 .9 0 billion at year-end 2017 . For the three- and nine- month periods ended September 30, 2018 , we recorded a before-tax unrealized loss of $ 73 million and a before-tax unrealized gain of $ 187 million, respectively, related to the shares held at the reporting dat e. See Note 15 —Fair Value Measurement , for additional information. Subject to market conditions, we intend to decrease our investment over time through market transactions, private agreements or otherwise .

Suspended Wells and Wells in Pr

Suspended Wells and Wells in Progress	9 Months Ended
	Sep. 30, 2018
Suspended Wells [Abstract]
Suspended Wells	Note 8 —Suspended Wells The capitalized cost of suspended wells at September 30, 2018 , was $ 986 million, an increase of $ 133 million from $ 853 million at year-end 2017 . Three suspended wells totaling $ 7 million were charged to dry hole expense during the first nine months of 2018 relating to exploratory well costs capitalized for a period greater than one year as of December 31, 2017 .

Impairments

Impairments	9 Months Ended
	Sep. 30, 2018
Impairment Of Long Lived Assets [Abstract]
Impairments	Note 9—Impairments During the three- and nine-month periods ended September 30, 2018 and 2017, we recognized before-tax impairment charges within the following segments: Millions of Dollars Three Months Ended Nine Months Ended September 30 September 30 2018 2017 2018 2017 Alaska $ - 1 - 178 Lower 48 44 3 55 3,888 Canada - - - 18 Europe and North Africa - 2 (48) 7 Asia Pacific and Middle East - - 14 2,384 $ 44 6 21 6,475 In the three-month period ended September 30, 2018 , impairments in our Lower 48 segment were primarily related to developed properties in our Barnett asset which were written down to fair value less costs to sell. In the nine-month period ended September 30, 2018, our Lower 48 segment included before-tax impairments of $ 55 million, primarily related to developed properties in our Barnett asset which were written down to fair value less costs to sell, partly offset by a revision to reflect finaliz ed proceeds on a separate transaction. In our Europe and North Africa segment, we recorded a credit to impairment of $ 49 million, primarily due to decreased ARO estimates on a certain field in the United Kingdom that has ceased production and was impaired in a prior year. For additional information related to the status of our Barnett asset, see Note 5 — Assets Held for Sale, Dispositions, Acquisitions and Other Planned Transactions . In the nine-month period ended September 30, 2017, our Lower 48 segment included before-tax impairments of $ 3.3 billion for our inte rests in the San Juan Basin and $ 0.6 billion for our interests in the Barnett asset, which were written down to fair value less costs to sell. See the “APLNG” section of Note 6 —Investments, Loans and Long-Term Receivables, for information on the impa irment of our APLNG investment included within the Asia Pacific and Middle East segment. Additionally, our Alaska segment included an impairment of $ 174 million for the associated carrying value of our small interest in the Point Thomson Unit. The charge discussed below is included in the “Exploration expenses” line on our consolidated income statement and is not reflected in the table above. In the nine-month period ended September 30, 201 7 , we recorded a before-tax impairment of $ 51 million in ou r Lower 48 segment 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.

Debt

Debt	9 Months Ended
	Sep. 30, 2018
Debt [Abstract]
Debt	Note 10 —Debt In May 2018, we refinanced our revolving credit facility from a total aggregate principal amount of $ 6.75 billion to $ 6.0 billion with a new expiration date of May 2023 . Our revolving credit facility may be used for direct bank borrowings, the issuance of letters of credit totaling up to $ 500 million, or as support for our commercial paper program. The revolving credit facility is broadly syndicated am ong financial instit utions and does not contain any material adverse change provisions or any covenants requiring maintenance of specified financial ratios or credit ratings. The facility agreement contains a cross-default provision relating to the failure to pay principal o r interest on other debt obligations of $ 200 million or more by ConocoPhillips, or any of its consolidated subsidiaries. Credit facility borrowings may bear interest at a margin above rates offered by certain designated banks in the London interbank marke t or at a margin above the overnight federal funds rate or prime rates offered by certain designated banks in the United States. The agreement calls for commitment fees on available, but unused, amounts. The agreement also contains early termination righ ts if our current directors or their approved successors cease to be a majority of our Board of Directors. The revolving credit facility supports the ConocoPhillips Company $ 6.0 billion commercial paper program which is primarily a funding s ource for short-term working capital needs. Commercial paper maturities are generally limited to 90 days. We had no commercial paper outstanding in programs in place at September 30, 2018 or December 31, 2017 . W e had no direct outstanding borrowings or letters of credit under the revolving credit facility a t September 30, 2018 and December 31, 2017 . Since we had no commercial paper outstanding and had issued no letters of credit, we had access to $ 6.0 billion in borrowing capacity under our revolving credit facility at September 30, 2018 . In the first quarter of 2018, we redeemed or repurchased a total of $2,650 million of debt as described below: 4.20% Notes due 2021 with remaining principal of $ 1.0 billion. 2.87 5% Notes due 2021 with principal of $ 750 million. 2.2% Notes due 2020 with principal of $ 500 million. 8.125% Notes due 2030 with principal of $600 million (partial repurchase of $210 million). 7.8% Notes due 2027 with principal of $300 million (partial rep urchase of $97 million). 7.9% Notes due 2047 with principal of $100 million (partial repurchase of $40 million). 9.125% Notes due 2021 with principal of $150 million (partial repurchase of $27 million). 8.20% Notes due 2025 with principal of $150 million (partial repurchase of $16 million). 7.65% Notes due 2023 with principal of $88 million (partial repurchase of $10 million). I n the second quarter of 2018, we repurchased a total of $ 1,800 million of debt as described below : 2.4% Notes due 2022 with principal of $1.0 billion (partial repurchase of $ 671 million). 3.35% Notes due 2024 with principal of $1.0 billion (partial repurchase of $ 574 million). 3.35% Notes due 2025 with principal of $500 million (partial repurchase of $ 301 million). 4.15% Notes due 2034 with principal of $500 million (partial repurchase of $ 254 million). During the first six months of 2018, we incurred net premiums above book value to redeem or repurchase these debt instruments of $ 208 million. In the second quarter of 2018, we also repaid the $ 250 million floating rate note due in 2018 at its natural maturity. At September 30, 2018 , 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	9 Months Ended
	Sep. 30, 2018
Noncontrolling Interests [Abstract]
Noncontrolling Interests	Note 11—Noncontrolling Interests Activity attributable to common stockholders’ equity and noncontrolling interests for the first nine months of 2018 and 2017 was as follows: Millions of Dollars 2018 2017 Common Stockholders’ Equity Non-Controlling Interest Total Equity Common Stockholders’ Equity Non-Controlling Interest Total Equity Balance at January 1 $ 30,607 194 30,801 34,974 252 35,226 Net income (loss) 4,389 38 4,427 (2,434) 43 (2,391) Dividends (1,009) - (1,009) (986) - (986) Repurchase of company common stock (2,073) - (2,073) (2,045) - (2,045) Distributions to noncontrolling interests - (105) (105) - (84) (84) Changes in Accounting Principles* (220) - (220) Other changes, net** 256 2 258 991 1 992 Balance at September 30 $ 31,950 129 32,079 30,500 212 30,712 *See Note 2—Changes in Accounting Principles for additional information related to ASC Topic 606. **Includes components of other comprehensive income, which are disclosed separately in our Consolidated Statement of Comprehensive Income.

Guarantees

Guarantees	9 Months Ended
	Sep. 30, 2018
Guarantees [Abstract]
Guarantees	Note 12 —Guarantees At September 30, 2018 , 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 September 30, 2018 , 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 September 2018 exchange rates: During the third quarter of 2016, we issued a guarantee to facilitate the withdrawal of our pro-rat a 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 $ 170 million and may become payabl e if an enforcement action is commenced by the project finance lenders against APLNG. At September 30, 2018 , the carrying value of this guarantee was approximately $ 14 million. For additional information, s ee Note 6 —Investments, Loans and Long-Term Receivables. 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 guarante es of an existing obligation of APLNG to deliver natural gas under several sales agreements with remaining terms of up to 24 years . Our maximum potential liability for future payments, or cost of volume delivery, under these guarantees is estimated to be $ 940 million ($ 1.58 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 mi tigated. 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 contribut ions 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 27 years or the life of the venture . Our maximum potential amount of future payments related to these guarantees is approximately $ 140 million and would become payable if APLNG does not perform. Other Guarantees We have other guarantees with maximum future potential payment amounts totaling approx imately $ 780 million, which consist primarily of guarantees of the residual value of leased office buildings, guarantees of the residual value of leased corporate aircraft, and a guarantee for our portion of a joint venture’s project finan ce reserve accounts. These guarantees have remaining terms of up to four 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 nonperforma nce 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, environmental 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 generally unlimited. The carrying amount recorded for these indemnifications at September 30, 2018 , was approximately $ 100 million. We amortize the indemnification liability over the rele vant time period, if one exists, based on the facts and circumstances surrounding each type of indemnity. In cases where the indemnification term is indefinite, we will reverse the liability when we have information the liability is essentially relieved o r amortize the liability over an appropriate time period as 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 possi ble to make a reasonable estimate of the maximum potential amount of future payments. Included in the recorded carrying amount at September 30, 2018 , were approximately $ 40 million of environmental accruals for known contamination that are included in the “Asset retirement obligations and accrued environmental costs” line on our consolidated balance sheet. For additional information about environmental liabilities, see Note 13 —Contingencies and Commitments. In 2012, we completed the separation of our downstream business, creating two independent energy companies: ConocoPhillips and Phillips 66. On March 1, 2015, a supplier to one of the refineries included in Phillips 66 as part of the separation of our downstream businesses formall y registered Phillips 66 as a party to the supply agreement, thereby triggering a guarantee we provided at the time of separation. As of December 31, 2017, the carrying value of this guarantee was $ 98 million. Because Phillips 66 has indemnified us for l osses incurred under this guarantee, we also recorded an indemnification asset from Phillips 66 of $ 98 million. During the third quarter of 2018, a termination agreement between the supplier and Phillips 66 was executed, releasing all parties from their respective obligations under the supply agreement. Since all obligations under the supply agreement were satisfied and discharged, the guarantee was terminated. As of September 30, 2018 , the carrying value of this guarantee and the associated indemnifica tion asset were removed .

Contingencies and Commitments

Contingencies and Commitments	9 Months Ended
	Sep. 30, 2018
Contingencies and Commitments [Abstract]
Contingencies and Commitments	Note 13 —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 and 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 such factors as the uncertain magnitude of cleanup costs, the unknown time and extent of such remedial actions that may be required, and the determination of our liability in proportion to that of other responsible parties. 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 a nd 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 accru als 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 September 30, 2018 , our balance sheet included a total environmental accrual of $ 170 million, compared with $ 180 million at December 31, 2017 , 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 wi ll continue 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 t he 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 professional 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 o f existing 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 September 30, 2018 , we had performance obligations secured by letters of credit of $ 275 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, ConocoPhillips was unable to reach agreement with respect to the empresa mixta structure mandated by the Venezuelan government’s Nationalization Decree. As a result, Venezuela’s national oil company, PDVSA, or its affiliates, directly assumed control over ConocoPhillips’ interests in the Petrozuata and Hamaca heavy oil ventures and the offshore Coroc oro development project. In response to this expropriation, ConocoPhillips initiated international arbitration on November 2, 2007, with the World Bank’s International Centre for Settlement of Investment Disputes (ICSID). On September 3, 2013, an ICSID a rbitration 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 curr ently proceeding to determine the damages owed to ConocoPhillips for Venezuela’s actions. In 2014, ConocoPhillips filed a separate and independent arbitration under the rules of the International Chamber of Commerce (ICC) against PDVSA under the contrac ts that had established the Petrozuata and Hamaca projects. The ICC Tribunal issued an award in April 2018, finding that PDVSA owed ConocoPhillips approximately $ 2 billion under their agreements in connection with the expropriation of t he projects and other pre-expropriation fiscal measures. In August 2018, ConocoPhillips entered into a settlement with PDVSA to recover the full amount of this ICC award, plus interest through the payment period, including initial payments totaling approx imately $ 500 million within a period of 90 days from the time of signing of the settlement agreement . The balance of the settlement is to be paid quarterly over a period of four and a half years. PDVSA also recognized the ICC award as a j udgment in various jurisdictions. During the third quarter of 2018, we collected from PDVSA under the settlement and recognized in other income $ 345 million consisting of $ 242 million in commodity inventory and $ 103 million in cash. The remainder of the initial payments is due in the fourth quarter of 2018. As of the end of October 2018, substantially all of the inventory recognized during the quarter has been sold. Per the settlement, ConocoPhillips agreed to susp end its legal enforcement actions of the ICC a ward, including in the Dutch Caribbean. ConocoPhillips has ensured that the settlement meets all appropriate U.S. regulatory requirements, including any applicable sanctions imposed by the U.S. against Venezue la. In 2016, ConocoPhillips filed a separate and independent arbitration under the rules of the ICC against PDVSA under the contracts that had established the Corocoro project. This ICC arbitration is currently in progress. In February 2017, an ICSID tr ibunal unanimously awarded Burlington Resources, Inc., a wholly owned subsidiary of ConocoPhillips, $ 380 million for Ecuador’s unlawful expropriation of Burlington’s investment in Blocks 7 and 21, in breach of the U.S.-Ecuador Bilateral Inves tment Treaty. The tribunal also issued a separate decision finding Ecuador to be entitled to $ 42 million for environmental and infrastructure counterclaims. In December 2017, Burlington and Ecuador entered into a settlement agreement by which Ecuador paid Burlington $ 337 million in two installments. The first installment of $ 75 million was paid in December 2017, and the second installment of $ 262 million was paid in April 2018. The settlement included an offset for the counterclaims decision, of which Burlington is entitled to a $ 24 million contribution from Perenco Ecuador Limited, its co-venturer and consortium operator, pursuant to a joint and several liabili ty provision in the joint operating agreement (JOA). Ecuador’s environmental and infrastructure counterclaims against Perenco remain pending in a separate ICSID arbitration between Perenco and Ecuador, and Burlington may owe Perenco contribution under the JOA for damages found by this tribunal . In December 2016, ConocoPhillips Angola filed a notice of arbitration against Sonangol E.P. under the Block 36 Production Sharing Contract relating to disputes arising thereunder. Earlier this year, the parties reached a confidential settlement. In June 2017, FAR Ltd. initiated arbitration before the ICC against ConocoPhillips Senegal B.V. in connection with the sale of ConocoPhillips Senegal B.V. to Woodside Energy Ho ldings (Senegal) Limited in 2016. This arbitration is ongoing . In 2017 and 2018, cities, counties, and/or state governments in California, New York, Washington, Rhode Island and Maryland have filed lawsuits against oil and gas companies, including Conoco Phillips, seeking compensatory damages and equitable relief to abate alleged climate change impacts. ConocoPhillips is vigorously defending against these lawsuits . The lawsuits brought by the Cities of San Francisco, Oakland and New York have been dismis sed by the district courts and appeals are pending.

Derivative and Financial Instru

Derivative and Financial Instruments	9 Months Ended
	Sep. 30, 2018
Derivative and Financial Instruments [Abstract]
Derivative and Financial Instruments	Note 14 —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 related to contracts that meet and are design ated with the normal purchase normal sale (NPNS) 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 September 30 December 31 2018 2017 Assets Prepaid expenses and other current assets $ 259 275 Other assets 42 36 Liabilities Other accruals 278 282 Other liabilities and deferred credits 37 28 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 Nine Months Ended September 30 September 30 2018 2017 2018 2017 Sales and other operating revenues $ (29) 17 (6) 120 Other income 3 (1) 12 (1) Purchased commodities 18 (19) 15 (88) The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts: Open Position Long/(Short) September 30 December 31 2018 2017 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (19) (29) Basis 5 12 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, and investments in equity securities. We do not elect hedge accounting on our foreign currency exchange 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 September 30 December 31 2018 2017 Assets Prepaid expenses and other current assets $ 18 1 Other assets - 6 Liabilities Other accruals 7 - Other liabilities and deferred credits - 15 In December 2017, we entered into foreign exchange zero cost collars buying the right to sell $1.25 billion CAD at $0.707 CAD and selling the right to buy $1.25 billion CAD at $0.842 CAD against the U.S. dollar. 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 Nine Months Ended September 30 September 30 2018 2017 2018 2017 Foreign currency transaction (gains) losses $ (2) (1) (5) 2 We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency September 30 December 31 2018 2017 Foreign Currency Exchange Derivatives Sell U.S. dollar, buy other currencies* USD 1,258 - Sell British pound, buy euro GBP 23 1 Sell Canadian dollar, buy U.S. dollar CAD 1,230 1,225 *Primarily British pound. 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 we currently invest in 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 purchased at a discount to mature at par. These financial instruments appear in the “Cash and cash equivalents” line of our consolidated 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 September 30 December 31 September 30 December 31 2018 2017 2018 2017 Cash $ 511 948 Time deposits Remaining maturities from 1 to 90 days 2,966 5,004 104 821 Commercial paper Remaining maturities from 1 to 90 days 239 373 771 978 Remaining maturities from 91 to 180 days - - - 74 $ 3,716 6,325 875 1,873 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, government 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 fo rwards, swaps and options, 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 significan t nonperformance. We 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 those 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 natio nal and international 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 counterparti es. We do not generally 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 fixed 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 am ounts typically revert 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 Exch ange. The aggregate fair value of all derivative instruments with such credit risk-related contingent features that were in a liability position on September 30, 2018 and December 31, 2017 , was $ 44 million and $ 55 mill ion, respectively. For these instruments , no collateral was posted as of September 30, 2018 or December 31, 2017 . If our credit rating had been downgraded below investment grade on September 30, 2018 , we would be required to post $ 44 million of additional collateral, either with cash or letters of credit.

Fair Value Measurement

Fair Value Measurement	9 Months Ended
	Sep. 30, 2018
Fair Value Measurement [Abstract]
Fair Value Measurement	Note 15 —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 sub sequently reported as Level 3 if corroborated market data is no longer available. Transfers occur at the end of the reporting period. At the end of the fourth quarter of 2017, our investment in Cenovus Energy transferred from Level 2 to Level 1 due to th e lapsing of trading restrictions. There were no other material transfers between levels during 2018 or 2017 . Recurring Fair Value Measurement Financial assets and liabilities reported at fair value on a recurring basis primaril y include our investment in Cenovus Energy shares and commodity derivatives. Level 1 derivative assets and liabilities primarily represent exchange-traded futures and options that are valued using unadjusted prices available from the underlying exchange. Level 1 also includes our investment in common shares of Cenovus Energy, which is valued using quotes for shares on the New York Stock Exchange. Level 2 derivative assets and liab ilities 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. Level 3 derivative ass ets 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 readily available. The derived value uses industry standard methodolo gies 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 va lue on a recurring basis): Millions of Dollars September 30, 2018 December 31, 2017 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ 2,086 - - 2,086 1,899 - - 1,899 Commodity derivatives 186 97 18 301 175 106 30 311 Total assets $ 2,272 97 18 2,387 2,074 106 30 2,210 Liabilities Commodity derivatives $ 176 103 36 315 158 111 41 310 Total liabilities $ 176 103 36 315 158 111 41 310 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 September 30, 2018 Assets $ 301 206 95 - 7 88 Liabilities 315 206 109 2 3 104 December 31, 2017 Assets $ 311 186 125 - 4 121 Liabilities 310 186 124 7 5 112 At September 30, 2018 and December 31, 2017, 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 Net PP&E (held for sale) March 31, 2018 $ 250 - 250 44 September 30, 2018 $ 201 201 - 43 During the first and third quarters of 2018, certain net PP&E held for sale was written down to fair value, less costs to sell. In the third quarter, fair value was determined by its negotiated selling price. In the first quarter , f air value was estimated using information gathered during marketing efforts. For additional information, see Note 5 — Assets Held for Sale, Dispositions, Acquisitions and Other Planned Transactions . 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 7 —Investment in Cenovus Energy, for a discussion of the carrying value and fair value of our investment in C enovus 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 va lue hierarchy. See Note 6 —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 ba lance 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 th e 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 September 30 December 31 September 30 December 31 2018 2017 2018 2017 Financial assets Investment in Cenovus Energy $ 2,086 1,899 2,086 1,899 Commodity derivatives 95 125 95 125 Total loans and advances—related parties 464 586 464 586 Financial liabilities Total debt, excluding capital leases 14,201 18,929 16,554 22,435 Commodity derivatives 107 117 107 117

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	9 Months Ended
	Sep. 30, 2018
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Income	Note 16—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 Income (Loss) December 31, 2017 $ (400) (58) (5,060) (5,518) Cumulative effect of adopting ASU No. 2016-01* - 58 - 58 Other comprehensive income (loss) 240 - (222) 18 September 30, 2018 $ (160) - (5,282) (5,442) *See Note 2—Changes in Accounting Principles for additional information. 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 Nine Months Ended September 30 September 30 2018 2017 2018 2017 Defined benefit plans $ 17 26 155 116 The above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of $6 million and $14 million for the three months ended September 30, 2018 and September 30, 2017, respectively, and $43 million and $61 million for the nine-month periods ended September 30, 2018 and September 30, 2017, respectively. See Note 18—Employee Benefit Plans, for additional information.

