Occidental Petroleum Corporatio (OXY) 10-Q 4 Nov 19 2019 Q3 Quarterly report Financial data

Cover Page

Cover Page	9 Months Ended
	Sep. 30, 2019shares
Cover page.
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2019
Document Transition Report	false
Entity File Number	1-9210
Entity Registrant Name	OCCIDENTAL PETROLEUM CORP /DE/
Entity Central Index Key	0000797468
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	95-4035997
Entity Address, Address Line One	5 Greenway Plaza, Suite 110
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77046
City Area Code	713
Local Phone Number	215-7000
Title of 12(b) Security	Common Stock, $0.20 par value
Trading Symbol	OXY
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	893,317,470

CONSOLIDATED CONDENSED BALANCE

CONSOLIDATED CONDENSED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
CURRENT ASSETS
Cash and cash equivalents	$ 4,840	$ 3,033
Restricted cash and restricted cash equivalents	454	0
Trade receivables, net	5,854	4,893
Inventories	1,601	1,260
Assets held for sale	6,445	0
Other current assets	1,750	746
Total current assets	20,944	9,932
INVESTMENTS IN UNCONSOLIDATED ENTITIES ($2,261 related to WES)	3,684	1,680
PROPERTY, PLANT AND EQUIPMENT	136,925	74,420
Accumulated depreciation, depletion, and amortization	(46,804)	(42,983)
PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation, depletion and amortization	90,121	31,437
OPERATING LEASE ASSETS	1,078
LONG-TERM RECEIVABLES AND OTHER ASSETS, NET	1,155	797
INTANGIBLES, NET ($2,380 related to WES)	2,387	8
TOTAL ASSETS	125,443	43,854
CURRENT LIABILITIES
Current maturities of long-term debt	31	116
Current operating lease liabilities	463
Accounts payable	6,789	4,885
Accrued liabilities ($315 related to WES)	5,175	2,411
Accrued income taxes	1,036	0
Liabilities of assets held for sale	2,203	0
Total current liabilities	15,697	7,412
LONG-TERM DEBT, NET
LONG-TERM DEBT, NET	47,583	10,201
DEFERRED CREDITS AND OTHER LIABILITIES
Deferred income taxes ($1,167 related to WES)	9,920	907
Asset retirement obligations ($319 related to WES)	4,164	1,424
Pension and postretirement obligations	1,927	809
Environmental remediation reserves	905	762
Operating lease liabilities	676
Other	3,566	1,009
Total deferred credits and other liabilities	21,158	4,911
EQUITY
Preferred stock, at $1.00 per share par value (100,000 shares at September 30, 2019)	9,762	0
Common stock, at $0.20 per share par value (1,043,640,621 shares at September 30, 2019, and 895,115,637 shares at December 31, 2018)	209	179
Treasury stock (150,323,151 shares at September 30, 2019, and 145,726,051 shares at December 31, 2018)	(10,653)	(10,473)
Additional paid-in capital	14,867	8,046
Retained earnings	22,227	23,750
Accumulated other comprehensive loss	(332)	(172)
Total stockholders' equity	36,080	21,330
Noncontrolling interests	4,925	0
Total equity	41,005	21,330
TOTAL LIABILITIES AND EQUITY	125,443	43,854
Occidental
LONG-TERM DEBT, NET
LONG-TERM DEBT, NET	39,946	10,201
Oil and Gas segment
CURRENT ASSETS
PROPERTY, PLANT AND EQUIPMENT	110,668	58,799
Chemical segment
CURRENT ASSETS
PROPERTY, PLANT AND EQUIPMENT	7,092	7,001
Marketing and Other Midstream segment
CURRENT ASSETS
PROPERTY, PLANT AND EQUIPMENT	8,133	8,070
WES Midstream
CURRENT ASSETS
PROPERTY, PLANT AND EQUIPMENT	9,635	0
WES
CURRENT ASSETS
INVESTMENTS IN UNCONSOLIDATED ENTITIES ($2,261 related to WES)	2,261
INTANGIBLES, NET ($2,380 related to WES)	2,380
GOODWILL - WES	6,074	0
CURRENT LIABILITIES
Accrued liabilities ($315 related to WES)	315
LONG-TERM DEBT, NET
LONG-TERM DEBT, NET	7,637	0
DEFERRED CREDITS AND OTHER LIABILITIES
Deferred income taxes ($1,167 related to WES)	1,167
Asset retirement obligations ($319 related to WES)	319
Corporate
CURRENT ASSETS
PROPERTY, PLANT AND EQUIPMENT	$ 1,397	$ 550

CONSOLIDATED CONDENSED BALANC_2

CONSOLIDATED CONDENSED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
INVESTMENTS IN UNCONSOLIDATED ENTITIES ($2,261 related to WES)	$ 3,684	$ 1,680
INTANGIBLES, NET	2,387	8
Accrued liabilities	5,175	2,411
Deferred income taxes ($1,167 related to WES)	9,920	907
Asset retirement obligations	$ 4,164	$ 1,424
Preferred stock, par value (in dollars per share)	$ 1	$ 1
Preferred stock, outstanding (in shares)	100,000	0
Common stock, par value (in dollars per share)	$ 0.20	$ 0.20
Common stock, outstanding (in shares)	1,043,640,621	895,115,637
Treasury stock (in shares)	150,323,151	145,726,051
WES
INVESTMENTS IN UNCONSOLIDATED ENTITIES ($2,261 related to WES)	$ 2,261
INTANGIBLES, NET	2,380
Accrued liabilities	315
Deferred income taxes ($1,167 related to WES)	1,167
Asset retirement obligations	$ 319

CONSOLIDATED CONDENSED STATEMEN

CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
REVENUES AND OTHER INCOME
Net sales	$ 5,687	$ 5,216	$ 14,111	$ 13,062
Interest, dividends, and other income	56	34	175	101
Gain on sale of assets, net	128	926	150	969
TOTAL REVENUES AND OTHER INCOME	5,871	6,176	14,436	14,132
COSTS AND OTHER DEDUCTIONS
Oil and gas operating expense	962	680	2,324	1,909
Transportation expense	217	41	281	121
Chemical and midstream cost of sales	741	722	2,046	2,128
Purchased commodities	441	343	1,237	456
Selling, general and administrative	242	151	545	423
Other operating expense	363	280	861	717
Taxes other than on income	198	110	432	333
Depreciation, depletion, and amortization	1,706	1,023	3,710	2,891
Asset impairments and other items	325	214	325	256
Anadarko merger-related costs	924	0	974	0
Exploration expense	63	24	134	60
Losses on interest-rate swaps and warrants, net	381	96	632	290
TOTAL COSTS AND OTHER DEDUCTIONS	6,563	3,684	13,501	9,584
Income (loss) before income taxes and other items	(692)	2,492	935	4,548
OTHER ITEMS
Gains (losses) on interest rate swaps and warrants, net	(33)	0	(33)	0
Income from equity investments	104	87	274	228
OTHER INCOME (LOSS)	71	87	241	228
Income (loss) from continuing operations before income taxes	(621)	2,579	1,176	4,776
Income tax expense	(116)	(710)	(647)	(1,351)
Income (loss) from continuing operations	(737)	1,869	529	3,425
Discontinued operations, net of tax	(15)	0	(15)	0
NET INCOME (LOSS)	(752)	1,869	514	3,425
Less: Net income attributable to noncontrolling interests	(42)	0	(42)	0
Less: Preferred stock dividends	(118)	0	(118)	0
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCKHOLDERS	$ (912)	$ 1,869	$ 354	$ 3,425
Income (loss) from continuing operations—basic (in usd per share)	$ (1.06)	$ 2.44	$ 0.47	$ 4.46
Income (loss) from discontinued operations—basic (in usd per share)	(0.02)	0	(0.02)	0
Net income (loss) attributable to common stockholders—basic (in usd per share)	(1.08)	2.44	0.45	4.46
Income (loss) from continuing operations—diluted (in usd per share)	(1.06)	2.44	0.47	4.45
Income (loss) from discontinued operations—diluted (in usd per share)	(0.02)	0	(0.02)	0
Net income (loss) attributable to common stockholders—diluted (in usd per share)	$ (1.08)	$ 2.44	$ 0.45	$ 4.45

CONSOLIDATED CONDENSED STATEM_2

CONSOLIDATED CONDENSED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Statement of Comprehensive Income [Abstract]
Net income (loss)		$ (752)	$ 1,869	$ 514	$ 3,425
Other comprehensive income (loss) items:
Losses on derivatives	[1]	(114)	(1)	(130)	(5)
Pension and postretirement (losses) gains	[2]	(34)	144	(30)	153
Reclassification of losses on derivatives	[3]	0	10	0	13
Other comprehensive (loss) income, net of tax		(148)	153	(160)	161
Comprehensive income (loss)		(900)	2,022	354	3,586
Comprehensive income attributable to noncontrolling interests		(42)	0	(42)	0
Comprehensive income (loss) attributable to preferred and common stockholders		$ (942)	$ 2,022	$ 312	$ 3,586
[1]	Net of tax of $32 million and zero for the three months ended September 30, 2019 , and 2018, and $36 million and $1 million for the nine months ended September 30, 2019 , and 2018, respectively.
[2]	Net of tax of $10 million and $(40) million for the three months ended September 30, 2019 , and 2018, and $8 million and $(43) million for the nine months ended September 30, 2019 , and 2018, respectively.
[3]	Net of tax of $(3) million for the three months ended September 30, 2018, and $(4) million for the nine months ended September 30, 2018, respectively.