Cash Flow Information

Cash Flow Information	9 Months Ended
	Sep. 30, 2018
Cash Flow Information [Abstract]
Cash Flow Information	Note 17 —Cash Flow Information Millions of Dollars Nine Months Ended September 30 2018 2017 Cash Payments Interest $ 584 918 Income taxes 1,927 574 Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ (1,705) (4,999) Short-term investments sold 2,701 2,416 $ 996 (2,583) The following items are included in the “Cash Flows From Operating Activities” section of our consolidated statement of cash flows : In the second quarter of 2018, we received a settlement payment of $ 262 million from the Republic of Ecuador. In the third quarter of 2018, we received a settlement payment of $103 million from PDVSA. For more information see Note 13—Contingencies and Commitments. In the first quarter of 2017, we recognized a $ 180 million adverse cash impact from the settlement of cro ss-currency swap transactions.

Employee Benefit Plans

Employee Benefit Plans	9 Months Ended
	Sep. 30, 2018
Employee Benefit Plans [Abstract]
Employee Benefit Plans	Note 18 — Employee Benefit Plans Pension and Postretirement Plans Millions of Dollars Pension Benefits Other Benefits 2018 2017 2018 2017 U.S. Int'l. U.S. Int'l. Components of Net Periodic Benefit Cost Three Months Ended September 30 Service cost $ 20 20 21 20 - - Interest cost 22 26 29 27 2 3 Expected return on plan assets (22) (38) (32) (41) - - Amortization of prior service cost (credit) - (1) 1 (1) (9) (9) Recognized net actuarial loss (gain) 10 9 17 12 - (1) Settlements 14 - 21 - - - Curtailments - (1) - - - - Net periodic benefit cost $ 44 15 57 17 (7) (7) Nine Months Ended September 30 Service cost $ 63 63 67 59 1 1 Interest cost 76 80 90 78 6 7 Expected return on plan assets (91) (118) (97) (119) - - Amortization of prior service cost (credit) - (4) 3 (4) (26) (27) Recognized net actuarial loss (gain) 41 27 53 36 (1) (2) Settlements 161 - 118 - - - Curtailments - (1) - - - - Net periodic benefit cost $ 250 47 234 50 (20) (21) The components of net periodic benefit cost, other than the service cost component, are included in the “Other expenses” line item on our consolidated income statement. During the first nine months of 2018 , we contributed $ 150 million to our domestic benefit plans and $ 130 million to our international benefit plans. In 2018 , we expect to contribute approximately $ 160 million to our domestic qualified and nonqualified pension and postretirement bene fit plans and $ 160 million to our international qualified and nonqualified pension and postretirement benefit plans. In June 2018 , we purchased a group annuity contract from Prudential and transferred approximately $ 700 million of future benefit obligations from the U.S. qualified pension plan to Prudential. The purchase of the group annuity contract was funded directly by plan assets of the U.S. qualified pension plan. We recognized a proportionate share of prior ac tuarial losses from other comprehensive income as pension settlement expense of $ 14 million and $ 161 million during the three- and nine- month periods ended September 30, 2018 , respectively. In conjunction with the recognition of pension s ettlement expense, the fair market values of the U.S. qualified pension plan assets were updated, and the pension benefit obligation of the U.S. qualified pension plan was remeasured as of June 30, 2018. At the measurement date, the net pension liability increased by $ 42 million as a result of a loss on U.S. qualified pension plan assets, offset by a gain on the projected benefit obligation due primarily to an increase in the discount rate from 3.6 percent to 4.2 percent, resulting in a corresponding decrease to other comprehensive income. During the three-month period ended September 30, 2018 , the fair market value of certain international pension plan assets was updated, and the pension benefit obligatio ns associated with these plans were remeasured. At the measurement.date, the net pension liability decreased by $ 157 million with a corresponding increase to other comprehensive income primarily as a result of an increase in discount r ate from 2.55 percent at December 31, 2017 , to 2.95 percent at September 30, 2018 . The reduction in net pension liability resulted in a balance of $ 146 million associated with an international qualified p lan being reclassified to the “Other assets” line on our consolidated balance sheet. Severance Accrual As a result of staff reductions occurring throughout the year, severance accruals of $ 35 million and $ 65 million wer e recorded during the three- and nine- month periods ended September 30, 2018 , respectively . The following table summarizes our severance accrual activity for the nine -month period ended September 30, 2018 : Millions of Dollars Balance at December 31, 2017 $ 53 Accruals 65 Benefit payments (38) Balance at September 30, 2018 $ 80 Of the remaining balance at September 30, 2018 , $ 55 million is classified as short term.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2018
Related Party Transactions [Abstract]
Related Party Transactions	Note 19—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 Nine Months Ended September 30 September 30 2018 2017 2018 2017 Operating revenues and other income $ 27 24 74 83 Purchases 25 26 74 74 Operating expenses and selling, general and administrative expenses 13 16 44 42 Net interest (income) expense* (4) (4) (11) (10) *We paid interest to, or received interest from, various affiliates. See Note 6—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Sales and Other Operating Reven

Sales and Other Operating Revenues	9 Months Ended
	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer [Text Block]	Note 21 —Sales and Other Operating Revenues Transitional Arrangements We adopted the provisions of ASC Topic 606 beginning January 1, 2018, using the modified retrospective approach, which we have applied to contracts within the scope of the standard that had not been completed as of January 1, 2018. Results for reporting periods beginning after January 1, 2018, are presented under ASC Topic 606, while prior period amounts are not adjusted and continue to be reported in accordance with ASC Topic 605. See N ote 2 —Change s in Accounting Principles for the effect on our consolidated balance sheet and the line items which have been impacted by the adoption of this standard. The cumulative effect of applying the standard relates solely to certain lice nsing arrangements where revenue was previously recognized ($ 61 million in 2011, $ 146 million in 2015 , and $ 44 million in 2017) based on contractual milestones. Under ASC Topic 606, such revenues are recognized when the customer has the ability to utilize and benefit from its right to use the license. As a result, such historically recognized revenues must be reversed through a cumulative effect adjustment and deferred until such time when the customer has the ability to utilize and benefit from the licens e. The cumulative effect adjustment relates to contracts that were not substantially completed at the date of implementation. Accounting Policy Revenues associated with the sales of crude oil, bitumen, natural gas, LNG, natural gas liquids and other items are recognized at the point in time when the customer obtains control of the asset. In evaluating when a customer has control of the asset , we primarily consider whether the transfer of legal title and physical delivery has occurred, whether the cus tomer has significant risks and rewards of ownership, and whether the customer has accepted delivery and a right to payment exists. These products are typically sol d at prevailing market prices. We allocate variable market-based consideration to deliveri es (performance obligations) in the current period as that consideration relates specifically to our efforts to transfer control of current period deliveries to the customer and represents the amount we expect to be entitled to in exchange for the related products. Payment is typically due within 30 days or less. Practical Expedients Typically, our commodity sales contracts are less than 12 months in duration; however, certain commodity sales contracts may carry a longer duration, which may extend to t he end of field life. We have long-term commodity sales contracts which use prevailing market prices at the time of delivery , and u nder these contracts, the market-based variable consideration for each performance obligation (i.e. , delivery of commodity) is allocated to each wholly unsatisfied performance obligation within the contract. Accordingly, we have applied the practical expedient allowed in ASC Topic 606 and do not disclose the aggregate amount of the transaction price allocated to performance ob ligations or when we expect to recognize revenues that are unsatisfied (or partially unsatisfied) as of the end of the reporting period. Revenue from Contracts with Customers The following table provides further disaggregation of our consolidated sales and other operating revenues : Millions of Dollars Three Months Ended Nine Months Ended September 30 September 30 2018 2017 * 2018 2017 * Revenue from contracts with customers $ 7,546 4,636 20,834 14,428 Revenue from contracts outside the scope of ASC Topic 606 Physical contracts meeting the definition of a derivative 1,897 2,050 5,877 6,631 Financial derivative contracts 6 2 40 (72) Consolidated sales and other operating revenues $ 9,449 6,688 26,751 20,987 *Under the modified retrospective approach, prior period amounts have not been adjusted upon adoption of ASC Topic 606. Revenues from contracts outside the scope of ASC Topic 606 relate primarily to physical gas contracts at market prices which qualify as derivatives accounted for under ASC Topic 815, “Derivatives and Hedging, ” and for which we have not elected NPNS . There is no significant difference in contractual terms or the policy for recognition of revenue from these contracts and those within the scope of ASC Topic 606. The following disaggregation of revenues is provided in conjunction with Note 21 — Seg ment Disclosures and Related Information : Millions of Dollars Three Months Ended Nine Months Ended September 30 September 30 2018 2017 * 2018 2017 * Revenue from Outside the Scope of ASC Topic 606 by Segment Lower 48 $ 1,534 1,563 4,547 4,834 Canada 87 161 374 680 Europe and North Africa 276 326 956 1,117 Physical contracts meeting the definition of a derivative $ 1,897 2,050 5,877 6,631 *Under the modified retrospective approach, prior period amounts have not been adjusted upon adoption of ASC Topic 606. Millions of Dollars Three Months Ended Nine Months Ended September 30 September 30 2018 2017 * 2018 2017 * Revenue from Outside the Scope of ASC Topic 606 by Product Crude oil $ 267 171 843 530 Natural gas 1,522 1,811 4,775 5,870 Other 108 68 259 231 Physical contracts meeting the definition of a derivative $ 1,897 2,050 5,877 6,631 *Under the modified retrospective approach, prior period amounts have not been adjusted upon adoption of ASC Topic 606. Receivables and Contract Liabilities Receivables from Contracts with Customers At September 30, 2018 , the “ Accounts and n otes receivable ” line on our consolidated balance sheet included trade receivables of $ 3,129 million compared with $ 2,675 million at December 31, 2017, and included both contracts with customers within the scope of ASC Topic 606 and those that are outside the scope of ASC Topic 606. We typically receive payment within 30 days or less (depending on the terms of the invoice) once deliver y is made . Revenues that are outside the scope of ASC Topic 606 relate primarily to physical gas sales contracts at market prices for which we do not elect NPNS and are therefore accounted for as a derivative under ASC Topic 815. There is little distinct ion in the nature of the customer or credit quality of trade receivables associated with gas sold under contracts for which NPNS has not been elected compared with trade receivables where NP NS has been elected. Contract Liabilities from Contracts with Customers We have entered into contractual arrangements where we license proprietary technology to customers related to the optimization process for operating LNG plants. The agreements typically provide for negotiated payments to be made at stated milest ones. The payments are not directly related to our performance under the contract and are recorded as deferred revenue to be recognized as revenue when the customer can utilize and benefit from their right to use the license. Payments are received in ins tal l ments over the construction period. Millions of Dollars Contract Liabilities At January 1, 2018 $ 251 Contractual payments received* 81 Revenue recognized (148) At September 30, 2018 $ 184 Amounts Recognized in the Consolidated Balance Sheet at September 30, 2018 Current liabilities $ 147 Noncurrent liabilities 37 $ 184 *Includes $14 million and $81 million for the three- and nine-month periods of 2018, respectively. For the three- and nine-month periods of 2018, we recognized revenue of $ 73 million and $148 million, respectively, in the “Sales and other operating revenues” line on our consolidated income statement. We expect to recognize the contract liabilities as of September 30, 2018, as revenue between the remainder of 2018 and 2022 as construction is complete d. Prior to the adoption of ASC Topic 606, contractual cash payments received would have been recognized as “S ales and o ther o perating r evenues ” when recei ved.

Segment Disclosures and Related

Segment Disclosures and Related Information	9 Months Ended
	Sep. 30, 2018
Segment Disclosures and Related Information [Abstract]
Segment Disclosures and Related Information	Note 21 —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 operati ng segment, such as most interest expense, corporate overhead and certain technology activities, including licensing revenues. Corporate assets include all cash and cash equivalents and short-term investments. We evaluate performance and allocate resou rces 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 Nine Months Ended September 30 September 30 2018 2017 * 2018 2017 * Sales and Other Operating Revenues Alaska $ 1,493 932 4,281 3,010 Lower 48 4,543 3,102 12,347 9,422 Intersegment eliminations (14) (2) (18) (7) Lower 48 4,529 3,100 12,329 9,415 Canada 735 699 2,436 2,357 Intersegment eliminations (308) (155) (853) (330) Canada 427 544 1,583 2,027 Europe and North Africa 1,574 1,110 4,826 3,564 Asia Pacific and Middle East 1,348 959 3,570 2,877 Corporate and Other 78 43 162 94 Consolidated sales and other operating revenues $ 9,449 6,688 26,751 20,987 Sales and Other Operating Revenues by Geographic Location United States $ 6,025 4,038 16,617 12,440 Australia 515 323 1,258 1,050 Canada 427 544 1,583 2,027 China 262 148 616 511 Indonesia 234 191 662 554 Libya** 264 91 802 315 Malaysia 339 297 1,039 768 Norway 734 583 2,112 1,751 United Kingdom 574 437 1,911 1,498 Other foreign countries 75 36 151 73 Worldwide consolidated $ 9,449 6,688 26,751 20,987 Sales and Other Operating Revenues by Product Crude Oil $ 5,277 2,947 14,503 9,387 Natural gas 2,503 2,496 7,593 7,949 Natural gas liquids 351 238 847 745 Other*** 1,318 1,007 3,808 2,906 Consolidated sales and other operating revenues by product $ 9,449 6,688 26,751 20,987 *Under the modified retrospective approach, prior period amounts have not been adjusted upon adoption of ASC Topic 606. **Included in "Other foreign countries" in prior periods. ***Includes LNG and bitumen. Net Income (Loss) Attributable to ConocoPhillips Alaska $ 427 103 1,369 291 Lower 48 513 (97) 1,231 (2,995) Canada 34 280 2 2,607 Europe and North Africa 241 85 776 379 Asia Pacific and Middle East 577 396 1,504 (1,540) Other International 316 (20) 267 (77) Corporate and Other (247) (327) (760) (1,099) Consolidated net income (loss) attributable to ConocoPhillips $ 1,861 420 4,389 (2,434) Millions of Dollars September 30 December 31 2018 2017 Total Assets Alaska $ 12,688 12,108 Lower 48 15,308 14,632 Canada 5,950 6,214 Europe and North Africa 11,895 11,870 Asia Pacific and Middle East 16,611 16,985 Other International 315 97 Corporate and Other 7,789 11,456 Consolidated total assets $ 70,556 73,362

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2018
Income Taxes [Abstract]
Income Taxes	Note 22 —Income Taxes Our effective tax rates for the three- and nine- month periods ended September 30, 2018 , were 36 percent and 39 percent, respectively, compared with 33 percent and 3 9 percent for the same periods of 2017 . The amounts of U.S. and foreign income (loss) 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 Nine Months Ended Three Months Ended Nine Months Ended September 30 September 30 September 30 September 30 2018 2017 2018 2017 2018 2017 2018 2017 Income (loss) before income taxes United States $ 893 (197) 2,799 (5,259) 30.7 % (30.2) 38.3 133.5 Foreign 2,013 850 4,502 1,319 69.3 130.2 61.7 (33.5) $ 2,906 653 7,301 (3,940) 100.0 % 100.0 100.0 100.0 Federal statutory income tax $ 610 228 1,533 (1,379) 21.0 % 35.0 21.0 35.0 Non-U.S. effective tax rates 479 137 1,339 503 16.5 21.0 18.3 (12.8) Canada disposition - (8) - (1,176) - (1.2) - 29.8 Recovery of outside basis (16) (118) (19) (957) (0.6) (18.1) (0.2) 24.3 Adjustment to tax reserves (3) (17) 2 764 (0.1) (2.6) - (19.4) Adjustment to valuation allowance (29) - 13 24 (1.0) - 0.2 (0.6) APLNG impairment - - - 834 - - - (21.2) State income tax 38 14 83 (98) 1.3 2.1 1.1 2.5 Enhanced oil recovery credit (36) (5) (73) (49) (1.3) (0.8) (1.0) 1.2 Other (10) (14) (4) (15) (0.3) (2.2) - 0.5 $ 1,033 217 2,874 (1,549) 35.5 % 33.2 39.4 39.3 The effective tax rate represents a blend of federal, state and foreign taxes and includes the impact of certain nondeductible items and adjustments to our valuation allowance. The effective tax rate for the three- and nine-month periods ended September 30, 2018 , also reflects the reduced federal corporate income tax rate as a result of the enactment of the Tax Cuts and Jobs Act (the Tax Legislation) in December 2017 and the impact of a change in the mix of our domestic and foreign earnings. In the third quarter of 2018, we recognized $ 53 million of U.S. Federal tax benefit related to previously unrecognized deferred tax assets associated with the income from the PDVSA settlement agreement. This benefit is included in the “Adjustment to Valuation Allowan ce” and “Recovery of Outside Basis” lines of the table above. Any future amounts received under the PDVSA settlement should result in nominal U.S. income tax implications due to the availability of unrecognized U.S. tax attributes to offset the receipts. For additional information, see Note 13 — Contingencies and Commitments. Our effective tax rate for the three- and nine-month periods ended September 30, 2017, was favorably impacted by a tax benefit of $ 114 million related to our prior decision to exit Nova Scotia deepwater exploration. This benefit is included in the “Recovery of Outside Tax Basis” line of the table above. Our effective tax rate for the nine- month period ended September 30 , 2017 , was also favorably impacted by a tax benefit of $ 1,1 76 million, associated with our 2017 disposition of various assets in Canada. This tax benefit was primarily associated with a deferred tax recovery related to the Canadian capital gains exclusion component of the 2017 Canada disposition and the recogni tion of previously unrealizable Canadian capital asset tax basis. The Canada disposition, along with the associated restructuring of our Canadian operations, may generate an additional tax benefit of $ 822 million. However, since we believe it is not like ly we will receive a corresponding cash tax savings, this $ 822 million benefit has been offset by a full tax reserve . The impairment of our APLNG investment in the second quarter of 2017 did not generate a tax benefit. See the “APLNG” section of Note 6 — Investments, Loans and Long-Term Receivables , for information on the impairment of our APLNG investment. We have not significantly revised the tax accounting impacts of our 2017 provisional estimates under Staff Accounting Bulletin 118 and ASU No. 2018-0 5, “Income Taxes” (Topic 740), but we are continuing to gather information and are waiting for further guidance from the Internal Revenue Service, Securities Exchange Commission and FASB on the Tax Legislation. The Tax Legislation subjects a U.S. sharehol der to tax on Global Intangible Low-Taxed Income (GILTI) earned by certain foreign subsidiaries. The FASB Staff Q&A, Topic 740, No. 5, “ Accounting for Global Intangible Low-Taxed Income ,” states that an entity can make an accounting policy election to eit her recognize deferred taxes for temporary basis differences expected to reverse as GILTI in future years or provide for the tax expense related to GILTI in the year the tax is incurred as a period expense only. Given the complexity , we are still evaluating the effects of the GILTI provisions and have not yet determined our accounting policy. At September 30, 2018, the current-year U.S. income tax impact related to GILTI activities is immaterial.