CONSOLIDATED CONDENSED STATEM_3

CONSOLIDATED CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Statement of Comprehensive Income [Abstract]
Unrealized losses on derivatives, tax	$ 32	$ 0	$ 36	$ 1
Pension and postretirement gains, tax	$ 10	(40)	$ 8	(43)
Reclassification to income of realized (gains) losses on derivatives, tax		$ (3)		$ (4)

CONSOLIDATED CONDENSED STATEM_4

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
CASH FLOW FROM OPERATING ACTIVITIES
Net income	$ 514	$ 3,425
Adjustments to reconcile net income to net cash provided by operating activities:
Discontinued operations, net	15	0
Depreciation, depletion and amortization of assets	3,710	2,891
Deferred income tax (benefit) provision	(1,050)	550
Other noncash charges to income	578	74
Gain on sale of assets, net	(150)	(969)
Asset impairments and other items	325	256
Undistributed earnings from affiliates	(50)	(16)
Dry hole expenses	41	27
Changes in operating assets and liabilities, net	1,506	(1,069)
Cash provided by operating activities - continuing operations	5,439	5,169
Cash used by operating activities - discontinued operations	(73)	0
Net cash provided by operating activities	5,366	5,169
CASH FLOW FROM INVESTING ACTIVITIES
Capital expenditures	(4,184)	(3,638)
Change in capital accrual	(160)	7
Proceeds from sale of assets and equity investments, net	4,809	2,745
Purchase of businesses and assets, net	(27,926)	(726)
Equity investments and other, net	(140)	(88)
Cash used by investing activities - continuing operations	(27,601)	(1,700)
Cash used by investing activities - discontinued operations	(125)	0
Net cash used by investing activities	(27,726)	(1,700)
CASH FLOW FROM FINANCING ACTIVITIES
Proceeds from long-term debt, net	21,557	978
Payments of long-term debt	(4,949)	(500)
Proceeds from WES revolvers	1,240	0
Payment of revolvers - WES	(1,000)	0
Proceeds from issuance of common and preferred stock	10,010	17
Purchases of treasury stock	(237)	(908)
Cash dividends paid to common stockholders	(1,766)	(1,780)
Distributions to noncontrolling interest	(127)	0
Other financing, net	(35)	6
Cash provided (used) by financing activities - continuing operations	24,693	(2,187)
Cash used by financing activities - discontinued operations	(1)	0
Net cash provided by (used) by financing activities	24,692	(2,187)
Increase in cash, cash equivalents, restricted cash and restricted cash equivalents	2,332	1,282
Cash and cash equivalents — beginning of period	3,033	1,672
Cash, cash equivalents, restricted cash and restricted cash equivalents — end of period	$ 5,365	$ 2,954

CONSOLIDATED CONDENSED STATEM_5

CONSOLIDATED CONDENSED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($) $ in Millions	Total	Common Stock	Preferred Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Loss	Non-controlling Interests
Beginning balance at Dec. 31, 2017	$ 20,572	$ 179	$ 0	$ (9,168)	$ 7,884	$ 21,935	$ (258)	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	3,425					3,425
Other comprehensive income (loss), net of tax	161						161
Dividends on common stock	(1,783)					(1,783)
Issuance of common stock and other, net	107				107
Purchases of treasury stock	(994)			(994)
Reclassification of stranded tax effects						58	(58)
Noncontrolling interest contributions, net	0							0
Ending balance at Sep. 30, 2018	21,488	179	0	(10,162)	7,991	23,635	(155)	0
Beginning balance at Jun. 30, 2018	20,931	179	0	(9,268)	7,967	22,361	(308)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,869					1,869
Other comprehensive income (loss), net of tax	153						153
Dividends on common stock	(595)					(595)
Issuance of common stock and other, net	24	0			24
Purchases of treasury stock	(894)			(894)
Reclassification of stranded tax effects						0	0
Noncontrolling interest contributions, net	0							0
Ending balance at Sep. 30, 2018	21,488	179	0	(10,162)	7,991	23,635	(155)	0
Beginning balance at Dec. 31, 2018	21,330	179	0	(10,473)	8,046	23,750	(172)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	514					472		42
Other comprehensive income (loss), net of tax	(160)						(160)
Dividends on common stock	(1,877)					(1,877)
Dividends on preferred stock	(118)					(118)
Issuance of common stock and other, net	6,851	30			6,821
Issuance of preferred stock, net	9,762		9,762
Purchases of treasury stock	(180)			(180)
Fair value of noncontrolling interest acquired	4,875							4,875
Noncontrolling interest contributions, net	8							8
Ending balance at Sep. 30, 2019	41,005	209	9,762	(10,653)	14,867	22,227	(332)	4,925
Beginning balance at Jun. 30, 2019	21,347	179	0	(10,653)	8,157	23,848	(184)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	(752)					(794)		42
Other comprehensive income (loss), net of tax	(148)						(148)
Dividends on common stock	(709)					(709)
Dividends on preferred stock	(118)					(118)
Issuance of common stock and other, net	6,740	30			6,710
Issuance of preferred stock, net	9,762		9,762
Fair value of noncontrolling interest acquired	4,875							4,875
Noncontrolling interest contributions, net	8							8
Ending balance at Sep. 30, 2019	$ 41,005	$ 209	$ 9,762	$ (10,653)	$ 14,867	$ 22,227	$ (332)	$ 4,925