New Accounting Standards

New Accounting Standards	9 Months Ended
	Sep. 30, 2018
New Accounting Standards [Abstract]
Description of New Accounting Pronouncements Not yet Adopted [Text Block]	Note 23 — New Accounting Standards 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” (FASB ASC Topic 840), 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 leas e and outline requirements for recognition, measurement, presentation and disclosure of leasing arrangements by both lessees and lessors. The ASU is effective for interim and annual periods beginning after December 15, 2018, and early adoption of the stan dard 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. ASU No. 2016-02 was amended in January 2018 by the provisions of ASU No. 2018-01, “Land Easement Practical Expedient for Transition to Topic 842” (ASU No. 2018-01), and in July 2018 by t he provisions of ASU No. 2018-10, “Codification Improvements to Topic 842, Leases” (ASU No. 2018-10). In addition, the FASB issued ASU No. 2018-11, “Targeted Improvements” (ASU No. 2018-11), in July 2018 to set forth certain additional practical expedient s for lessors and to provide entities with an option to apply the provisions of ASU No. 2016-02, as amended, to leasing arrangements existing at or entered into after the ASU’s effective date of adoption (the “Optional Transition Method”). Entities that e lect to utilize the Optional Transition Method would not apply the provisions of ASU No. 2016-02, as amended, to comparative periods presented in the financial statements. We plan to adopt ASU No. 2016-02, as amended, effective January 1, 2019, utilizin g the Optional Transition Method. Accordingly, the comparative periods presented in the financial statements prior to January 1, 2019, will be presented pursuant to the existing requirements of FASB ASC Topic 840 and not be adjusted upon the adoption of th e ASU. We continue to evaluate the ASU to determine the impact of adoption on our consolidated financial statements and disclosures, accounting policies and systems, business processes, and internal controls. We are currently implementing a third-party l ease accounting software solution to facilitate the ongoing accounting and financial reporting requirements of the ASU. We also continue to monitor proposals issued by the FASB to clarify the ASU and certain industry implementation issues. While our ev aluation of ASU No. 2016-02 and related implementation activities are ongoing, we expect the adoption of the ASU to have a material impact to our consolidated financial statements. Such impact is expected to relate primarily to our balance sheet, resultin g from the initial recognition of lease liabilities and corresponding right-of-use assets for our population of operating leases, as well as enhanced disclosure of our leasing arrangements. We also expect the adoption of ASU No. 2016-02 to result in certa in changes being made to our existing accounting policies and systems, business processes, and internal controls. 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 impairment 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, a nd early adoption of the standard is permitted. Entities are required 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	9 Months Ended
	Sep. 30, 2018
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 ConocoPh illips 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 obligations 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 securiti es. 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 Com pany 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 bas is. In March 2018, ConocoPhillips Company received a $ 1.2 billion loan repayment from a nonguarantor subsidiary to settle certain accumulated intercompany balances. This transaction had no impact on our consolidated financial statements. In June 2018, C onocoPhillips received a $ 2.5 billion return of capital from ConocoPhillips Company to settle certain accumulated intercompany balances. The transaction had no impact on our consolidated financial statements. In the second quarter of 2018, ConocoPhillips Company received $ 1.2 billion of loan repayments from a nonguarantor subsidiary to settle certain accumulated intercompany balances. This transaction had no impact on our consolidated financial statements. This condensed consolidating financial informat ion should be read in conjunction with the accompanying consolidated financial statements and notes. Millions of Dollars Three Months Ended September 30, 2018 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 $ - 4,330 - 5,119 - 9,449 Equity in earnings of affiliates 1,903 2,166 - 256 (4,031) 294 Gain on dispositions - 75 - 38 - 113 Other income - (61) - 370 - 309 Intercompany revenues 9 34 42 1,619 (1,704) - Total Revenues and Other Income 1,912 6,544 42 7,402 (5,735) 10,165 Costs and Expenses Purchased commodities - 3,880 - 1,196 (1,546) 3,530 Production and operating expenses - 298 - 1,085 (16) 1,367 Selling, general and administrative expenses 2 99 - 18 - 119 Exploration expenses - 41 - 62 - 103 Depreciation, depletion and amortization - 152 - 1,342 - 1,494 Impairments - 1 - 43 - 44 Taxes other than income taxes - 33 - 279 - 312 Accretion on discounted liabilities - 4 - 85 - 89 Interest and debt expense 72 156 37 63 (142) 186 Foreign currency transaction (gains) losses (12) 3 42 (28) - 5 Other expenses - 6 - 4 - 10 Total Costs and Expenses 62 4,673 79 4,149 (1,704) 7,259 Income (Loss) before income taxes 1,850 1,871 (37) 3,253 (4,031) 2,906 Income tax provision (benefit) (11) (32) 1 1,075 - 1,033 Net income (loss) 1,861 1,903 (38) 2,178 (4,031) 1,873 Less: net income attributable to noncontrolling interests - - - (12) - (12) Net Income (Loss) Attributable to ConocoPhillips $ 1,861 1,903 (38) 2,166 (4,031) 1,861 Comprehensive Income Attributable to ConocoPhillips $ 2,056 2,098 5 2,330 (4,433) 2,056 Income Statement Three Months Ended September 30, 2017* Revenues and Other Income Sales and other operating revenues $ - 2,997 - 3,691 - 6,688 Equity in earnings of affiliates 486 348 - 119 (757) 196 Gain (Loss) on dispositions - 879 - (633) - 246 Other income - 12 - 53 - 65 Intercompany revenues 10 77 43 774 (904) - Total Revenues and Other Income 496 4,313 43 4,004 (1,661) 7,195 Costs and Expenses Purchased commodities - 2,666 - 1,001 (741) 2,926 Production and operating expenses - 216 - 1,007 (1) 1,222 Selling, general and administrative expenses 2 97 - 11 - 110 Exploration expenses - 29 - 44 - 73 Depreciation, depletion and amortization - 203 - 1,405 - 1,608 Impairments - 1 - 5 - 6 Taxes other than income taxes - 29 - 146 - 175 Accretion on discounted liabilities - 8 - 81 - 89 Interest and debt expense 86 169 37 121 (162) 251 Foreign currency transaction (gains) losses (27) 1 77 (46) - 5 Other expenses 50 29 - (2) - 77 Total Costs and Expenses 111 3,448 114 3,773 (904) 6,542 Income (Loss) before income taxes 385 865 (71) 231 (757) 653 Income tax provision (benefit) (35) 379 6 (133) - 217 Net income (loss) 420 486 (77) 364 (757) 436 Less: net income attributable to noncontrolling interests - - - (16) - (16) Net Income (Loss) Attributable to ConocoPhillips $ 420 486 (77) 348 (757) 420 Comprehensive Income Attributable to ConocoPhillips $ 1,470 1,536 22 864 (2,422) 1,470 *Certain amounts have been reclassified to conform to the current-period presentation resulting from the adoption of ASU No. 2017-07. See Note 2 — Changes in Accounting Principles, for additional information. See Notes to Consolidated Financial Statements. Millions of Dollars Nine Months Ended September 30, 2018 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 $ - 11,774 - 14,977 - 26,751 Equity in earnings of affiliates 4,562 5,398 - 833 (10,026) 767 Gain on dispositions - 78 - 97 - 175 Other income - 230 - 443 - 673 Intercompany revenues 28 124 129 4,227 (4,508) - Total Revenues and Other Income 4,590 17,604 129 20,577 (14,534) 28,366 Costs and Expenses Purchased commodities - 10,571 - 3,757 (4,020) 10,308 Production and operating expenses - 723 - 3,181 (53) 3,851 Selling, general and administrative expenses 7 254 - 80 (5) 336 Exploration expenses - 132 - 135 - 267 Depreciation, depletion and amortization - 427 - 3,917 - 4,344 Impairments - (9) - 30 - 21 Taxes other than income taxes - 111 - 657 - 768 Accretion on discounted liabilities - 13 - 253 - 266 Interest and debt expense 219 456 110 192 (430) 547 Foreign currency transaction (gains) losses 22 (6) (43) 34 - 7 Other expenses - 348 - 2 - 350 Total Costs and Expenses 248 13,020 67 12,238 (4,508) 21,065 Income before income taxes 4,342 4,584 62 8,339 (10,026) 7,301 Income tax provision (benefit) (47) 22 (5) 2,904 - 2,874 Net income 4,389 4,562 67 5,435 (10,026) 4,427 Less: net income attributable to noncontrolling interests - - - (38) - (38) Net Income Attributable to ConocoPhillips $ 4,389 4,562 67 5,397 (10,026) 4,389 Comprehensive Income (Loss) Attributable to ConocoPhillips $ 4,407 4,580 (13) 5,289 (9,856) 4,407 Income Statement Nine Months Ended September 30, 2017* Revenues and Other Income Sales and other operating revenues $ - 9,066 - 11,921 - 20,987 Equity in earnings (losses) of affiliates (2,092) (776) - 432 3,010 574 Gain on dispositions - 908 - 1,236 - 2,144 Other income 1 27 - 115 - 143 Intercompany revenues 39 222 126 2,360 (2,747) - Total Revenues and Other Income (2,052) 9,447 126 16,064 263 23,848 Costs and Expenses Purchased commodities - 8,068 - 3,229 (2,257) 9,040 Production and operating expenses - 483 - 3,358 (3) 3,838 Selling, general and administrative expenses 8 244 - 55 (5) 302 Exploration expenses - 433 - 287 - 720 Depreciation, depletion and amortization - 658 - 4,554 - 5,212 Impairments - 1,075 - 5,400 - 6,475 Taxes other than income taxes - 114 - 490 - 604 Accretion on discounted liabilities - 28 - 248 - 276 Interest and debt expense 340 505 110 399 (482) 872 Foreign currency transaction (gains) losses (49) 3 145 (71) - 28 Other expenses 267 159 - (5) - 421 Total Costs and Expenses 566 11,770 255 17,944 (2,747) 27,788 Loss before income taxes (2,618) (2,323) (129) (1,880) 3,010 (3,940) Income tax provision (benefit) (184) (231) 12 (1,146) - (1,549) Net loss (2,434) (2,092) (141) (734) 3,010 (2,391) Less: net income attributable to noncontrolling interests - - - (43) - (43) Net Loss Attributable to ConocoPhillips $ (2,434) (2,092) (141) (777) 3,010 (2,434) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (1,533) (1,191) 39 (37) 1,189 (1,533) *Certain amounts have been reclassified to conform to the current-period presentation resulting from the adoption of ASU No. 2017-07. See Note 2—Changes in Accounting Principles, for additional information. See Notes to Consolidated Financial Statements. Millions of Dollars September 30, 2018 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Assets Cash and cash equivalents $ - 16 - 3,700 - 3,716 Short-term investments - - - 875 - 875 Accounts and notes receivable 6 2,614 1 5,301 (3,423) 4,499 Investment in Cenovus Energy - 2,086 - - - 2,086 Inventories - 198 - 1,041 - 1,239 Prepaid expenses and other current assets - 159 7 2,169 (27) 2,308 Total Current Assets 6 5,073 8 13,086 (3,450) 14,723 Investments, loans and long-term receivables* 31,249 51,482 2,623 20,829 (96,295) 9,888 Net properties, plants and equipment - 4,495 - 40,709 (468) 44,736 Other assets 19 484 178 1,458 (930) 1,209 Total Assets $ 31,274 61,534 2,809 76,082 (101,143) 70,556 Liabilities and Stockholders’ Equity Accounts payable $ - 3,444 7 3,890 (3,423) 3,918 Short-term debt (3) 12 7 88 (9) 95 Accrued income and other taxes - 104 - 1,478 - 1,582 Employee benefit obligations - 476 - 150 - 626 Other accruals 57 404 51 695 (27) 1,180 Total Current Liabilities 54 4,440 65 6,301 (3,459) 7,401 Long-term debt 3,790 7,152 1,698 2,740 (478) 14,902 Asset retirement obligations and accrued environmental costs - 424 - 7,130 - 7,554 Deferred income taxes - - - 5,968 (433) 5,535 Employee benefit obligations - 1,315 - 440 - 1,755 Other liabilities and deferred credits* 2,042 11,064 981 7,643 (20,400) 1,330 Total Liabilities 5,886 24,395 2,744 30,222 (24,770) 38,477 Retained earnings 25,972 17,591 (614) 16,906 (27,360) 32,495 Other common stockholders’ equity (584) 19,548 679 28,825 (49,013) (545) Noncontrolling interests - - - 129 - 129 Total Liabilities and Stockholders’ Equity $ 31,274 61,534 2,809 76,082 (101,143) 70,556 *Includes intercompany loans. Balance Sheet December 31, 2017 Assets Cash and cash equivalents $ - 234 4 6,087 - 6,325 Short-term investments - - - 1,873 - 1,873 Accounts and notes receivable 24 2,255 35 4,870 (2,864) 4,320 Investment in Cenovus Energy - 1,899 - - - 1,899 Inventories - 163 - 897 - 1,060 Prepaid expenses and other current assets 1 278 6 779 (29) 1,035 Total Current Assets 25 4,829 45 14,506 (2,893) 16,512 Investments, loans and long-term receivables* 29,400 47,974 2,533 15,050 (84,897) 10,060 Net properties, plants and equipment - 4,230 - 41,930 (477) 45,683 Other assets 15 1,146 186 1,302 (1,542) 1,107 Total Assets $ 29,440 58,179 2,764 72,788 (89,809) 73,362 Liabilities and Stockholders’ Equity Accounts payable $ - 3,094 1 3,799 (2,864) 4,030 Short-term debt (5) 2,505 7 77 (9) 2,575 Accrued income and other taxes - 107 - 931 - 1,038 Employee benefit obligations - 554 - 171 - 725 Other accruals 85 314 48 612 (30) 1,029 Total Current Liabilities 80 6,574 56 5,590 (2,903) 9,397 Long-term debt 3,787 9,321 1,703 2,794 (477) 17,128 Asset retirement obligations and accrued environmental costs - 432 - 7,199 - 7,631 Deferred income taxes - - - 6,263 (981) 5,282 Employee benefit obligations - 1,335 - 519 - 1,854 Other liabilities and deferred credits* 1,528 5,229 926 9,215 (15,629) 1,269 Total Liabilities 5,395 22,891 2,685 31,580 (19,990) 42,561 Retained earnings 22,867 13,317 (681) 11,958 (18,070) 29,391 Other common stockholders’ equity 1,178 21,971 760 29,056 (51,749) 1,216 Noncontrolling interests - - - 194 - 194 Total Liabilities and Stockholders’ Equity $ 29,440 58,179 2,764 72,788 (89,809) 73,362 *Includes intercompany loans. Millions of Dollars Nine Months Ended September 30, 2018 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 $ 2,331 863 (121) 8,937 (2,859) 9,151 Cash Flows From Investing Activities Capital expenditures and investments - (771) - (4,369) 7 (5,133) Working capital changes associated with investing activities - (77) - 20 - (57) Proceeds from asset dispositions - 307 - 199 (112) 394 Sales of short-term investments - - - 996 - 996 Long-term advances/loans—related parties - (36) - (127) 163 - Collection of advances/loans—related parties - 3,432 - 129 (3,442) 119 Intercompany cash management 514 3,426 - (3,940) - - Other - - - 16 - 16 Net Cash Provided by (Used in) Investing Activities 514 6,281 - (7,076) (3,384) (3,665) Cash Flows From Financing Activities Issuance of debt - 10 117 36 (163) - Repayment of debt - (4,865) - (3,547) 3,442 (4,970) Issuance of company common stock 234 - - - (113) 121 Repurchase of company common stock (2,073) - - - - (2,073) Dividends paid (1,009) - - (452) 452 (1,009) Other 3 (2,511) - (228) 2,625 (111) Net Cash Provided by (Used in) Financing Activities (2,845) (7,366) 117 (4,191) 6,243 (8,042) Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash - 4 - (44) - (40) Net Change in Cash, Cash Equivalents and Restricted Cash - (218) (4) (2,374) - (2,596) Cash, cash equivalents and restricted cash at beginning of period* - 234 4 6,298 - 6,536 Cash, Cash Equivalents and Restricted Cash at End of Period $ - 16 - 3,924 - 3,940 Statement of Cash Flows Nine Months Ended September 30, 2017 Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (161) 634 22 6,868 (2,767) 4,596 Cash Flows From Investing Activities Capital expenditures and investments - (1,230) - (2,711) 867 (3,074) Working capital changes associated with investing activities - 36 - (54) - (18) Proceeds from asset dispositions 5,000 10,974 - 12,737 (14,971) 13,740 Purchases of short-term investments - - - (2,583) - (2,583) Long-term advances/loans—related parties - (74) - (20) 94 - Collection of advances/loans—related parties 658 127 - 2,196 (2,866) 115 Intercompany cash management 2,903 (2,474) - (429) - - Other - - - 51 - 51 Net Cash Provided by Investing Activities 8,561 7,359 - 9,187 (16,876) 8,231 Cash Flows From Financing Activities Issuance of debt - 20 - 74 (94) - Repayment of debt (5,459) (3,146) - (855) 2,866 (6,594) Issuance of company common stock 87 - - - (152) (65) Repurchase of company common stock (2,045) - - - - (2,045) Dividends paid (986) - - (2,919) 2,919 (986) Other 3 (5,000) - (9,187) 14,104 (80) Net Cash Used in Financing Activities (8,400) (8,126) - (12,887) 19,643 (9,770) Effect of Exchange Rate Changes on Cash and Cash Equivalents - 1 - 243 - 244 Net Change in Cash and Cash Equivalents - (132) 22 3,411 - 3,301 Cash and cash equivalents at beginning of period - 358 13 3,239 - 3,610 Cash and Cash Equivalents at End of Period $ - 226 35 6,650 - 6,911 *Restated to include $211 million of restricted cash at January 1, 2018. See Note 2 — Changes in Accounting Principles for additional information relating to the adoption of ASU No. 2016-18. Restricted cash totaling $224 million is included in the "Other assets" line of our Consolidated Balance Sheet as of September 30, 2018.

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2018
Policy Text Block [Abstract]
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 2017 Annual Report on Form 10-K.
New Accounting Pronouncements, Policy	We adopted the provisions of Financial Accounting Standards Board (FASB) Accounting Standards Update ( ASU ) No. 2014-09, “Revenue from Contracts with Customers , ” and its amendments issued by the provisions of ASU No. 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net) , ” ASU No. 2016-10, “Identifying Performance Obligations and Licensing , ” ASU No. 2016-12, “Narrow-Scope Improvements and Practical Expedients , ” and ASU No. 2016-20, “Technical Corrections and Improvements to Topic 606, Revenue From Contracts with Customers , ” collectively Accounting Standards Codification (ASC) Topic 606 , “Revenue from Contracts with Customers,” (ASC Topic 606) beginning January 1, 2018. ASC Topic 60 6 outlines a single comprehensive model for an entity to use in accounting for revenue arising from all contracts with customers except where revenues are in scope of another accounting standard. T he ASU superseded the revenue recognition requirements in ASC Topic 605, “Revenue Recognition , ” and most industry-specific guidance. ASC Topic 606 sets forth a five-step model for determining when and how revenue is recognized. Under the model, an entity is required to recognize revenue to depict the transfer o f goods or services to a customer at an amount reflecting the consideration it expects to receive in exchange for those goods and services. ASC Topic 606 also requires certain additional revenue-related disclosures. The adoption of ASC Topic 606 did not have a material impact on our consolidated financial statements. See Note 20 —S ales and Other Operating Revenues for additional information related to this ASC . We adopted the provisions of F ASB AS U No. 2016-01, “Recognition and Measurement of Financial Assets and Liabilities , ” (AS U No. 2016-01 ) beginning January 1, 2018. The ASU, among other things, requires an entit y to record the changes in fair value of equity investments, other than investments accounted for using the equity method, within net i ncome. Under this ASU, an entity is no longer able to recognize unrealized holding gains and losses on available-for-sale securities in other comprehensive income and instead must recognize them in the income statement . See Note 7 — Investment i n Cenovus Energy and Note 16 — Accumulated Other Comprehensive Loss for additional information relating to this ASU The cumulative effect of the changes made to our consolidated balance sheet at January 1, 2018, for the adoption of ASC Topic 606 and ASU No. 2016-01 were as follows: Millions of Dollars December 31 ASC Topic 606 ASU No. 2016-01 January 1 2017 Adjustments Adjustments 2018 Liabilities Other accruals $ 1,029 104 - 1,133 Total current liabilities 9,397 104 - 9,501 Deferred income taxes 5,282 (31) - 5,251 Other liabilities and deferred credits 1,269 147 - 1,416 Total liabilities 42,561 220 - 42,781 Equity Accumulated other comprehensive loss $ (5,518) - 58 (5,460) Retained earnings 29,391 (220) (58) 29,113 Total common stockholders' equity 30,607 (220) - 30,387 Total equity 30,801 (220) - 30,581 For discussion of adjustments for ASU No. 2016-01 and ASC Topic 606, see Note 7 — Investment in Cenovus Energy and Note 20—Sales and Other Operating Revenues, respectively. We adopted the provisions of FASB ASU No. 2017-07, “Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” beginning January 1, 2018. We retrospectively applied the presentation of service cost separate from the other components of net periodic costs. The interest cost, expected return on plan assets, amortization of prior service cost/credit, recognized net actuarial loss/gain, settlement expense, curtailment loss/gain, and special termination benefits have been reclassified from the “ Production and operating expenses,” “Selling, general and administrative expenses,” and “Exploration expenses” lines to the “ Other expenses” line on our consolidated income statement. We elected to apply the prac tical expedient which allows us to reclassify amounts disclosed previously in the employee benefit plans footnote as the basis for applying retrospective presentation for prior comparative periods as it is impracticable to determine the disaggregation of t he cost components for amounts capitalized and amortized in those periods. On a prospective basis, the other components of net periodic benefit costs will not be included in amounts capitalized in inventory or properties, plants, and equipment (PP&E) We adopted the provisions of FASB ASU No. 2016-15 , “Classification of Certain Cash Receipts and Cash Payments , ” beginning January 1, 2018. This ASU clarifies how certain cash receipts and cash payments should be classified and presented in the statement of cash flows. We have made an accounting policy election to classify distributions received from equity method investees using the nature of the distribution approach which classifies distributions received from investees as either cash inflows from operating activities or cash inflows from investing activities in the statement of cash flows based on the nature of the activ ities of the investee that generated the distribution. The impact of adopting this ASU was not material to prior presented periods. We adopted the provisions of FASB ASU No. 2016-18 , “Restricted Cash , ” beginning January 1, 2018. This ASU requires amount s deemed restricted cash to be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows, and presentation should permit a reconciliation when cash, cash equivalent s and restricted cash are presented in more than one line item on the balance sheet. We have amounts deposited in statutory bank accounts in certain countries to satisfy asset retirement obligations (ARO) . These amounts are deemed restricted cash and are included in the “ Other assets ” line of our consolidated balance sheet. This standard is required to be applied retrospectively to all periods presented, but the impact in those periods was not material .
Revenue Recognition, Policy	Revenues associated with the sales of crude oil, bitumen, natural gas, LNG, natural gas liquids and other items are recognized at the point in time when the customer obtains control of the asset. In evaluating when a customer has control of the asset , we primarily consider whether the transfer of legal title and physical delivery has occurred, whether the cus tomer has significant risks and rewards of ownership, and whether the customer has accepted delivery and a right to payment exists. These products are typically sol d at prevailing market prices. We allocate variable market-based consideration to deliveri es (performance obligations) in the current period as that consideration relates specifically to our efforts to transfer control of current period deliveries to the customer and represents the amount we expect to be entitled to in exchange for the related products. Payment is typically due within 30 days or less.

Change in Accounting Principl_2

Change in Accounting Principles (Tables)	9 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles [Table Text Block]	The cumulative effect of the changes made to our consolidated balance sheet at January 1, 2018, for the adoption of ASC Topic 606 and ASU No. 2016-01 were as follows: Millions of Dollars December 31 ASC Topic 606 ASU No. 2016-01 January 1 2017 Adjustments Adjustments 2018 Liabilities Other accruals $ 1,029 104 - 1,133 Total current liabilities 9,397 104 - 9,501 Deferred income taxes 5,282 (31) - 5,251 Other liabilities and deferred credits 1,269 147 - 1,416 Total liabilities 42,561 220 - 42,781 Equity Accumulated other comprehensive loss $ (5,518) - 58 (5,460) Retained earnings 29,391 (220) (58) 29,113 Total common stockholders' equity 30,607 (220) - 30,387 Total equity 30,801 (220) - 30,581 For discussion of adjustments for ASU No. 2016-01 and ASC Topic 606, see Note 7 — Investment in Cenovus Energy and Note 20—Sales and Other Operating Revenues, respectively. The effect of the retrospective presentation change related to the net periodic benefit cost of our defined benefit pension and other postretirement employee benefits plans on our consolidated income statement was as follows: Millions of Dollars Previously Effect of Change As Reported Higher/(Lower) Revised Three Months Ended September 30, 2017 Production and operating expenses $ 1,224 (2) 1,222 Selling, general and administrative expenses 132 (22) 110 Exploration expenses 75 (2) 73 Other expenses 51 26 77 Nine Months Ended September 30, 2017 Production and operating expenses $ 3,849 (11) 3,838 Selling, general and administrative expenses 423 (121) 302 Exploration expenses 724 (4) 720 Other expenses 285 136 421

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2018
Inventories [Abstract]
Inventories	Note 4—Inventories Inventories consisted of the following: Millions of Dollars September 30 December 31 2018 2017 Crude oil and natural gas $ 673 512 Materials and supplies 566 548 $ 1,239 1,060

Impairments (Tables)

Impairments (Tables)	9 Months Ended
	Sep. 30, 2018
Impairment Of Long Lived Assets [Abstract]
Impairment charges by segment before tax.	Note 9—Impairments During the three- and nine-month periods ended September 30, 2018 and 2017, we recognized before-tax impairment charges within the following segments: Millions of Dollars Three Months Ended Nine Months Ended September 30 September 30 2018 2017 2018 2017 Alaska $ - 1 - 178 Lower 48 44 3 55 3,888 Canada - - - 18 Europe and North Africa - 2 (48) 7 Asia Pacific and Middle East - - 14 2,384 $ 44 6 21 6,475

Noncontrolling Interests (Table

Noncontrolling Interests (Tables)	9 Months Ended
	Sep. 30, 2018
Noncontrolling Interests [Abstract]
Change in equity attributable to non-controlling interests	Note 11—Noncontrolling Interests Activity attributable to common stockholders’ equity and noncontrolling interests for the first nine months of 2018 and 2017 was as follows: Millions of Dollars 2018 2017 Common Stockholders’ Equity Non-Controlling Interest Total Equity Common Stockholders’ Equity Non-Controlling Interest Total Equity Balance at January 1 $ 30,607 194 30,801 34,974 252 35,226 Net income (loss) 4,389 38 4,427 (2,434) 43 (2,391) Dividends (1,009) - (1,009) (986) - (986) Repurchase of company common stock (2,073) - (2,073) (2,045) - (2,045) Distributions to noncontrolling interests - (105) (105) - (84) (84) Changes in Accounting Principles* (220) - (220) Other changes, net** 256 2 258 991 1 992 Balance at September 30 $ 31,950 129 32,079 30,500 212 30,712 *See Note 2—Changes in Accounting Principles for additional information related to ASC Topic 606. **Includes components of other comprehensive income, which are disclosed separately in our Consolidated Statement of Comprehensive Income.

Derivative and Financial Inst_2

Derivative and Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2018
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 September 30 December 31 2018 2017 Assets Prepaid expenses and other current assets $ 259 275 Other assets 42 36 Liabilities Other accruals 278 282 Other liabilities and deferred credits 37 28 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 September 30 December 31 2018 2017 Assets Prepaid expenses and other current assets $ 18 1 Other assets - 6 Liabilities Other accruals 7 - Other liabilities and deferred credits - 15 In December 2017, we entered into foreign exchange zero cost collars buying the right to sell $1.25 billion CAD at $0.707 CAD and selling the right to buy $1.25 billion CAD at $0.842 CAD against the U.S. dollar.
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 Nine Months Ended September 30 September 30 2018 2017 2018 2017 Sales and other operating revenues $ (29) 17 (6) 120 Other income 3 (1) 12 (1) Purchased commodities 18 (19) 15 (88) 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 Nine Months Ended September 30 September 30 2018 2017 2018 2017 Foreign currency transaction (gains) losses $ (2) (1) (5) 2
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) September 30 December 31 2018 2017 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (19) (29) Basis 5 12 We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency September 30 December 31 2018 2017 Foreign Currency Exchange Derivatives Sell U.S. dollar, buy other currencies* USD 1,258 - Sell British pound, buy euro GBP 23 1 Sell Canadian dollar, buy U.S. dollar CAD 1,230 1,225 *Primarily British pound.
Balances of financial instruments	Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments September 30 December 31 September 30 December 31 2018 2017 2018 2017 Cash $ 511 948 Time deposits Remaining maturities from 1 to 90 days 2,966 5,004 104 821 Commercial paper Remaining maturities from 1 to 90 days 239 373 771 978 Remaining maturities from 91 to 180 days - - - 74 $ 3,716 6,325 875 1,873

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	9 Months Ended
	Sep. 30, 2018
Fair Value Measurement [Abstract]
Fair value hierarchy for gross financial assets and liabilities	Millions of Dollars September 30, 2018 December 31, 2017 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ 2,086 - - 2,086 1,899 - - 1,899 Commodity derivatives 186 97 18 301 175 106 30 311 Total assets $ 2,272 97 18 2,387 2,074 106 30 2,210 Liabilities Commodity derivatives $ 176 103 36 315 158 111 41 310 Total liabilities $ 176 103 36 315 158 111 41 310
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 September 30, 2018 Assets $ 301 206 95 - 7 88 Liabilities 315 206 109 2 3 104 December 31, 2017 Assets $ 311 186 125 - 4 121 Liabilities 310 186 124 7 5 112 At September 30, 2018 and December 31, 2017, 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 Net PP&E (held for sale) March 31, 2018 $ 250 - 250 44 September 30, 2018 $ 201 201 - 43
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 September 30 December 31 September 30 December 31 2018 2017 2018 2017 Financial assets Investment in Cenovus Energy $ 2,086 1,899 2,086 1,899 Commodity derivatives 95 125 95 125 Total loans and advances—related parties 464 586 464 586 Financial liabilities Total debt, excluding capital leases 14,201 18,929 16,554 22,435 Commodity derivatives 107 117 107 117

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Tables)	9 Months Ended
	Sep. 30, 2018
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Components of accumulated other comprehensive income in the equity section of the balance sheet	Note 16—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 Income (Loss) December 31, 2017 $ (400) (58) (5,060) (5,518) Cumulative effect of adopting ASU No. 2016-01* - 58 - 58 Other comprehensive income (loss) 240 - (222) 18 September 30, 2018 $ (160) - (5,282) (5,442) *See Note 2—Changes in Accounting Principles for additional information.
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 Nine Months Ended September 30 September 30 2018 2017 2018 2017 Defined benefit plans $ 17 26 155 116 The above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of $6 million and $14 million for the three months ended September 30, 2018 and September 30, 2017, respectively, and $43 million and $61 million for the nine-month periods ended September 30, 2018 and September 30, 2017, respectively. See Note 18—Employee Benefit Plans, for additional information.

Cash Flow Information (Tables)

Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2018
Cash Flow Information [Abstract]
Cash Flow Information	Note 17 —Cash Flow Information Millions of Dollars Nine Months Ended September 30 2018 2017 Cash Payments Interest $ 584 918 Income taxes 1,927 574 Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ (1,705) (4,999) Short-term investments sold 2,701 2,416 $ 996 (2,583)

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	9 Months Ended
	Sep. 30, 2018
Employee Benefit Plans [Abstract]
Pension and Postretirement Plans	Note 18 — Employee Benefit Plans Pension and Postretirement Plans Millions of Dollars Pension Benefits Other Benefits 2018 2017 2018 2017 U.S. Int'l. U.S. Int'l. Components of Net Periodic Benefit Cost Three Months Ended September 30 Service cost $ 20 20 21 20 - - Interest cost 22 26 29 27 2 3 Expected return on plan assets (22) (38) (32) (41) - - Amortization of prior service cost (credit) - (1) 1 (1) (9) (9) Recognized net actuarial loss (gain) 10 9 17 12 - (1) Settlements 14 - 21 - - - Curtailments - (1) - - - - Net periodic benefit cost $ 44 15 57 17 (7) (7) Nine Months Ended September 30 Service cost $ 63 63 67 59 1 1 Interest cost 76 80 90 78 6 7 Expected return on plan assets (91) (118) (97) (119) - - Amortization of prior service cost (credit) - (4) 3 (4) (26) (27) Recognized net actuarial loss (gain) 41 27 53 36 (1) (2) Settlements 161 - 118 - - - Curtailments - (1) - - - - Net periodic benefit cost $ 250 47 234 50 (20) (21)
Severance accrual	Millions of Dollars Balance at December 31, 2017 $ 53 Accruals 65 Benefit payments (38) Balance at September 30, 2018 $ 80

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2018
Related Party Transactions [Abstract]
Significant transactions with related parties	Note 19—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 Nine Months Ended September 30 September 30 2018 2017 2018 2017 Operating revenues and other income $ 27 24 74 83 Purchases 25 26 74 74 Operating expenses and selling, general and administrative expenses 13 16 44 42 Net interest (income) expense* (4) (4) (11) (10) *We paid interest to, or received interest from, various affiliates. See Note 6—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Sales and Other Operating Rev_2

Sales and Other Operating Revenue (Tables)	9 Months Ended
	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue [Table Text Block]	Millions of Dollars Three Months Ended Nine Months Ended September 30 September 30 2018 2017 * 2018 2017 * Revenue from contracts with customers $ 7,546 4,636 20,834 14,428 Revenue from contracts outside the scope of ASC Topic 606 Physical contracts meeting the definition of a derivative 1,897 2,050 5,877 6,631 Financial derivative contracts 6 2 40 (72) Consolidated sales and other operating revenues $ 9,449 6,688 26,751 20,987 *Under the modified retrospective approach, prior period amounts have not been adjusted upon adoption of ASC Topic 606. Millions of Dollars Three Months Ended Nine Months Ended September 30 September 30 2018 2017 * 2018 2017 * Revenue from Outside the Scope of ASC Topic 606 by Segment Lower 48 $ 1,534 1,563 4,547 4,834 Canada 87 161 374 680 Europe and North Africa 276 326 956 1,117 Physical contracts meeting the definition of a derivative $ 1,897 2,050 5,877 6,631 *Under the modified retrospective approach, prior period amounts have not been adjusted upon adoption of ASC Topic 606. Millions of Dollars Three Months Ended Nine Months Ended September 30 September 30 2018 2017 * 2018 2017 * Revenue from Outside the Scope of ASC Topic 606 by Product Crude oil $ 267 171 843 530 Natural gas 1,522 1,811 4,775 5,870 Other 108 68 259 231 Physical contracts meeting the definition of a derivative $ 1,897 2,050 5,877 6,631 *Under the modified retrospective approach, prior period amounts have not been adjusted upon adoption of ASC Topic 606.
Contract with Customer, Asset and Liability [Table Text Block]	Millions of Dollars Contract Liabilities At January 1, 2018 $ 251 Contractual payments received* 81 Revenue recognized (148) At September 30, 2018 $ 184 Amounts Recognized in the Consolidated Balance Sheet at September 30, 2018 Current liabilities $ 147 Noncurrent liabilities 37 $ 184 *Includes $14 million and $81 million for the three- and nine-month periods of 2018, respectively.

Segment Disclosures and Relat_2

Segment Disclosures and Related Information (Tables)	9 Months Ended
	Sep. 30, 2018
Segment Disclosures and Related Information [Abstract]
Analysis of Results by Operating Segment	Analysis of Results by Operating Segment Millions of Dollars Three Months Ended Nine Months Ended September 30 September 30 2018 2017 * 2018 2017 * Sales and Other Operating Revenues Alaska $ 1,493 932 4,281 3,010 Lower 48 4,543 3,102 12,347 9,422 Intersegment eliminations (14) (2) (18) (7) Lower 48 4,529 3,100 12,329 9,415 Canada 735 699 2,436 2,357 Intersegment eliminations (308) (155) (853) (330) Canada 427 544 1,583 2,027 Europe and North Africa 1,574 1,110 4,826 3,564 Asia Pacific and Middle East 1,348 959 3,570 2,877 Corporate and Other 78 43 162 94 Consolidated sales and other operating revenues $ 9,449 6,688 26,751 20,987 Sales and Other Operating Revenues by Geographic Location United States $ 6,025 4,038 16,617 12,440 Australia 515 323 1,258 1,050 Canada 427 544 1,583 2,027 China 262 148 616 511 Indonesia 234 191 662 554 Libya** 264 91 802 315 Malaysia 339 297 1,039 768 Norway 734 583 2,112 1,751 United Kingdom 574 437 1,911 1,498 Other foreign countries 75 36 151 73 Worldwide consolidated $ 9,449 6,688 26,751 20,987 Sales and Other Operating Revenues by Product Crude Oil $ 5,277 2,947 14,503 9,387 Natural gas 2,503 2,496 7,593 7,949 Natural gas liquids 351 238 847 745 Other*** 1,318 1,007 3,808 2,906 Consolidated sales and other operating revenues by product $ 9,449 6,688 26,751 20,987 *Under the modified retrospective approach, prior period amounts have not been adjusted upon adoption of ASC Topic 606. **Included in "Other foreign countries" in prior periods. ***Includes LNG and bitumen. Net Income (Loss) Attributable to ConocoPhillips Alaska $ 427 103 1,369 291 Lower 48 513 (97) 1,231 (2,995) Canada 34 280 2 2,607 Europe and North Africa 241 85 776 379 Asia Pacific and Middle East 577 396 1,504 (1,540) Other International 316 (20) 267 (77) Corporate and Other (247) (327) (760) (1,099) Consolidated net income (loss) attributable to ConocoPhillips $ 1,861 420 4,389 (2,434) Millions of Dollars September 30 December 31 2018 2017 Total Assets Alaska $ 12,688 12,108 Lower 48 15,308 14,632 Canada 5,950 6,214 Europe and North Africa 11,895 11,870 Asia Pacific and Middle East 16,611 16,985 Other International 315 97 Corporate and Other 7,789 11,456 Consolidated total assets $ 70,556 73,362

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2018
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 Nine Months Ended Three Months Ended Nine Months Ended September 30 September 30 September 30 September 30 2018 2017 2018 2017 2018 2017 2018 2017 Income (loss) before income taxes United States $ 893 (197) 2,799 (5,259) 30.7 % (30.2) 38.3 133.5 Foreign 2,013 850 4,502 1,319 69.3 130.2 61.7 (33.5) $ 2,906 653 7,301 (3,940) 100.0 % 100.0 100.0 100.0 Federal statutory income tax $ 610 228 1,533 (1,379) 21.0 % 35.0 21.0 35.0 Non-U.S. effective tax rates 479 137 1,339 503 16.5 21.0 18.3 (12.8) Canada disposition - (8) - (1,176) - (1.2) - 29.8 Recovery of outside basis (16) (118) (19) (957) (0.6) (18.1) (0.2) 24.3 Adjustment to tax reserves (3) (17) 2 764 (0.1) (2.6) - (19.4) Adjustment to valuation allowance (29) - 13 24 (1.0) - 0.2 (0.6) APLNG impairment - - - 834 - - - (21.2) State income tax 38 14 83 (98) 1.3 2.1 1.1 2.5 Enhanced oil recovery credit (36) (5) (73) (49) (1.3) (0.8) (1.0) 1.2 Other (10) (14) (4) (15) (0.3) (2.2) - 0.5 $ 1,033 217 2,874 (1,549) 35.5 % 33.2 39.4 39.3

Supplementary Information - C_2

Supplementary Information - Condensed Consolidating Financial Information (Tables)	9 Months Ended
	Sep. 30, 2018
Supplementary Information - Condensed Consolidating Financial Information [Abstract]
Condensed Consolidated Income Statement	Millions of Dollars Three Months Ended September 30, 2018 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 $ - 4,330 - 5,119 - 9,449 Equity in earnings of affiliates 1,903 2,166 - 256 (4,031) 294 Gain on dispositions - 75 - 38 - 113 Other income - (61) - 370 - 309 Intercompany revenues 9 34 42 1,619 (1,704) - Total Revenues and Other Income 1,912 6,544 42 7,402 (5,735) 10,165 Costs and Expenses Purchased commodities - 3,880 - 1,196 (1,546) 3,530 Production and operating expenses - 298 - 1,085 (16) 1,367 Selling, general and administrative expenses 2 99 - 18 - 119 Exploration expenses - 41 - 62 - 103 Depreciation, depletion and amortization - 152 - 1,342 - 1,494 Impairments - 1 - 43 - 44 Taxes other than income taxes - 33 - 279 - 312 Accretion on discounted liabilities - 4 - 85 - 89 Interest and debt expense 72 156 37 63 (142) 186 Foreign currency transaction (gains) losses (12) 3 42 (28) - 5 Other expenses - 6 - 4 - 10 Total Costs and Expenses 62 4,673 79 4,149 (1,704) 7,259 Income (Loss) before income taxes 1,850 1,871 (37) 3,253 (4,031) 2,906 Income tax provision (benefit) (11) (32) 1 1,075 - 1,033 Net income (loss) 1,861 1,903 (38) 2,178 (4,031) 1,873 Less: net income attributable to noncontrolling interests - - - (12) - (12) Net Income (Loss) Attributable to ConocoPhillips $ 1,861 1,903 (38) 2,166 (4,031) 1,861 Comprehensive Income Attributable to ConocoPhillips $ 2,056 2,098 5 2,330 (4,433) 2,056 Income Statement Three Months Ended September 30, 2017* Revenues and Other Income Sales and other operating revenues $ - 2,997 - 3,691 - 6,688 Equity in earnings of affiliates 486 348 - 119 (757) 196 Gain (Loss) on dispositions - 879 - (633) - 246 Other income - 12 - 53 - 65 Intercompany revenues 10 77 43 774 (904) - Total Revenues and Other Income 496 4,313 43 4,004 (1,661) 7,195 Costs and Expenses Purchased commodities - 2,666 - 1,001 (741) 2,926 Production and operating expenses - 216 - 1,007 (1) 1,222 Selling, general and administrative expenses 2 97 - 11 - 110 Exploration expenses - 29 - 44 - 73 Depreciation, depletion and amortization - 203 - 1,405 - 1,608 Impairments - 1 - 5 - 6 Taxes other than income taxes - 29 - 146 - 175 Accretion on discounted liabilities - 8 - 81 - 89 Interest and debt expense 86 169 37 121 (162) 251 Foreign currency transaction (gains) losses (27) 1 77 (46) - 5 Other expenses 50 29 - (2) - 77 Total Costs and Expenses 111 3,448 114 3,773 (904) 6,542 Income (Loss) before income taxes 385 865 (71) 231 (757) 653 Income tax provision (benefit) (35) 379 6 (133) - 217 Net income (loss) 420 486 (77) 364 (757) 436 Less: net income attributable to noncontrolling interests - - - (16) - (16) Net Income (Loss) Attributable to ConocoPhillips $ 420 486 (77) 348 (757) 420 Comprehensive Income Attributable to ConocoPhillips $ 1,470 1,536 22 864 (2,422) 1,470 *Certain amounts have been reclassified to conform to the current-period presentation resulting from the adoption of ASU No. 2017-07. See Note 2 — Changes in Accounting Principles, for additional information. See Notes to Consolidated Financial Statements. Millions of Dollars Nine Months Ended September 30, 2018 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 $ - 11,774 - 14,977 - 26,751 Equity in earnings of affiliates 4,562 5,398 - 833 (10,026) 767 Gain on dispositions - 78 - 97 - 175 Other income - 230 - 443 - 673 Intercompany revenues 28 124 129 4,227 (4,508) - Total Revenues and Other Income 4,590 17,604 129 20,577 (14,534) 28,366 Costs and Expenses Purchased commodities - 10,571 - 3,757 (4,020) 10,308 Production and operating expenses - 723 - 3,181 (53) 3,851 Selling, general and administrative expenses 7 254 - 80 (5) 336 Exploration expenses - 132 - 135 - 267 Depreciation, depletion and amortization - 427 - 3,917 - 4,344 Impairments - (9) - 30 - 21 Taxes other than income taxes - 111 - 657 - 768 Accretion on discounted liabilities - 13 - 253 - 266 Interest and debt expense 219 456 110 192 (430) 547 Foreign currency transaction (gains) losses 22 (6) (43) 34 - 7 Other expenses - 348 - 2 - 350 Total Costs and Expenses 248 13,020 67 12,238 (4,508) 21,065 Income before income taxes 4,342 4,584 62 8,339 (10,026) 7,301 Income tax provision (benefit) (47) 22 (5) 2,904 - 2,874 Net income 4,389 4,562 67 5,435 (10,026) 4,427 Less: net income attributable to noncontrolling interests - - - (38) - (38) Net Income Attributable to ConocoPhillips $ 4,389 4,562 67 5,397 (10,026) 4,389 Comprehensive Income (Loss) Attributable to ConocoPhillips $ 4,407 4,580 (13) 5,289 (9,856) 4,407 Income Statement Nine Months Ended September 30, 2017* Revenues and Other Income Sales and other operating revenues $ - 9,066 - 11,921 - 20,987 Equity in earnings (losses) of affiliates (2,092) (776) - 432 3,010 574 Gain on dispositions - 908 - 1,236 - 2,144 Other income 1 27 - 115 - 143 Intercompany revenues 39 222 126 2,360 (2,747) - Total Revenues and Other Income (2,052) 9,447 126 16,064 263 23,848 Costs and Expenses Purchased commodities - 8,068 - 3,229 (2,257) 9,040 Production and operating expenses - 483 - 3,358 (3) 3,838 Selling, general and administrative expenses 8 244 - 55 (5) 302 Exploration expenses - 433 - 287 - 720 Depreciation, depletion and amortization - 658 - 4,554 - 5,212 Impairments - 1,075 - 5,400 - 6,475 Taxes other than income taxes - 114 - 490 - 604 Accretion on discounted liabilities - 28 - 248 - 276 Interest and debt expense 340 505 110 399 (482) 872 Foreign currency transaction (gains) losses (49) 3 145 (71) - 28 Other expenses 267 159 - (5) - 421 Total Costs and Expenses 566 11,770 255 17,944 (2,747) 27,788 Loss before income taxes (2,618) (2,323) (129) (1,880) 3,010 (3,940) Income tax provision (benefit) (184) (231) 12 (1,146) - (1,549) Net loss (2,434) (2,092) (141) (734) 3,010 (2,391) Less: net income attributable to noncontrolling interests - - - (43) - (43) Net Loss Attributable to ConocoPhillips $ (2,434) (2,092) (141) (777) 3,010 (2,434) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (1,533) (1,191) 39 (37) 1,189 (1,533) *Certain amounts have been reclassified to conform to the current-period presentation resulting from the adoption of ASU No. 2017-07. See Note 2—Changes in Accounting Principles, for additional information. See Notes to Consolidated Financial Statements.
Schedule of Condensed Balance Sheet	Millions of Dollars September 30, 2018 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Assets Cash and cash equivalents $ - 16 - 3,700 - 3,716 Short-term investments - - - 875 - 875 Accounts and notes receivable 6 2,614 1 5,301 (3,423) 4,499 Investment in Cenovus Energy - 2,086 - - - 2,086 Inventories - 198 - 1,041 - 1,239 Prepaid expenses and other current assets - 159 7 2,169 (27) 2,308 Total Current Assets 6 5,073 8 13,086 (3,450) 14,723 Investments, loans and long-term receivables* 31,249 51,482 2,623 20,829 (96,295) 9,888 Net properties, plants and equipment - 4,495 - 40,709 (468) 44,736 Other assets 19 484 178 1,458 (930) 1,209 Total Assets $ 31,274 61,534 2,809 76,082 (101,143) 70,556 Liabilities and Stockholders’ Equity Accounts payable $ - 3,444 7 3,890 (3,423) 3,918 Short-term debt (3) 12 7 88 (9) 95 Accrued income and other taxes - 104 - 1,478 - 1,582 Employee benefit obligations - 476 - 150 - 626 Other accruals 57 404 51 695 (27) 1,180 Total Current Liabilities 54 4,440 65 6,301 (3,459) 7,401 Long-term debt 3,790 7,152 1,698 2,740 (478) 14,902 Asset retirement obligations and accrued environmental costs - 424 - 7,130 - 7,554 Deferred income taxes - - - 5,968 (433) 5,535 Employee benefit obligations - 1,315 - 440 - 1,755 Other liabilities and deferred credits* 2,042 11,064 981 7,643 (20,400) 1,330 Total Liabilities 5,886 24,395 2,744 30,222 (24,770) 38,477 Retained earnings 25,972 17,591 (614) 16,906 (27,360) 32,495 Other common stockholders’ equity (584) 19,548 679 28,825 (49,013) (545) Noncontrolling interests - - - 129 - 129 Total Liabilities and Stockholders’ Equity $ 31,274 61,534 2,809 76,082 (101,143) 70,556 *Includes intercompany loans. Balance Sheet December 31, 2017 Assets Cash and cash equivalents $ - 234 4 6,087 - 6,325 Short-term investments - - - 1,873 - 1,873 Accounts and notes receivable 24 2,255 35 4,870 (2,864) 4,320 Investment in Cenovus Energy - 1,899 - - - 1,899 Inventories - 163 - 897 - 1,060 Prepaid expenses and other current assets 1 278 6 779 (29) 1,035 Total Current Assets 25 4,829 45 14,506 (2,893) 16,512 Investments, loans and long-term receivables* 29,400 47,974 2,533 15,050 (84,897) 10,060 Net properties, plants and equipment - 4,230 - 41,930 (477) 45,683 Other assets 15 1,146 186 1,302 (1,542) 1,107 Total Assets $ 29,440 58,179 2,764 72,788 (89,809) 73,362 Liabilities and Stockholders’ Equity Accounts payable $ - 3,094 1 3,799 (2,864) 4,030 Short-term debt (5) 2,505 7 77 (9) 2,575 Accrued income and other taxes - 107 - 931 - 1,038 Employee benefit obligations - 554 - 171 - 725 Other accruals 85 314 48 612 (30) 1,029 Total Current Liabilities 80 6,574 56 5,590 (2,903) 9,397 Long-term debt 3,787 9,321 1,703 2,794 (477) 17,128 Asset retirement obligations and accrued environmental costs - 432 - 7,199 - 7,631 Deferred income taxes - - - 6,263 (981) 5,282 Employee benefit obligations - 1,335 - 519 - 1,854 Other liabilities and deferred credits* 1,528 5,229 926 9,215 (15,629) 1,269 Total Liabilities 5,395 22,891 2,685 31,580 (19,990) 42,561 Retained earnings 22,867 13,317 (681) 11,958 (18,070) 29,391 Other common stockholders’ equity 1,178 21,971 760 29,056 (51,749) 1,216 Noncontrolling interests - - - 194 - 194 Total Liabilities and Stockholders’ Equity $ 29,440 58,179 2,764 72,788 (89,809) 73,362 *Includes intercompany loans.
Condensed Consolidated Statement of Cash Flows	Millions of Dollars Nine Months Ended September 30, 2018 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 $ 2,331 863 (121) 8,937 (2,859) 9,151 Cash Flows From Investing Activities Capital expenditures and investments - (771) - (4,369) 7 (5,133) Working capital changes associated with investing activities - (77) - 20 - (57) Proceeds from asset dispositions - 307 - 199 (112) 394 Sales of short-term investments - - - 996 - 996 Long-term advances/loans—related parties - (36) - (127) 163 - Collection of advances/loans—related parties - 3,432 - 129 (3,442) 119 Intercompany cash management 514 3,426 - (3,940) - - Other - - - 16 - 16 Net Cash Provided by (Used in) Investing Activities 514 6,281 - (7,076) (3,384) (3,665) Cash Flows From Financing Activities Issuance of debt - 10 117 36 (163) - Repayment of debt - (4,865) - (3,547) 3,442 (4,970) Issuance of company common stock 234 - - - (113) 121 Repurchase of company common stock (2,073) - - - - (2,073) Dividends paid (1,009) - - (452) 452 (1,009) Other 3 (2,511) - (228) 2,625 (111) Net Cash Provided by (Used in) Financing Activities (2,845) (7,366) 117 (4,191) 6,243 (8,042) Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash - 4 - (44) - (40) Net Change in Cash, Cash Equivalents and Restricted Cash - (218) (4) (2,374) - (2,596) Cash, cash equivalents and restricted cash at beginning of period* - 234 4 6,298 - 6,536 Cash, Cash Equivalents and Restricted Cash at End of Period $ - 16 - 3,924 - 3,940 Statement of Cash Flows Nine Months Ended September 30, 2017 Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (161) 634 22 6,868 (2,767) 4,596 Cash Flows From Investing Activities Capital expenditures and investments - (1,230) - (2,711) 867 (3,074) Working capital changes associated with investing activities - 36 - (54) - (18) Proceeds from asset dispositions 5,000 10,974 - 12,737 (14,971) 13,740 Purchases of short-term investments - - - (2,583) - (2,583) Long-term advances/loans—related parties - (74) - (20) 94 - Collection of advances/loans—related parties 658 127 - 2,196 (2,866) 115 Intercompany cash management 2,903 (2,474) - (429) - - Other - - - 51 - 51 Net Cash Provided by Investing Activities 8,561 7,359 - 9,187 (16,876) 8,231 Cash Flows From Financing Activities Issuance of debt - 20 - 74 (94) - Repayment of debt (5,459) (3,146) - (855) 2,866 (6,594) Issuance of company common stock 87 - - - (152) (65) Repurchase of company common stock (2,045) - - - - (2,045) Dividends paid (986) - - (2,919) 2,919 (986) Other 3 (5,000) - (9,187) 14,104 (80) Net Cash Used in Financing Activities (8,400) (8,126) - (12,887) 19,643 (9,770) Effect of Exchange Rate Changes on Cash and Cash Equivalents - 1 - 243 - 244 Net Change in Cash and Cash Equivalents - (132) 22 3,411 - 3,301 Cash and cash equivalents at beginning of period - 358 13 3,239 - 3,610 Cash and Cash Equivalents at End of Period $ - 226 35 6,650 - 6,911 *Restated to include $211 million of restricted cash at January 1, 2018. See Note 2 — Changes in Accounting Principles for additional information relating to the adoption of ASU No. 2016-18. Restricted cash totaling $224 million is included in the "Other assets" line of our Consolidated Balance Sheet as of September 30, 2018.

Change in Accounting Principl_3

Change in Accounting Principles (Details) - USD ($) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017		Sep. 30, 2018	Sep. 30, 2017		Jan. 01, 2018	Dec. 31, 2017	Dec. 31, 2016
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Production and Operating Expenses		$ 1,367	$ 1,222	[1],[2]	$ 3,851	$ 3,838	[1],[2]
Selling, General and Administrative Expense		119	110	[1],[2]	336	302	[1],[2]
Exploration Expense		103	73	[1],[2]	267	720	[1],[2]
Other Non Operating Expense		10	77	[1]	350	421	[1]
Liabilities [Abstract]
Other accruals		1,180			1,180				$ 1,029
Total Current Liabilities		7,401			7,401				9,397
Deferred Tax Liabilities, Noncurrent		5,535			5,535				5,282
Deferred Credits and Other Liabilities		1,330			1,330				1,269
Total Liabilities		38,477			38,477				42,561
Accumulated Other Comprehensive Income [Abstract]
Accumulated Other Comprehensive Income , Net of Tax		(5,442)			(5,442)				(5,518)
Retained Earnings (Accumulated Deficit)		32,495			32,495				29,391
Stockholders' Equity Attributable to Parent		31,950			31,950				30,607
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest		$ 32,079	30,712		$ 32,079	30,712			30,801	$ 35,226
Adjustments for New Accounting Pronouncement [Member]
Liabilities [Abstract]
Other accruals								$ 1,133	1,029
Total Current Liabilities								9,501	9,397
Deferred Tax Liabilities, Noncurrent								5,251	5,282
Deferred Credits and Other Liabilities								1,416	1,269
Total Liabilities								42,781	42,561
Accumulated Other Comprehensive Income [Abstract]
Accumulated Other Comprehensive Income , Net of Tax								(5,460)	(5,518)
Retained Earnings (Accumulated Deficit)								29,113	29,391
Stockholders' Equity Attributable to Parent								30,387	30,607
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest								30,581	$ 30,801
ASU 2014-09 Revenue Recognition [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member]
Liabilities [Abstract]
Other accruals	[3]							104
Total Current Liabilities	[3]							104
Deferred Tax Liabilities, Noncurrent	[3]							(31)
Deferred Credits and Other Liabilities	[3]							147
Total Liabilities	[3]							220
Accumulated Other Comprehensive Income [Abstract]
Accumulated Other Comprehensive Income , Net of Tax	[3]							0
Retained Earnings (Accumulated Deficit)	[3]							(220)
Stockholders' Equity Attributable to Parent	[3]							(220)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest	[3]							(220)
ASU 2016-01 Accounting for Cenovus Shares [Member] | Restatement Adjustment [Member]
Accumulated Other Comprehensive Income [Abstract]
Accumulated Other Comprehensive Income , Net of Tax								58
Retained Earnings (Accumulated Deficit)								$ (58)
ASU 2017-07 Pension Costs [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Production and Operating Expenses			1,222			3,838
Selling, General and Administrative Expense			110			302
Exploration Expense			73			720
Other Non Operating Expense			77			421
ASU 2017-07 Pension Costs [Member] | Previously Reported [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Production and Operating Expenses			1,224			3,849
Selling, General and Administrative Expense			132			423
Exploration Expense			75			724
Other Non Operating Expense			51			285
ASU 2017-07 Pension Costs [Member] | Restatement Adjustment [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Production and Operating Expenses			(2)			(11)
Selling, General and Administrative Expense			(22)			(121)
Exploration Expense			(2)			(4)
Other Non Operating Expense			$ 26			$ 136
[1]	*Certain amounts have been reclassified to conform to the current-period presentation resulting from the adoption of ASU No. 2017-07.
[2]	See Note 2—Changes in Accounting Principles, for additional information.
[3]	For discussion of adjustments for ASU No. 2016-01 and ASC Topic 606, see Note ##NICE—Investment in Cenovus Energy and Note ##NSAOR—Sales and Other Operating Revenues, respectively.

Variable Interest Entities (V_2

Variable Interest Entities (VIEs) (Details) - MWCC LLC [Member] $ in Millions	9 Months Ended
	Sep. 30, 2018USD ($)
Variable Interest Entity [Line Items]
Book value of equity method investment	$ 132
MWCC Board Members	ten
MWCC LLC [Member]
Variable Interest Entity [Line Items]
Ownership percentage in equity investment	10.00%
Term loan backed by a letter of credit	$ 154
Letter of Credit [Member] | MWCC LLC [Member]
Variable Interest Entity [Line Items]
Debt at face value - letter of credit	$ 22

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Inventories [Abstract]
Crude oil and natural gas	$ 673	$ 512
Materials and supplies	566	548
Total Inventories	$ 1,239	$ 1,060

Inventories Textual (Details)

Inventories Textual (Details) - USD ($) $ in Millions	1 Months Ended	9 Months Ended
	Apr. 30, 2018	Sep. 30, 2018	Dec. 31, 2017
Inventory [Line Items]
LIFO Inventory Amount		$ 283	$ 341
Excess of Replacement or Current Costs over Stated LIFO Value		100	$ 124
Conoco Phillips Vs Petroleos de Venezuela SA [Member]
Inventory [Line Items]
Litigation Settlement, Amount Awarded from Other Party	$ 2,000
Inventory Exchanges [Member] | Conoco Phillips Vs Petroleos de Venezuela SA [Member]
Inventory [Line Items]
Litigation Settlement, Amount Awarded from Other Party		$ 139

Assets Held for Sale or Sold (D

Assets Held for Sale or Sold (Details) - Operating Segments [Member] - USD ($) $ in Millions	1 Months Ended		3 Months Ended				9 Months Ended
	Oct. 31, 2018	Jul. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Oct. 01, 2018
Lower 48 Segment | 2018 Q3 Undeveloped Acreage Exchanged
Long Lived Assets Held For Sale [Line Items]
Gain (Loss) on Sale of Oil and Gas Property			$ 56
Barnett [Member] | Lower 48 Segment
Long Lived Assets Held For Sale [Line Items]
Net carrying value			201				$ 201
Impairment of AHFS			43		$ 44			$ 568
Fair Value - Net PP&E (held for sale)					250
Amount of PP&E in carrying value of assets			250				250
Pretax operating Income (Loss) on AHFS							(59)	(575)
Barnett [Member] | Lower 48 Segment | Scenario Plan [Member]
Long Lived Assets Held For Sale [Line Items]
Proceeds from asset dispositions			230
Barnett [Member] | Lower 48 Segment | Asset Retirement Obligation Costs [Member]
Long Lived Assets Held For Sale [Line Items]
Liabilities of AHFS			49				$ 49
2018 Q1 Certain properties sold. | Lower 48 Segment
Long Lived Assets Held For Sale [Line Items]
Proceeds from asset dispositions					112
Gain (Loss) on Sale of Oil and Gas Property					$ 0
2018 Q2 undeveloped acreage sold [Member] | Lower 48 Segment
Long Lived Assets Held For Sale [Line Items]
Proceeds from asset dispositions				$ 105
Gain (Loss) on Sale of Oil and Gas Property				0
Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member] | Canada
Long Lived Assets Held For Sale [Line Items]
Cenovus Contingent Payment Trigger							The contingent payment, calculated on a quarterly basis, is $6 million Canadian dollars (CAD) for every $1 CAD by which the Western Canada Select quarterly average crude price exceeds $52 CAD per barrel.
Gain (Loss) on Sale of Oil and Gas Property			45	$ 50
Clair Field [Member] | Europe and North Africa Segment [Member]
Long Lived Assets Held For Sale [Line Items]
Net carrying value			945				$ 945
Amount of PP&E in carrying value of assets			1,552				1,552
Amount of deferred taxes in carrying value of asset			544				544
Pretax operating Income (Loss) on AHFS							13	$ 1
Clair Field [Member] | Europe and North Africa Segment [Member] | Scenario Plan [Member]
Long Lived Assets Held For Sale [Line Items]
Percent Sold		16.50%
Percent Retained		7.50%
Clair Field [Member] | Europe and North Africa Segment [Member] | Minimum [Member] | Scenario Plan [Member]
Long Lived Assets Held For Sale [Line Items]
Non Cash Gain (Loss) On Sale		$ 500
Clair Field [Member] | Europe and North Africa Segment [Member] | Maximum [Member] | Scenario Plan [Member]
Long Lived Assets Held For Sale [Line Items]
Non Cash Gain (Loss) On Sale		$ 1,000
Clair Field [Member] | Europe and North Africa Segment [Member] | Asset Retirement Obligation Costs [Member]
Long Lived Assets Held For Sale [Line Items]
Liabilities of AHFS			$ 63				$ 63
San Juan Basin [Member] | Lower 48 Segment
Long Lived Assets Held For Sale [Line Items]
San Juan Contingent Trigger			The transaction includes a contingent payment of up to $300 million.
Proceeds from asset dispositions						$ 2,500
Gain (Loss) on Sale of Oil and Gas Property						$ (22)
Greater Sunrise Fields [Member] | Asia Pacific and Middle East Segment [Member] | Scenario Plan [Member]
Long Lived Assets Held For Sale [Line Items]
Proceeds from asset dispositions	$ 350
Investment Owned, Percent of Net Assets									30.00%

Acquisition (Details)

Acquisition (Details) - Alaska Segment [Member] - Operating Segments [Member] - USD ($) $ in Millions	3 Months Ended
	Jun. 30, 2018	Jul. 31, 2018
Interest In WNS Assets and Alpine Pipeline [Member]
Business Acquisition [Line Items]
Costs Incurred, Acquisition of Oil and Gas Properties	$ 386
Percent Acquired	22.00%
Interest In Greater Kuparuk Area [Member] | Scenario Plan [Member]
Business Acquisition [Line Items]
Percent Acquired		39.20%
Interest In Kuparuk Transportation Co [Member] | Scenario Plan [Member]
Business Acquisition [Line Items]
Percent Acquired		38.00%

Investments, Loans and Long-T_2

Investments, Loans and Long-Term Receivables (Details) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Equity method investments
Loan balance with affiliated company	$ 464		$ 586
APLNG [Member]
Equity method investments
Line of Credit Facility, Maximum Borrowing Capacity	8,500
Line Of Credit Facility Value Outstanding	7,200
Book value of equity method investment	7,676
Non Cash Impairment of Equity Investment Other than Temporary		$ 2,384
APLNG [Member] | Export-Import Bank of the US [Member]
Equity method investments
Line of Credit Facility, Maximum Borrowing Capacity	2,900
APLNG [Member] | Export-Import Bank of China [Member]
Equity method investments
Line of Credit Facility, Maximum Borrowing Capacity	2,700
Early Repayment of Senior Debt	1,400
APLNG [Member] | Australian and International Commercial Bank Syndicate [Member]
Equity method investments
Line of Credit Facility, Maximum Borrowing Capacity	2,900
APLNG [Member] | U S Private Placement Bond [Member]
Equity method investments
Line of Credit Facility, Maximum Borrowing Capacity	1,400
QG3 [Member]
Equity method investments
Loan balance with affiliated company	$ 461

Investment in Cenovus Energy (D

Investment in Cenovus Energy (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended	5 Months Ended	9 Months Ended
	Sep. 30, 2018	May 17, 2017	Sep. 30, 2018	Jan. 01, 2018	Dec. 31, 2017
Schedule Of Available For Sale Securities [Line Items]
Investment in Cenovus Energy	$ 2,086		$ 2,086		$ 1,899
Accumulated Other Comprehensive Income , Net of Tax	(5,442)		(5,442)		(5,518)
Adjustments for New Accounting Pronouncement [Member]
Schedule Of Available For Sale Securities [Line Items]
Accumulated Other Comprehensive Income , Net of Tax				$ (5,460)	(5,518)
Common Stock [Member]
Schedule Of Available For Sale Securities [Line Items]
Ivnestment in Equity Security Cost		$ 1,960
Common Stock [Member] | Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member]
Schedule Of Available For Sale Securities [Line Items]
Shares Exchange for Assets Held for Sale		208
Investment Owned, Common Stock, percent of Issued and Outstanding		16.90%
Investment In Equity Security Fair Value	2,090	$ 1,960	$ 2,090		$ 1,900
Investment Owned, Common Stock, price per share		$ 9.41	$ 10.03
Unrealized Gain (Loss) on Securities	$ (73)		$ 187
Common Stock [Member] | ASU 2016-01 Accounting for Cenovus Shares [Member] | Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member]
Schedule Of Available For Sale Securities [Line Items]
Accumulated Other Comprehensive Income , Net of Tax				$ (58)

Suspended Wells and Wells in _2

Suspended Wells and Wells in Progress (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Suspended Wells [Abstract]
Capitalized cost of suspended wells	$ 986	$ 853
Increase (decrease) in capitalized cost of suspended wells	$ 133
Number of wells charged to dry hole expense	3
Capitalized Exploratory Well Cost, Charged to Dry Hole Expense	$ 7

Impairments (Details)

Impairments (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 44	$ 6	$ 21	$ 6,475
Alaska [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	0	1	0	178
Lower 48 [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	44	3	55	3,888
Canada | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	0	0	0	18
Europe and North Africa [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	0	2	(48)	7
Asia Pacific and Middle East [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 0	$ 0	$ 14	$ 2,384

Impairments Narrative (Details)

Impairments Narrative (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017		Sep. 30, 2018	Sep. 30, 2017
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 44	$ 6		$ 21	$ 6,475
Exploration Expense	$ 103	$ 73	[1],[2]	267	720	[1],[2]
Alaska Segment [Member] | Operating Segments [Member] | Point Thomson [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges					174
Lower Forty Eight Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges				55
Lower Forty Eight Segment [Member] | Operating Segments [Member] | Barnett [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges					600
Lower Forty Eight Segment [Member] | Operating Segments [Member] | San Juan Properties [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges					3,300
Lower Forty Eight Segment [Member] | Operating Segments [Member] | GOM | Shenandoah [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense					$ 51
Europe and North Africa Segment [Member] | Operating Segments [Member] | UK Field [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges				$ 49
[1]	*Certain amounts have been reclassified to conform to the current-period presentation resulting from the adoption of ASU No. 2017-07.
[2]	See Note 2—Changes in Accounting Principles, for additional information.

Debt Narrative (Details)

Debt Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended	9 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Jun. 30, 2018	Sep. 30, 2018	Sep. 30, 2017	May 21, 2018	May 20, 2018
Short Term Debt [Line Items]
Commercial Paper Program, Amount Outstanding				$ 275
Debt Instrument [Line Items]
Repayments of Debt				4,970	$ 6,594
Revolving Credit Facility [Member]
Short Term Debt [Line Items]
Maximum borrowing capactiy under revolving credit facility						$ 6,000	$ 6,750
Remaining borrowing capacity under revolving credit facility				6,000
Letter of Credit [Member]
Short Term Debt [Line Items]
Commercial Paper Program, Amount Outstanding				0
Minimum Limit of Debt for Cross Default Provision				200
Letter of Credit [Member] | Maximum [Member]
Short Term Debt [Line Items]
Maximum borrowing capactiy under revolving credit facility				500
Commercial Paper [Member]
Short Term Debt [Line Items]
Commercial Paper Program, Amount Outstanding				0
Unsecured Debt [Member]
Debt Instrument [Line Items]
Repayments of Debt	$ 1,800	$ 2,650
Premiums paid above book value to redeem debt			$ 208
Unsecured Debt [Member] | 9.125% Debentures [Member] | Due 2021 [Member]
Debt Instrument [Line Items]
Repayments of Debt		27
Unsecured Debt [Member] | 2.2% Notes [Member] | Due 2020 [Member]
Debt Instrument [Line Items]
Repayments of Debt		500
Unsecured Debt [Member] | 4.2% Notes [Member] | Due 2021 [Member]
Debt Instrument [Line Items]
Repayments of Debt		1,000
Unsecured Debt [Member] | 2.875% Notes [Member] | Due 2021 [Member]
Debt Instrument [Line Items]
Repayments of Debt		750
Unsecured Debt [Member] | 8.20% Debentures [Member] | Due 2025 [Member]
Debt Instrument [Line Items]
Repayments of Debt		16
Unsecured Debt [Member] | 8.125% Notes [Member] | Due 2030 [Member]
Debt Instrument [Line Items]
Repayments of Debt		210
Unsecured Debt [Member] | 7.9% Debentures [Member] | Due 2047 [Member]
Debt Instrument [Line Items]
Repayments of Debt		40
Unsecured Debt [Member] | 7.65% Debentures [Member] | Due 2023 [Member]
Debt Instrument [Line Items]
Repayments of Debt		10
Unsecured Debt [Member] | 7.8% Debentures [Member] | Due 2027 [Member]
Debt Instrument [Line Items]
Repayments of Debt		$ 97
Unsecured Debt [Member] | 2.4% Notes [Member] | Due 2022 [Member]
Debt Instrument [Line Items]
Repayments of Debt	671
Unsecured Debt [Member] | 3.35% Notes [Member] | Due 2024 [Member]
Debt Instrument [Line Items]
Repayments of Debt	574
Unsecured Debt [Member] | 3.35% Notes [Member] | Due 2025 [Member]
Debt Instrument [Line Items]
Repayments of Debt	301
Unsecured Debt [Member] | 4.15 % Notes [Member] | Due 2034 [Member]
Debt Instrument [Line Items]
Repayments of Debt	254
VRDB [Member]
Debt Instrument [Line Items]
Debt Instrument Face Amount				$ 283
Floating Rate Notes [Member] | Floating rate note due 2018 [Member] | Due 2018 [Member]
Debt Instrument [Line Items]
Repayments of Debt	$ 250
ConocoPhillips Commercial Paper Program [Member] | Commercial Paper [Member]
Short Term Debt [Line Items]
Maturity period of commercial paper (in days)				90
Commercial Paper Program, Capacity				$ 6,000
Commercial Paper Program, Amount Outstanding				$ 0

Noncontrolling Interests (Detai

Noncontrolling Interests (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Activity for equity attributable to noncontrolling interests
Beginning Balance				$ 30,801	$ 35,226
Net income (loss)		$ 1,873	$ 436	4,427	(2,391)
Dividends paid				(1,009)	(986)
Repurchase of company common stock				(2,073)	(2,045)
Distributions to noncontrolling interests				(105)	(84)
Other	[1]			258	992
Ending Balance		32,079	30,712	32,079	30,712
Adjustments for New Accounting Pronouncement [Member]
Activity for equity attributable to noncontrolling interests
Beginning Balance				30,801
Accounting Standards Update 2014-09 [Member]
Activity for equity attributable to noncontrolling interests
Change in Accounting Principle	[2]			(220)
Common Stockholders' Equity [Member]
Activity for equity attributable to noncontrolling interests
Beginning Balance				30,607	34,974
Net income (loss)				4,389	(2,434)
Dividends paid				(1,009)	(986)
Repurchase of company common stock				(2,073)	(2,045)
Distributions to noncontrolling interests				0	0
Other	[1]			256	991
Ending Balance		31,950	30,500	31,950	30,500
Common Stockholders' Equity [Member] | Accounting Standards Update 2014-09 [Member]
Activity for equity attributable to noncontrolling interests
Change in Accounting Principle	[2]			(220)
Noncontrolling Interest [Member]
Activity for equity attributable to noncontrolling interests
Beginning Balance				194	252
Net income (loss)				38	43
Dividends paid				0	0
Repurchase of company common stock				0	0
Distributions to noncontrolling interests				(105)	(84)
Other	[1]			2	1
Ending Balance		$ 129	$ 212	129	$ 212
Noncontrolling Interest [Member] | Accounting Standards Update 2014-09 [Member]
Activity for equity attributable to noncontrolling interests
Change in Accounting Principle	[2]			$ 0
[1]	**Includes components of other comprehensive income, which are disclosed separately in our Consolidated Statement of Comprehensive Income.
[2]	*See Note 2—Changes in Accounting Principles for additional information related to ASC Topic 606.

Guarantees (Details)

Guarantees (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Continued development [Member] | Australia Pacific APLNG [Member]
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	$ 140
Terms of guarantees outstanding	up to 27 years or the life of the venture
Other Guarantees [Member]
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	$ 780
Terms of guarantees outstanding	up to four years
Indemnifications [Member]
Guarantor Obligations [Line Items]
Environmental accruals for known contamination in carrying amount recorded for indemnifications	$ 40
Guarantor Obligations, Current Carrying Value	$ 100
Indemnifications [Member] | Refinery Supplier [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Current Carrying Value		$ 98
Carrying value of indemnification asset from other party		$ 98
Guarantee existing sales agreement of natural gas delivery | Australia Pacific APLNG [Member]
Guarantor Obligations [Line Items]
Terms of guarantees outstanding	up to 24 years
Max potential future payments-reckless breach [Member] | Australia Pacific APLNG [Member]
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	$ 1,580
Max potential future payments-prorata share [Member] | Australia Pacific APLNG [Member]
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	$ 940
Finance Reserve Guarantee [Member] | Australia Pacific APLNG [Member]
Guarantor Obligations [Line Items]
Ownership percentage in equity investment	37.50%
Maximum potential amount of future payments	$ 170
Terms of guarantees outstanding	12 years
Carrying value of indemnification asset from other party	$ 14

Contingencies and Commitments (

Contingencies and Commitments (Details) - USD ($)	1 Months Ended				3 Months Ended		9 Months Ended
	Aug. 31, 2018	Jul. 31, 2018	Apr. 30, 2018	Feb. 28, 2017	Sep. 30, 2018	Jun. 30, 2018	Sep. 30, 2018	Apr. 13, 2018	Dec. 31, 2017	Dec. 01, 2017
Loss Contingencies [Line Items]
Loss Contingency, Settlement Agreement, Terms							30 years
Letters of Credit Outstanding, Amount					$ 275,000,000		$ 275,000,000
Burlington Resources Inc Vs The Republic Of Ecuador [Member]
Loss Contingencies [Line Items]
Cash Proceeds from Legal Settlements						$ 262,000,000
Conoco Phillips Vs Petroleos de Venezuela SA [Member]
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party			$ 2,000,000,000
Initial Litigation Settlement Amount Awarded From Other Party		$ 1,930,000,000
Total Proceeds From Legal Settlement					345,000,000
Cash Proceeds from Legal Settlements					103,000,000
Inventory Received For Settlement					242,000,000
Initial Settlement Agreement Payment Terms							90 days from the timing of signing
Remaining Settlement Agreement Payment Terms							paid quarterly over a period of four and a half years
Initial Payment received related to legal settlement	$ 500,000,000
ECUADOR | Burlington Resources Inc Vs The Republic Of Ecuador [Member] | Burlington Resources, Inc [Member]
Loss Contingencies [Line Items]
Litigation Settlement Amount Awarded To Other Party				$ 380,000,000
Litigation Settlement, Amount Awarded from Other Party				42,000,000
Settlement Amount Awarded To Other Party Through Third Party									$ 337,000,000
Settlement Amount Received By Other Party								$ 262,000,000		$ 75,000,000
Offset For Counter Claim				$ 24,000,000
U.S. and Canada | Cleanup Remediation Activities [Member]
Loss Contingencies [Line Items]
Total environmental accrual included in balance sheet					$ 170,000,000		$ 170,000,000		$ 180,000,000

Derivative and Financial Inst_3

Derivative and Financial Instruments - Commodity Balance Sheet (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	$ 259	$ 275
Other assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	42	36
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	278	282
Other liabilities and deferred credits [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	$ 37	$ 28

Derivative and Financial Inst_4

Derivative and Financial Instruments - Commodity GainLoss (Details) - Commodity Contract [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Sales and other operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ (29)	$ 17	$ (6)	$ 120
Other Income [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	3	(1)	12	(1)
Purchased commodities [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ 18	$ (19)	$ 15	$ (88)

Derivative and Financial Inst_5

Derivative and Financial Instruments - Commodity Notional (Details) - Commodity Contract [Member] - Bcfe	Sep. 30, 2018	Dec. 31, 2017
Natural gas and power, Fixed price [Member] | Short [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	19	29
Natural gas and power, Basis [Member] | Long [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	5	12

Derivative and Financial Inst_6

Derivative and Financial Instruments - FX Balance Sheet (Details) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Description of Foreign Currency Derivative Instruments Not Designated as Hedging Instruments Activities	In December 2017, we entered into foreign exchange zero cost collars buying the right to sell $1.25 billion CAD at $0.707 CAD and selling the right to buy $1.25 billion CAD at $0.842 CAD against the U.S. dollar.
Prepaid Expenses and Other Current Assets [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	$ 18	$ 1
Other Assets [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	0	6
Other Accruals [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative liabilities	7	0
Other liabilities and deferred credits [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative liabilities	$ 0	$ 15

Derivative and Financial Inst_7

Derivative and Financial Instruments - FX GainLoss (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Foreign currency transaction gains (losses) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Foreign currency transaction (gains) losses	$ (2)	$ (1)	$ (5)	$ 2

Derivative and Financial Inst_8

Derivative and Financial Instruments - FX Notional (Details) - USD ($) $ in Millions	Sep. 30, 2018		Dec. 31, 2017
Sell US Dollar Buy Other Currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	$ 1,258	[1]	$ 0
Sell British pound, buy other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	23		1
Sell Canadian dollar, buy U.S. dollar [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	$ 1,230		$ 1,225
[1]	(1)Primarily British pound.

Derivative and Financial Inst_9

Derivative and Financial Instruments - Financial Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	$ 3,716	$ 6,325
Short-term Investments	875	1,873
Cash [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	511	948
Time Deposits [Member] | Remaining maturities from 1 to 90 days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	2,966	5,004
Short-term Investments	104	821
Commercial Paper [Member] | Remaining maturities from 1 to 90 days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	239	373
Short-term Investments	771	978
Commercial Paper [Member] | Remaining maturities from 91 to 180 days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	0	0
Short-term Investments	$ 0	$ 74

Derivative and Financial Ins_10

Derivative and Financial Instruments - Credit Risk (Details Textual) - USD ($)	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Aggregate fair value of all derivative instruments in a liability position	$ 44,000,000	$ 55,000,000
Collateral was posted for derivative instruments in a liability position	0	$ 0
Additional collateral, either in the form of cash or letters of credit	$ 44,000,000
Trade receivables [Member] | Maximum [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) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	$ 2,086	$ 1,899
Commodity derivative asset, gross	$ 301	311
Fair Value, Assets, Level 2 to Level 1 Transfers, Description	At the end of the fourth quarter of 2017, our investment in Cenovus Energy transferred from Level 2 to Level 1 due to the lapsing of trading restrictions.
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	$ 2,086	1,899
Commodity derivative asset, gross	301	311
Total assets	2,387	2,210
Commodity derivative liability, gross	315	310
Total liabilities	315	310
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	2,086	1,899
Commodity derivative asset, gross	186	175
Total assets	2,272	2,074
Commodity derivative liability, gross	176	158
Total liabilities	176	158
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	0
Commodity derivative asset, gross	97	106
Total assets	97	106
Commodity derivative liability, gross	103	111
Total liabilities	103	111
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	0
Commodity derivative asset, gross	18	30
Total assets	18	30
Commodity derivative liability, gross	36	41
Total liabilities	$ 36	$ 41

Fair Value Measurement - FV of

Fair Value Measurement - FV of Commodity Derivatives (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Offsetting Derivative Assets [Abstract]
Assets - gross amounts recognized	$ 301	$ 311
Assets - gross amounts offset	206	186
Assets - net amounts presented	95	125
Assets - cash collateral	0	0
Assets - amounts without right of setoff	7	4
Assets - net amounts	88	121
Offsetting Derivative Liabilities [Abstract]
Liabilities - gross amounts recognized	315	310
Liabilities - gross amounts offset	206	186
Liabilities - net amounts presented	109	124
Liabilities - cash collateral	2	7
Liabilities - amounts without right of setoff	3	5
Liabilities - net amounts	$ 104	$ 112

Fair Value Measurement - Nonrec

Fair Value Measurement - Nonrecurring (Details) - Fair Value Measurements Nonrecurring [Member] - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2018	Mar. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for sale)	$ 201	$ 250
Before Tax Loss Net PPE (held for sale)	43	44
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)	201	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	$ 250

Fair Value Measurement - FV o_2

Fair Value Measurement - FV of Financial Instruments (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Carrying Amount [Member]
Financial Assets [Abstract]
Investment in Cenovus Energy	$ 2,086	$ 1,899
Total loans and advances - related parties	464	586
Financial Liabilities [Abstract]
Total debt, excluding capital leases	14,201	18,929
Carrying Amount [Member] | Commodity Contract [Member]
Financial Assets [Abstract]
Commodity derivatives, assets	95	125
Financial Liabilities [Abstract]
Commodity derivatives, liability	107	117
Investment in Cenovus Energy	2,086	1,899
Commodity derivatives, assets	95	125
Total loans and advances - related parties	464	586
Total debt, excluding capital leases	16,554	22,435
Commodity derivatives, liability	104	112
Commodity Contract [Member]
Financial Assets [Abstract]
Commodity derivatives, assets	95	125
Financial Liabilities [Abstract]
Commodity derivatives, liability	$ 107	$ 117

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Defined Benefit Plans, Beginning Balance			$ (400)
Defined Benefit Plans	$ (136)	$ (35)	(240)	$ (99)
Defined Benefit Plans, Ending Balance	(160)		(160)
Investment in Equity Securities, Begninng Balance			(58)
Unrealized holding gain (loss) on securities	0	551	0	127
Investment in Equity Securities, Ending Balance	0		0
Foreign Currency Translation, Beginning Balance			(5,060)
Foreign Currency Translation	59	509	(222)	720
Foreign Currency Translation, Ending Balance	(5,282)		(5,282)
Accumulated Other Comprehensive Income, Beginning Balance			(5,518)
Other Comprehensive Income (Loss), Net of Tax	195	$ 1,050	18	$ 901
Accumulated Other Comprehensive Income, Ending Balance	$ (5,442)		(5,442)
Adjustments for New Accounting Pronouncement [Member]
Accumulated Other Comprehensive Income, Beginning Balance			(5,518)
ASU 2016-01 Accounting for Cenovus Shares [Member]
Cumulative effect of adopting ASU No. 2016-01			58
ASU 2016-01 Accounting for Cenovus Shares [Member] | Restatement Adjustment [Member]
Unrealized holding gain (loss) on securities			$ 58

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) - Reclassifications (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Defined Benefit Plans	$ 17	$ 26	$ 155	$ 116
Tax expense of defined benefit plans	$ 6	$ 14	$ 43	$ 61

Cash Flow Information (Details)

Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Interest	$ 584	$ 918
Income taxes	1,927	574
Net Purchases of Short-Term Investments
Short-term investments purchased	(1,705)	(4,999)
Short-term investments sold	2,701	2,416
Net sale (purchases) of short-term investments	$ 996	$ (2,583)

Cash Flow Information - Textual

Cash Flow Information - Textual (Details) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2017
Burlington Resources Inc Vs The Republic Of Ecuador [Member]
Loss Contingencies [Line Items]
Cash Proceeds from Legal Settlements		$ 262
Conoco Phillips Vs Petroleos de Venezuela SA [Member]
Loss Contingencies [Line Items]
Cash Proceeds from Legal Settlements	$ 103
Currency Swap [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Payments for Foreign Currency Derivative Instruments Not Designated as Hedging Instruments			$ 180

Employee Benefit Plans - Compon

Employee Benefit Plans - Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Pension Plans Defined Benefit [Member] | U.S.
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	$ 20	$ 21	$ 63	$ 67
Interest cost	22	29	76	90
Expected return on plan assets	(22)	(32)	(91)	(97)
Amortization of prior service cost (credit)	0	1	0	3
Recognized net actuarial (gain) loss	10	17	41	53
Settlements	14	21	161	118
Curtailments (gain) loss	0	0	0	0
Net periodic benefit cost	44	57	250	234
Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	20	20	63	59
Interest cost	26	27	80	78
Expected return on plan assets	(38)	(41)	(118)	(119)
Amortization of prior service cost (credit)	(1)	(1)	(4)	(4)
Recognized net actuarial (gain) loss	9	12	27	36
Settlements	0	0	0	0
Curtailments (gain) loss	(1)	0	(1)	0
Net periodic benefit cost	15	17	47	50
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Service cost	0	0	1	1
Interest cost	2	3	6	7
Expected return on plan assets	0	0	0	0
Amortization of prior service cost (credit)	(9)	(9)	(26)	(27)
Recognized net actuarial (gain) loss	0	(1)	(1)	(2)
Settlements	0	0	0	0
Curtailments (gain) loss	0	0	0	0
Net periodic benefit cost	$ (7)	$ (7)	$ (20)	$ (21)

Employee Benefit Plans - Textua

Employee Benefit Plans - Textual (Details) - USD ($)	1 Months Ended	3 Months Ended			9 Months Ended
	Jun. 30, 2018	Sep. 30, 2018	Jun. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017	Dec. 01, 2017
Employee Benefit Plans (Textual) [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax		$ 187,000,000		$ 13,000,000	$ 145,000,000	$ (26,000,000)
U.S.
Employee Benefit Plans (Textual) [Abstract]
Company contributions					150,000,000
Expected company contributions		160,000,000			160,000,000
U.S. | Qualified Plan [Member]
Employee Benefit Plans (Textual) [Abstract]
Pension settlement expense		14,000,000			161,000,000
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax			$ 42,000,000
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	4.20%		4.20%					3.60%
U.S. | Qualified Plan [Member] | Prudential Benefit Obligation [Member]
Employee Benefit Plans (Textual) [Abstract]
Change In Defined Benefit Assets	$ 700,000,000
Change In Defined Benefit Obligation	$ 700,000,000
Int'l (Pension Benefits) [Member]
Employee Benefit Plans (Textual) [Abstract]
Company contributions					130,000,000
Expected company contributions		160,000,000			$ 160,000,000
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax		$ (157,000,000)
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate		2.95%			2.95%		2.55%
Int'l (Pension Benefits) [Member] | Qualified Plan [Member]
Employee Benefit Plans (Textual) [Abstract]
Reclassification of Pension Liability		$ 146,000,000			$ 146,000,000

Employee Benefit Plans - Severa

Employee Benefit Plans - Severances (Details) - Employee Severance [Member] - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2018
Restructuring Cost and Reserve [Line Items]
Balance at begninning of period		$ 53
Increase (Decrease) in Restructuring Reserve	$ 35	65
Payments for Restructuring		38
Restructuring Reserve, Foreign Currency Translation Gain (Loss)		0
Balance at end of period	80	80
Short term supplemental unemployment benefits [Member]
Restructuring Cost and Reserve [Line Items]
Balance at end of period	$ 55	$ 55

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Significant transactions with related parties
Related Party Revenue	$ 27,000,000	$ 24,000,000	$ 74,000,000	$ 83,000,000
Related Party Purchases	25,000,000	26,000,000	74,000,000	74,000,000
Operating expenses and selling, general and administrative expenses	13,000,000	16,000,000	44,000,000	42,000,000
Net interest income	$ (4,000,000)	$ (4,000,000)	$ (11,000,000)	$ (10,000,000)

Sales and Other Operating Rev_3

Sales and Other Operating Revenue - Transitional Arrangements (Details) - Accounting Standards Update 2014-09 [Member] - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2018	Dec. 31, 2017	Dec. 31, 2015	Dec. 31, 2011
Contract with Customer, Timing of Satisfaction of Performance Obligation and Payment	We have entered into contractual arrangements where we license proprietary technology to customers related to the optimization process for operating LNG plants. The agreements typically provide for negotiated payments to be made at stated milestones. The payments are not directly related to our performance under the contract and are recorded as deferred revenue to be recognized as revenue when the customer can utilize and benefit from their right to use the license. Payments are received in installments over the construction period.
Revenue, Initial Application Period Cumulative Effect Transition, Description	The cumulative effect of applying the standard relates solely to certain licensing arrangements where revenue was previously recognized ($61 million in 2011, $146 million in 2015, and $44 million in 2017) based on contractual milestones. Under ASC Topic 606, such revenues are recognized when the customer has the ability to utilize and benefit from its right to use the license. As a result, such historically recognized revenues must be reversed through a cumulative effect adjustment and deferred until such time when the customer has the ability to utilize and benefit from the license. The cumulative effect adjustment relates to contracts that were not substantially completed at the date of implementation.
Difference between Revenue Guidance in Effect before and after Topic 606 [Member]
Revenue Recognition, Milestone Method, Revenue Recognized		$ 44	$ 146	$ 61

Sales and Other Operating Rev_4

Sales and Other Operating Revenue - Practical Expedients (Details)	9 Months Ended
	Sep. 30, 2018
Revenue, Practical Expedient [Abstract]
Revenue, Practical Expedient, Remaining Performance Obligation, Description	Typically, our commodity sales contracts are less than 12 months in duration; however, certain commodity sales contracts may carry a longer duration, which may extend to the end of field life. We have long-term commodity sales contracts which use prevailing market prices at the time of delivery, and under these contracts, the market-based variable consideration for each performance obligation (i.e., delivery of commodity) is allocated to each wholly unsatisfied performance obligation within the contract. Accordingly, we have applied the practical expedient allowed in ASC Topic 606 and do not disclose the aggregate amount of the transaction price allocated to performance obligations or when we expect to recognize revenues that are unsatisfied (or partially unsatisfied) as of the end of the reporting period.

Sales and Other Operating Rev_5

Sales and Other Operating Revenue - Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017		Sep. 30, 2018	Sep. 30, 2017
Revenue from contracts with customers	$ 9,449	$ 6,688		$ 26,751	$ 20,987
Revenue, Performance Obligation, Description of Payment Terms				We typically receive payment within 30 days or less (depending on the terms of the invoice) once delivery is made.
Physical gas contracts [Member]
Revenue from contracts with customers	1,897	2,050	[1]	$ 5,877	6,631	[1]
Crude oil product line [Member]
Revenue from contracts with customers	267	171	[1]	843	530	[1]
Natural Gas Product Line [Member]
Revenue from contracts with customers	1,522	1,811	[1]	4,775	5,870	[1]
Other Products [Member]
Revenue from contracts with customers	108	68	[1]	259	231	[1]
Financial Derivative Contracts [Member]
Revenue from contracts with customers	6	2	[1]	40	(72)	[1]
Lower 48 Segment | Physical gas contracts [Member]
Revenue from contracts with customers	1,534	1,563	[1]	4,547	4,834	[1]
Canada Segment [Member] | Physical gas contracts [Member]
Revenue from contracts with customers	87	161	[1]	374	680	[1]
Europe and North Africa Segment [Member] | Physical gas contracts [Member]
Revenue from contracts with customers	276	326	[1]	956	1,117	[1]
Accounting Standards Update 2014-09 [Member]
Revenue from contracts with customers	$ 7,546	$ 4,636	[1]	$ 20,834	$ 14,428	[1]
Revenue, Performance Obligation, Description of Payment Terms				We typically receive payment within 30 days or less (depending on the terms of the invoice)
[1]	*Under the modified retrospective approach, prior period amounts have not been adjusted upon adoption of ASC Topic 606.

Sales and Other Operating Rev_6

Sales and Other Operating Revenue - Receivables and Contract LIabilities (Details) - USD ($)		3 Months Ended	9 Months Ended
		Sep. 30, 2018	Sep. 30, 2018	Dec. 31, 2017
Revenue, Performance Obligation, Description of Payment Terms			We typically receive payment within 30 days or less (depending on the terms of the invoice) once delivery is made.
Contract with Customer, Liability [Abstract]
Contract with Customer, Liability Beginning Balance			$ 251,000,000
Contract with Customer, Liability, Cash Received	[1]		(81,000,000)
Contract with Customer, Liability, Revenue Recognized		$ (73,000,000)	(148,000,000)
Contract with Customer, Liability Ending Balance		184,000,000	184,000,000
Change in Contract with Customer, Liability [Abstract]
Contract with Customer, Liability, Revenue Recognized		$ 73,000,000	148,000,000
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Explanation		For the three- and nine-month periods of 2018, we recognized revenue of $73 million and $148 million, respectively, in the “Sales and other operating revenues” line on our consolidated income statement. We expect to recognize the contract liabilities as of September 30, 2018, as revenue between the remainder of 2018 and 2022 as construction is completed.
Short-term Contract with Customer [Member]
Contract with Customer, Liability [Abstract]
Contract with Customer, Liability Ending Balance		$ 147,000,000	147,000,000
Long-term Contract with Customer [Member]
Contract with Customer, Liability [Abstract]
Contract with Customer, Liability Ending Balance		37,000,000	37,000,000
Accounting Standards Update 2014-09 [Member]
Accounts Receivable, Net		$ 3,129,000,000	$ 3,129,000,000	$ 2,675,000,000
Revenue, Performance Obligation, Description of Payment Terms			We typically receive payment within 30 days or less (depending on the terms of the invoice)
Revenue, Performance Obligation, Description of Timing			once delivery is made.
Contract with Customer, Timing of Satisfaction of Performance Obligation and Payment		We have entered into contractual arrangements where we license proprietary technology to customers related to the optimization process for operating LNG plants. The agreements typically provide for negotiated payments to be made at stated milestones. The payments are not directly related to our performance under the contract and are recorded as deferred revenue to be recognized as revenue when the customer can utilize and benefit from their right to use the license. Payments are received in installments over the construction period.
[1]	*Includes $14 million and $81 million for the three- and nine-month periods of 2018, respectively.

Segment Disclosures and Relat_3

Segment Disclosures and Related Information - Sales (Details) - USD ($)		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Segment Reporting Information [Line Items]
Sales and other operating revenues		$ 9,449,000,000	$ 6,688,000,000	$ 26,751,000,000	$ 20,987,000,000
Natural Gas [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		2,503,000,000	2,496,000,000	7,593,000,000	7,949,000,000
Natural Gas Liquids Reserves [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		351,000,000	238,000,000	847,000,000	745,000,000
Crude Oil [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		5,277,000,000	2,947,000,000	14,503,000,000	9,387,000,000
Other Products [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,318,000,000	1,007,000,000	3,808,000,000	2,906,000,000
U.S.
Segment Reporting Information [Line Items]
Sales and other operating revenues		6,025,000,000	4,038,000,000	16,617,000,000	12,440,000,000
Australia
Segment Reporting Information [Line Items]
Sales and other operating revenues		515,000,000	323,000,000	1,258,000,000	1,050,000,000
Canada
Segment Reporting Information [Line Items]
Sales and other operating revenues		427,000,000	544,000,000	1,583,000,000	2,027,000,000
China
Segment Reporting Information [Line Items]
Sales and other operating revenues		262,000,000	148,000,000	616,000,000	511,000,000
Indonesia
Segment Reporting Information [Line Items]
Sales and other operating revenues		234,000,000	191,000,000	662,000,000	554,000,000
Malaysia
Segment Reporting Information [Line Items]
Sales and other operating revenues		339,000,000	297,000,000	1,039,000,000	768,000,000
Norway
Segment Reporting Information [Line Items]
Sales and other operating revenues		734,000,000	583,000,000	2,112,000,000	1,751,000,000
United Kingdom
Segment Reporting Information [Line Items]
Sales and other operating revenues		574,000,000	437,000,000	1,911,000,000	1,498,000,000
Libya
Segment Reporting Information [Line Items]
Sales and other operating revenues	[1]	264,000,000	91,000,000	802,000,000	315,000,000
Other Non US Countries
Segment Reporting Information [Line Items]
Sales and other operating revenues		75,000,000	36,000,000	151,000,000	73,000,000
Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		9,449,000,000	6,688,000,000	26,751,000,000	20,987,000,000
Alaska [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,493,000,000	932,000,000	4,281,000,000	3,010,000,000
Lower 48 [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		4,543,000,000	3,102,000,000	12,347,000,000	9,422,000,000
Lower 48 [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		4,529,000,000	3,100,000,000	12,329,000,000	9,415,000,000
Lower 48 [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		(14,000,000)	(2,000,000)	(18,000,000)	(7,000,000)
Canada
Segment Reporting Information [Line Items]
Sales and other operating revenues		735,000,000	699,000,000	2,436,000,000	2,357,000,000
Canada | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		427,000,000	544,000,000	1,583,000,000	2,027,000,000
Canada | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		(308,000,000)	(155,000,000)	(853,000,000)	(330,000,000)
Europe and North Africa [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,574,000,000	1,110,000,000	4,826,000,000	3,564,000,000
Asia Pacific and Middle East [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		1,348,000,000	959,000,000	3,570,000,000	2,877,000,000
Corporate and Other [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Sales and other operating revenues		$ 78,000,000	$ 43,000,000	$ 162,000,000	$ 94,000,000
[1]	Included in "Other foreign countries" in prior periods

Segment Disclosures and Relat_4

Segment Disclosures and Related Information - Net Income (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Net Income (Loss) Attributable to ConocoPhillips [Abstract]
Consolidated net income (loss) attributable to ConocoPhillips	$ 1,861	$ 420	$ 4,389	$ (2,434)
Assets [Abstract]
Assets	70,556		70,556		$ 73,362
Alaska [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips [Abstract]
Consolidated net income (loss) attributable to ConocoPhillips	427	103	1,369	291
Assets [Abstract]
Assets	12,688		12,688		12,108
Lower 48 [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips [Abstract]
Consolidated net income (loss) attributable to ConocoPhillips	513	(97)	1,231	(2,995)
Assets [Abstract]
Assets	15,308		15,308		14,632
Canada [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips [Abstract]
Consolidated net income (loss) attributable to ConocoPhillips	34	280	2	2,607
Assets [Abstract]
Assets	5,950		5,950		6,214
Europe and North Africa [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips [Abstract]
Consolidated net income (loss) attributable to ConocoPhillips	241	85	776	379
Assets [Abstract]
Assets	11,895		11,895		11,870
Asia Pacific and Middle East [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips [Abstract]
Consolidated net income (loss) attributable to ConocoPhillips	577	396	1,504	(1,540)
Assets [Abstract]
Assets	16,611		16,611		16,985
Other International [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips [Abstract]
Consolidated net income (loss) attributable to ConocoPhillips	316	(20)	267	(77)
Assets [Abstract]
Assets	315		315		97
Corporate and Other [Member] | Corporate, Non-Segment [Member]
Net Income (Loss) Attributable to ConocoPhillips [Abstract]
Consolidated net income (loss) attributable to ConocoPhillips	(247)	$ (327)	(760)	$ (1,099)
Assets [Abstract]
Assets	$ 7,789		$ 7,789		$ 11,456

Segment Disclosures - Textual (

Segment Disclosures - Textual (Details)	3 Months Ended
	Sep. 30, 2018
Segment Disclosures and Related Information [Abstract]
Number of Operating Segments	6

Segment Disclosures and Relat_5

Segment Disclosures and Related Information - Assets (Details) - USD ($) $ in Millions	Sep. 30, 2018	Dec. 31, 2017
Assets [Abstract]
Consolidated total assets	$ 70,556	$ 73,362

Income Taxes (Details)

Income Taxes (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Income Taxes (Textual) [Abstract]
Effective tax rate	35.50%	33.20%	39.40%	39.30%

Income Taxes - Rate Reconciliat

Income Taxes - Rate Reconciliation (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Effective Income Tax Rate Reconciliation, Amount [Abstract]
Income (loss) before taxes - United States	$ 893	$ (197)	$ 2,799	$ (5,259)
Income Loss Before Income Taxes Foreign	2,013	850	4,502	1,319
Income (Loss) before income taxes	2,906	653	7,301	(3,940)
Federal Statutory Income Tax Rate, Amount	610	228	1,533	(1,379)
Non-U.S. effective tax rates	479	137	1,339	503
Canada disposition	0	(8)	0	(1,176)
Recovery of outside basis	(16)	(118)	(19)	(957)
Adjustment to tax reserves, amount	(3)	(17)	2	764
Adjustment to valuation allowances	(29)	0	13	24
APLNG impairment	0	0	0	834
State Income Taxes	38	14	83	(98)
Enhanded oil recovery credit	(36)	(5)	(73)	(49)
Other Reconciling Items	(10)	(14)	(4)	(15)
Income Tax Expense (Benefit)	$ 1,033	$ 217	$ 2,874	$ (1,549)
Effective Income Tax Rate Continuing Operations Tax Rate Reconciliation Abstract
Income (Loss) Before Income Taxes Domestic Percentage	30.70%	(30.20%)	38.30%	133.50%
Income (Loss) Before Income Taxes Foreign Percentage	69.30%	130.20%	61.70%	(33.50%)
Income (Loss) Before Income Taxes In Percent	100.00%	100.00%	100.00%	100.00%
Federal statutory rate percentage	21.00%	35.00%	21.00%	35.00%
Non US effective tax rates percentage	16.50%	21.00%	18.30%	(12.80%)
Canada disposition, percentage	0.00%	(1.20%)	0.00%	29.80%
Recovery of outside basis, percentage	(0.60%)	(18.10%)	(0.20%)	24.30%
Adjustment to tax reserves, percentage	(0.10%)	(2.60%)	0.00%	(19.40%)
Adjustment to Value Allowance, Percentage	(1.00%)	0.00%	0.20%	(0.60%)
APLNG Impairment, percentage	0.00%	0.00%	0.00%	(21.20%)
State income tax, percentage	1.30%	2.10%	1.10%	2.50%
Enhanced oil recovery, percentage	(1.30%)	(0.80%)	(1.00%)	1.20%
Other, percentage	(0.30%)	(2.20%)	0.00%	0.50%
Effective Income Tax Rate, Continuing Operations	35.50%	33.20%	39.40%	39.30%

Income Taxes (Details Textual)

Income Taxes (Details Textual) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Income Tax Examination [Line Items]
Canada disposition	$ 0	$ (8)	$ 0	$ (1,176)
Recovery of outside basis	(16)	(118)	(19)	(957)
Adjustment to tax reserves, amount	(3)	(17)	2	764
Oil and gas
Income Tax Examination [Line Items]
Recovery of outside basis		$ (114)		$ (114)
Conoco Phillips Vs Petroleos de Venezuela SA [Member]
Income Tax Examination [Line Items]
Total Tax Benefit Related to Settlement	$ 53
Canada Revenue Agency [Member] | Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member]
Income Tax Examination [Line Items]
Canada disposition			(1,176)
Recovery of outside basis			(822)
Adjustment to tax reserves, amount			$ 822

Supplementary Information - C_3

Supplementary Information - Condensed Consolidating Financial Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2018	Sep. 30, 2017
Condensed Financial Statements, Captions [Line Items]
Repayments of Debt			$ 4,970	$ 6,594
Proceeds from Collection of Long-term Loans to Related Parties			$ 119	$ 115
ConocoPhillips - [Member]
Condensed Financial Statements, Captions [Line Items]
Proceeds from Contributions from Affiliates	$ 2,500
ConocoPhillips - [Member] | ConocoPhillips Company [Member]
Condensed Financial Statements, Captions [Line Items]
NonControlling Interest Ownership			100.00%
ConocoPhillips Company [Member] | Reportable Legal Entities [Member]
Condensed Financial Statements, Captions [Line Items]
Proceeds from Collection of Long-term Loans to Related Parties	$ 1,200	$ 1,200
ConocoPhillips Company [Member] | ConocoPhillips Canada Funding Company I [Member]
Condensed Financial Statements, Captions [Line Items]
NonControlling Interest Ownership			100.00%

Supplementary Information - C_4

Supplementary Information - Condensed Consolidating Financial Information - Inc Stmt (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017		Sep. 30, 2018	Sep. 30, 2017
Revenues and Other Income
Sales and other operating revenues	$ 9,449	$ 6,688		$ 26,751	$ 20,987
Equity in earnings (losses) of affiliates	294	196		767	574
Gain (loss) on dispositions	113	246		175	2,144
Other income	309	65		673	143
Intercomapny revenues	0			0	0
Total Revenues and Other Income	10,165	7,195		28,366	23,848
Costs and Expenses
Purchased commodities	3,530	2,926		10,308	9,040
Production and operating expenses	1,367	1,222	[1],[2]	3,851	3,838	[1],[2]
Selling, general and administrative expenses	119	110	[1],[2]	336	302	[1],[2]
Exploration expenses	103	73	[1],[2]	267	720	[1],[2]
Depreciation, depletion and amortization	1,494	1,608		4,344	5,212
Impairments	44	6		21	6,475
Taxes other than income taxes	312	175		768	604
Accretion on discounted liabilities	89	89		266	276
Interest and debt expense	186	251		547	872
Foreign currency transaction (gains) losses	5	5		7	28
Other Expense	10	77	[1]	350	421	[1]
Total Costs and Expenses	7,259	6,542		21,065	27,788
Income (Loss) before income taxes	2,906	653		7,301	(3,940)
Income Tax Expense (Benefit)	1,033	217		2,874	(1,549)
Net income (loss)	1,873	436		4,427	(2,391)
Less: net income attributable to noncontrolling interests	(12)	(16)		(38)	(43)
Net Income (Loss)	1,861	420		4,389	(2,434)
Comprehensive Income (Loss) Attributable to ConocoPhillips	2,056	1,470		4,407	(1,533)	[3]
ConocoPhillips - [Member]
Revenues and Other Income
Sales and other operating revenues	0	0		0	0
Equity in earnings (losses) of affiliates	1,903	486		4,562	(2,092)
Gain (loss) on dispositions	0	0		0	0
Other income	0	0		0	1
Intercomapny revenues	9	10		28	39
Total Revenues and Other Income	1,912	496		4,590	(2,052)
Costs and Expenses
Purchased commodities	0	0		0	0
Production and operating expenses	0	0		0	0
Selling, general and administrative expenses	2	2		7	8
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	72	86		219	340
Foreign currency transaction (gains) losses	(12)	(27)		22	(49)
Other Expense	0	50		0	267
Total Costs and Expenses	62	111		248	566
Income (Loss) before income taxes	1,850	385		4,342	(2,618)
Income Tax Expense (Benefit)	(11)	(35)		(47)	(184)
Net income (loss)	1,861	420		4,389	(2,434)
Less: net income attributable to noncontrolling interests	0	0		0	0
Net Income (Loss)	1,861	420		4,389	(2,434)
Comprehensive Income (Loss) Attributable to ConocoPhillips	2,056	1,470		4,407	(1,533)
Consolidating Adjustments [Member]
Revenues and Other Income
Sales and other operating revenues	0	0		0	0
Equity in earnings (losses) of affiliates	(4,031)	(757)		(10,026)	3,010
Gain (loss) on dispositions	0	0		0	0
Other income	0	0		0	0
Intercomapny revenues	(1,704)	(904)		(4,508)	(2,747)
Total Revenues and Other Income	(5,735)	(1,661)		(14,534)	263
Costs and Expenses
Purchased commodities	(1,546)	(741)		(4,020)	(2,257)
Production and operating expenses	(16)	(1)		(53)	(3)
Selling, general and administrative expenses	0	0		(5)	(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	(142)	(162)		(430)	(482)
Foreign currency transaction (gains) losses	0	0		0	0
Other Expense	0	0		0	0
Total Costs and Expenses	(1,704)	(904)		(4,508)	(2,747)
Income (Loss) before income taxes	(4,031)	(757)		(10,026)	3,010
Income Tax Expense (Benefit)	0	0		0	0
Net income (loss)	(4,031)	(757)		(10,026)	3,010
Less: net income attributable to noncontrolling interests	0	0		0	0
Net Income (Loss)	(4,031)	(757)		(10,026)	3,010
Comprehensive Income (Loss) Attributable to ConocoPhillips	(4,433)	(2,422)		(9,856)	1,189
Reportable Legal Entities [Member] | ConocoPhillips Company [Member]
Revenues and Other Income
Sales and other operating revenues	4,330	2,997		11,774	9,066
Equity in earnings (losses) of affiliates	2,166	348		5,398	(776)
Gain (loss) on dispositions	75	879		78	908
Other income	(61)	12		230	27
Intercomapny revenues	34	77		124	222
Total Revenues and Other Income	6,544	4,313		17,604	9,447
Costs and Expenses
Purchased commodities	3,880	2,666		10,571	8,068
Production and operating expenses	298	216		723	483
Selling, general and administrative expenses	99	97		254	244
Exploration expenses	41	29		132	433
Depreciation, depletion and amortization	152	203		427	658
Impairments	1	1		(9)	1,075
Taxes other than income taxes	33	29		111	114
Accretion on discounted liabilities	4	8		13	28
Interest and debt expense	156	169		456	505
Foreign currency transaction (gains) losses	3	1		(6)	3
Other Expense	6	29		348	159
Total Costs and Expenses	4,673	3,448		13,020	11,770
Income (Loss) before income taxes	1,871	865		4,584	(2,323)
Income Tax Expense (Benefit)	(32)	379		22	(231)
Net income (loss)	1,903	486		4,562	(2,092)
Less: net income attributable to noncontrolling interests	0	0		0	0
Net Income (Loss)	1,903	486		4,562	(2,092)
Comprehensive Income (Loss) Attributable to ConocoPhillips	2,098	1,536		4,580	(1,191)
Reportable Legal Entities [Member] | 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
Intercomapny revenues	42	43		129	126
Total Revenues and Other Income	42	43		129	126
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	37	37		110	110
Foreign currency transaction (gains) losses	42	77		(43)	145
Other Expense	0	0		0	0
Total Costs and Expenses	79	114		67	255
Income (Loss) before income taxes	(37)	(71)		62	(129)
Income Tax Expense (Benefit)	1	6		(5)	12
Net income (loss)	(38)	(77)		67	(141)
Less: net income attributable to noncontrolling interests	0	0		0	0
Net Income (Loss)	(38)	(77)		67	(141)
Comprehensive Income (Loss) Attributable to ConocoPhillips	5	22		(13)	39
Reportable Legal Entities [Member] | All Other Subsidiaries [Member]
Revenues and Other Income
Sales and other operating revenues	5,119	3,691		14,977	11,921
Equity in earnings (losses) of affiliates	256	119		833	432
Gain (loss) on dispositions	38	(633)		97	1,236
Other income	370	53		443	115
Intercomapny revenues	1,619	774		4,227	2,360
Total Revenues and Other Income	7,402	4,004		20,577	16,064
Costs and Expenses
Purchased commodities	1,196	1,001		3,757	3,229
Production and operating expenses	1,085	1,007		3,181	3,358
Selling, general and administrative expenses	18	11		80	55
Exploration expenses	62	44		135	287
Depreciation, depletion and amortization	1,342	1,405		3,917	4,554
Impairments	43	5		30	5,400
Taxes other than income taxes	279	146		657	490
Accretion on discounted liabilities	85	81		253	248
Interest and debt expense	63	121		192	399
Foreign currency transaction (gains) losses	(28)	(46)		34	(71)
Other Expense	4	(2)		2	(5)
Total Costs and Expenses	4,149	3,773		12,238	17,944
Income (Loss) before income taxes	3,253	231		8,339	(1,880)
Income Tax Expense (Benefit)	1,075	(133)		2,904	(1,146)
Net income (loss)	2,178	364		5,435	(734)
Less: net income attributable to noncontrolling interests	(12)	(16)		(38)	(43)
Net Income (Loss)	2,166	348		5,397	(777)
Comprehensive Income (Loss) Attributable to ConocoPhillips	$ 2,330	$ 864		$ 5,289	$ (37)
[1]	*Certain amounts have been reclassified to conform to the current-period presentation resulting from the adoption of ASU No. 2017-07.
[2]	See Note 2—Changes in Accounting Principles, for additional information.
[3]	See Notes to Consolidated Financial Statements.

Supplementary Information - C_5

Supplementary Information - Condensed Consolidating Financial Information - Bal Sheet (Details) - USD ($) $ in Millions		Sep. 30, 2018	Dec. 31, 2017
Assets
Cash and cash equivalents		$ 3,716	$ 6,325
Short-term investments		875	1,873
Accounts and notes receivable		4,499	4,320
Investment in Cenovus Energy		2,086	1,899
Inventories		1,239	1,060
Prepaid expenses and other current assets		2,308	1,035
Total Current Assets		14,723	16,512
Investments and long-term receiavables		9,888	10,060
Net properties, plants and equipment		44,736	45,683
Other assets		1,209	1,107
Total Assets		70,556	73,362
Liabilities and Stockholders' Equity
Accounts payable		3,918	4,030
Short-term debt		95	2,575
Accrued income and other taxes		1,582	1,038
Employee benefit obligations		626	725
Other accruals		1,180	1,029
Total Current Liabilities		7,401	9,397
Long-term debt		14,902	17,128
Asset retirement obligations and accrued environmental costs		7,554	7,631
Deferred income taxes		5,535	5,282
Employee benefit obligations		1,755	1,854
Other liabilities and deferred credits		1,330	1,269
Total Liabilities		38,477	42,561
Retained earnings		32,495	29,391
Other common stockholders' equity		(545)	1,216
Noncontrolling interests		129	194
Total Liabilities and Stockholders' Equity	[1]	70,556	73,362
ConocoPhillips - [Member]
Assets
Cash and cash equivalents		0	0
Short-term investments		0	0
Accounts and notes receivable		6	24
Investment in Cenovus Energy		0	0
Inventories		0	0
Prepaid expenses and other current assets		0	1
Total Current Assets		6	25
Investments and long-term receiavables		31,249	29,400
Net properties, plants and equipment		0	0
Other assets		19	15
Total Assets		31,274	29,440
Liabilities and Stockholders' Equity
Accounts payable		0	0
Short-term debt		(3)	(5)
Accrued income and other taxes		0	0
Employee benefit obligations		0	0
Other accruals		57	85
Total Current Liabilities		54	80
Long-term debt		3,790	3,787
Asset retirement obligations and accrued environmental costs		0	0
Deferred income taxes		0	0
Employee benefit obligations		0	0
Other liabilities and deferred credits		2,042	1,528
Total Liabilities		5,886	5,395
Retained earnings		25,972	22,867
Other common stockholders' equity		(584)	1,178
Noncontrolling interests		0	0
Total Liabilities and Stockholders' Equity		31,274	29,440
Consolidating Adjustments [Member]
Assets
Cash and cash equivalents		0	0
Short-term investments		0	0
Accounts and notes receivable		(3,423)	(2,864)
Investment in Cenovus Energy		0	0
Inventories		0	0
Prepaid expenses and other current assets		(27)	(29)
Total Current Assets		(3,450)	(2,893)
Investments and long-term receiavables		(96,295)	(84,897)
Net properties, plants and equipment		(468)	(477)
Other assets		(930)	(1,542)
Total Assets		(101,143)	(89,809)
Liabilities and Stockholders' Equity
Accounts payable		(3,423)	(2,864)
Short-term debt		(9)	(9)
Accrued income and other taxes		0	0
Employee benefit obligations		0	0
Other accruals		(27)	(30)
Total Current Liabilities		(3,459)	(2,903)
Long-term debt		(478)	(477)
Asset retirement obligations and accrued environmental costs		0	0
Deferred income taxes		(433)	(981)
Employee benefit obligations		0	0
Other liabilities and deferred credits		(20,400)	(15,629)
Total Liabilities		(24,770)	(19,990)
Retained earnings		(27,360)	(18,070)
Other common stockholders' equity		(49,013)	(51,749)
Noncontrolling interests		0	0
Total Liabilities and Stockholders' Equity		(101,143)	(89,809)
Reportable Legal Entities [Member] | ConocoPhillips Company [Member]
Assets
Cash and cash equivalents		16	234
Short-term investments		0	0
Accounts and notes receivable		2,614	2,255
Investment in Cenovus Energy		2,086	1,899
Inventories		198	163
Prepaid expenses and other current assets		159	278
Total Current Assets		5,073	4,829
Investments and long-term receiavables		51,482	47,974
Net properties, plants and equipment		4,495	4,230
Other assets		484	1,146
Total Assets		61,534	58,179
Liabilities and Stockholders' Equity
Accounts payable		3,444	3,094
Short-term debt		12	2,505
Accrued income and other taxes		104	107
Employee benefit obligations		476	554
Other accruals		404	314
Total Current Liabilities		4,440	6,574
Long-term debt		7,152	9,321
Asset retirement obligations and accrued environmental costs		424	432
Deferred income taxes		0	0
Employee benefit obligations		1,315	1,335
Other liabilities and deferred credits		11,064	5,229
Total Liabilities		24,395	22,891
Retained earnings		17,591	13,317
Other common stockholders' equity		19,548	21,971
Noncontrolling interests		0	0
Total Liabilities and Stockholders' Equity		61,534	58,179
Reportable Legal Entities [Member] | ConocoPhillips Canada Funding Company I [Member]
Assets
Cash and cash equivalents		0	4
Short-term investments		0	0
Accounts and notes receivable		1	35
Investment in Cenovus Energy		0	0
Inventories		0	0
Prepaid expenses and other current assets		7	6
Total Current Assets		8	45
Investments and long-term receiavables		2,623	2,533
Net properties, plants and equipment		0	0
Other assets		178	186
Total Assets		2,809	2,764
Liabilities and Stockholders' Equity
Accounts payable		7	1
Short-term debt		7	7
Accrued income and other taxes		0	0
Employee benefit obligations		0	0
Other accruals		51	48
Total Current Liabilities		65	56
Long-term debt		1,698	1,703
Asset retirement obligations and accrued environmental costs		0	0
Deferred income taxes		0	0
Employee benefit obligations		0	0
Other liabilities and deferred credits		981	926
Total Liabilities		2,744	2,685
Retained earnings		(614)	(681)
Other common stockholders' equity		679	760
Noncontrolling interests		0	0
Total Liabilities and Stockholders' Equity		2,809	2,764
Reportable Legal Entities [Member] | All Other Subsidiaries [Member]
Assets
Cash and cash equivalents		3,700	6,087
Short-term investments		875	1,873
Accounts and notes receivable		5,301	4,870
Investment in Cenovus Energy		0	0
Inventories		1,041	897
Prepaid expenses and other current assets		2,169	779
Total Current Assets		13,086	14,506
Investments and long-term receiavables		20,829	15,050
Net properties, plants and equipment		40,709	41,930
Other assets		1,458	1,302
Total Assets		76,082	72,788
Liabilities and Stockholders' Equity
Accounts payable		3,890	3,799
Short-term debt		88	77
Accrued income and other taxes		1,478	931
Employee benefit obligations		150	171
Other accruals		695	612
Total Current Liabilities		6,301	5,590
Long-term debt		2,740	2,794
Asset retirement obligations and accrued environmental costs		7,130	7,199
Deferred income taxes		5,968	6,263
Employee benefit obligations		440	519
Other liabilities and deferred credits		7,643	9,215
Total Liabilities		30,222	31,580
Retained earnings		16,906	11,958
Other common stockholders' equity		28,825	29,056
Noncontrolling interests		129	194
Total Liabilities and Stockholders' Equity		$ 76,082	$ 72,788
[1]	See Notes to Consolidated Financial Statements.

Supplementary Information - C_6

Supplementary Information - Condensed Consolidating Financial Information - Cash Flow (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2018		Sep. 30, 2017
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities	$ 9,151		$ 4,596
Cash Flows From Investing Activities
Capital expenditures and investments	(5,133)		(3,074)
Working capital changes associated with investing activities	(57)		(18)
Proceeds from asset dispositions	394		13,740
Net sales (purchases) of short-term investments	996		(2,583)
Long-term advances/loans-related parties	0		0
Collection of advances/loans-related parties	119		115
Intercompany cash management	0		0
Other	16		51
Net Cash Provided by (Used in) Investing Activities	(3,665)		8,231
Cash Flows From Financing Activities
Issuance of debt	0		0
Repayment of debt	(4,970)		(6,594)
Issuance of company common stock	121		(65)
Repurchase of company common stock	(2,073)		(2,045)
Dividends paid	(1,009)		(986)
Other	(111)		(80)
Net Cash Provided by (Used in) Financing Activities	(8,042)		(9,770)
Effect of Exchange Rate Changes on Cash and Cash Equivalents and Restricted Cash	(40)		244
Net Change in Cash and Cash Equivalents and Restricted Cash	(2,596)		3,301
Cash and Cash Equivalents and Restricted Cash at beginning of period	6,536	[1]	3,610
Cash and Cash Equivalents and Restricted Cash at end of period	3,940	[2]	6,911
ConocoPhillips - [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities	2,331		(161)
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		5,000
Net sales (purchases) of short-term investments	0		0
Long-term advances/loans-related parties	0		0
Collection of advances/loans-related parties	0		658
Intercompany cash management	514		2,903
Other	0		0
Net Cash Provided by (Used in) Investing Activities	514		8,561
Cash Flows From Financing Activities
Issuance of debt	0		0
Repayment of debt	0		(5,459)
Issuance of company common stock	234		87
Repurchase of company common stock	(2,073)		(2,045)
Dividends paid	(1,009)		(986)
Other	3		3
Net Cash Provided by (Used in) Financing Activities	(2,845)		(8,400)
Effect of Exchange Rate Changes on Cash and Cash Equivalents and Restricted Cash	0		0
Net Change in Cash and Cash Equivalents and Restricted Cash	0		0
Cash and Cash Equivalents and Restricted Cash at beginning of period	0		0
Cash and Cash Equivalents and Restricted Cash at end of period	0		0
Reportable Legal Entities [Member] | ConocoPhillips Company [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities	863		634
Cash Flows From Investing Activities
Capital expenditures and investments	(771)		(1,230)
Working capital changes associated with investing activities	(77)		36
Proceeds from asset dispositions	307		10,974
Net sales (purchases) of short-term investments	0		0
Long-term advances/loans-related parties	(36)		(74)
Collection of advances/loans-related parties	3,432		127
Intercompany cash management	3,426		(2,474)
Other	0		0
Net Cash Provided by (Used in) Investing Activities	6,281		7,359
Cash Flows From Financing Activities
Issuance of debt	10		20
Repayment of debt	(4,865)		(3,146)
Issuance of company common stock	0		0
Repurchase of company common stock	0		0
Dividends paid	0		0
Other	(2,511)		(5,000)
Net Cash Provided by (Used in) Financing Activities	(7,366)		(8,126)
Effect of Exchange Rate Changes on Cash and Cash Equivalents and Restricted Cash	4		1
Net Change in Cash and Cash Equivalents and Restricted Cash	(218)		(132)
Cash and Cash Equivalents and Restricted Cash at beginning of period	234		358
Cash and Cash Equivalents and Restricted Cash at end of period	16		226
Reportable Legal Entities [Member] | ConocoPhillips Canada Funding Company I [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities	(121)		22
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 Provided by (Used in) Investing Activities	0		0
Cash Flows From Financing Activities
Issuance of debt	117		0
Repayment of debt	0		0
Issuance of company common stock	0		0
Repurchase of company common stock	0		0
Dividends paid	0		0
Other	0		0
Net Cash Provided by (Used in) Financing Activities	117		0
Effect of Exchange Rate Changes on Cash and Cash Equivalents and Restricted Cash	0		0
Net Change in Cash and Cash Equivalents and Restricted Cash	(4)		22
Cash and Cash Equivalents and Restricted Cash at beginning of period	4		13
Cash and Cash Equivalents and Restricted Cash at end of period	0		35
Reportable Legal Entities [Member] | All Other Subsidiaries [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities	8,937		6,868
Cash Flows From Investing Activities
Capital expenditures and investments	(4,369)		(2,711)
Working capital changes associated with investing activities	20		(54)
Proceeds from asset dispositions	199		12,737
Net sales (purchases) of short-term investments	996		(2,583)
Long-term advances/loans-related parties	(127)		(20)
Collection of advances/loans-related parties	129		2,196
Intercompany cash management	(3,940)		(429)
Other	16		51
Net Cash Provided by (Used in) Investing Activities	(7,076)		9,187
Cash Flows From Financing Activities
Issuance of debt	36		74
Repayment of debt	(3,547)		(855)
Issuance of company common stock	0		0
Repurchase of company common stock	0		0
Dividends paid	(452)		(2,919)
Other	(228)		(9,187)
Net Cash Provided by (Used in) Financing Activities	(4,191)		(12,887)
Effect of Exchange Rate Changes on Cash and Cash Equivalents and Restricted Cash	(44)		243
Net Change in Cash and Cash Equivalents and Restricted Cash	(2,374)		3,411
Cash and Cash Equivalents and Restricted Cash at beginning of period	6,298		3,239
Cash and Cash Equivalents and Restricted Cash at end of period	3,924		6,650
Consolidating Adjustments [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) operating activities	(2,859)		(2,767)
Cash Flows From Investing Activities
Capital expenditures and investments	7		867
Working capital changes associated with investing activities	0		0
Proceeds from asset dispositions	(112)		(14,971)
Net sales (purchases) of short-term investments	0		0
Long-term advances/loans-related parties	163		94
Collection of advances/loans-related parties	(3,442)		(2,866)
Intercompany cash management	0		0
Other	0		0
Net Cash Provided by (Used in) Investing Activities	(3,384)		(16,876)
Cash Flows From Financing Activities
Issuance of debt	(163)		(94)
Repayment of debt	3,442		2,866
Issuance of company common stock	(113)		(152)
Repurchase of company common stock	0		0
Dividends paid	452		2,919
Other	2,625		14,104
Net Cash Provided by (Used in) Financing Activities	6,243		19,643
Effect of Exchange Rate Changes on Cash and Cash Equivalents and Restricted Cash	0		0
Net Change in Cash and Cash Equivalents and Restricted Cash	0		0
Cash and Cash Equivalents and Restricted Cash at beginning of period	0		0
Cash and Cash Equivalents and Restricted Cash at end of period	$ 0		$ 0
[1]	*Restated to include $211 million of restricted cash at January 1, 2018. See Note 2—Changes in Accounting Principles for additional information relating to the adoption of ASU No. 2016-18.
[2]	Restricted cash totaling $224 million is included in the "Other assets" line of our Consolidated Balance Sheet as of September 30, 2018.

Uncategorized Items - cop-20180

Label	Element	Value
Restatement Adjustment [Member]
Restricted Cash	us-gaap_RestrictedCash	$ 211,000,000