CONSOLIDATED CONDENSED STATEM_6

CONSOLIDATED CONDENSED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Statement of Stockholders' Equity [Abstract]
DIVIDENDS PER COMMON SHARE (in dollars per share)	$ 0.79	$ 0.78	$ 2.35	$ 2.32
DIVIDENDS PER PREFERRED SHARE (in dollars per share)	$ 1,489		$ 1,489

General

General	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
General	General Nature of Operations In this report, "Occidental" means Occidental Petroleum Corporation, a Delaware corporation (OPC), or OPC and one or more entities in which it owns a controlling interest (subsidiaries). Occidental conducts its operations through various subsidiaries and affiliates. On August 8, 2019, pursuant to the Agreement and Plan of Merger, dated as of May 9, 2019 (the Merger Agreement), among Occidental, Baseball Merger Sub 1, Inc., a Delaware corporation and an indirect, wholly owned subsidiary of Occidental (Merger Subsidiary), and Anadarko Petroleum Corporation (Anadarko), Occidental acquired all of the outstanding shares of Anadarko through a transaction in which Merger Subsidiary merged with and into Anadarko (the Merger), with Anadarko continuing as the surviving entity and as an indirect, wholly owned subsidiary of Occidental. See Note 3 - The Merger . Occidental's principal businesses consist of four reporting segments: Oil and Gas, Chemical, Marketing and Other Midstream, and WES Midstream, which includes the operations of Western Midstream Partners, LP (WES), a publicly traded limited partnership and a consolidated subsidiary of OPC. The Oil and Gas segment explores for, develops and produces oil and condensate, natural gas liquids (NGL) and natural gas. The Chemical segment (OxyChem) mainly manufactures and markets basic chemicals and vinyls. The Marketing and Other Midstream segment purchases, markets, gathers, processes, transports and stores oil, condensate, NGL, natural gas, carbon dioxide (CO 2 ) and power. It also trades around its assets, including transportation and storage capacity, and invests in entities that conduct similar activities. Also within the Marketing and Other Midstream segment is Oxy Low Carbon Ventures (OLCV). OLCV seeks to capitalize on Occidental’s enhanced oil recovery (EOR) leadership by developing carbon capture, utilization and storage projects that source anthropogenic carbon dioxide and promote innovative technologies that drive cost efficiencies and grow Occidental’s business while reducing emissions. The WES Midstream segment owns gathering systems, plants and pipelines and earns revenue from fee-based and service-based contracts with Occidental and third parties. WES is a variable interest entity (VIE) to Occidental. Principles of Consolidation The unaudited consolidated financial statements have been prepared in conformity with United States Generally Accepted Accounting Principles (GAAP) and include the accounts of OPC, its subsidiaries, VIEs for which Occidental is the primary beneficiary, and its undivided interests in oil and gas exploration and production ventures. Occidental has made its disclosures in accordance with GAAP as they apply to interim reporting, and condensed or omitted, as permitted by the Securities and Exchange Commission's rules and regulations, certain information and disclosures normally included in consolidated financial statements and notes. These unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and the notes thereto in Occidental's Annual Report on Form 10-K for the year ended December 31, 2018 (the 2018 Form 10-K). The Merger, including the addition of WES Midstream as a new reporting segment, introduced different revenue and expense streams to Occidental's legacy operations. As a result, changes were made to the structure of certain financial statements, notes and supplementary data to provide clarity and to conform to the current presentation. Variable Interest Entities Occidental, through its ownership of the general partner interest in WES, has the power to direct the activities that significantly affect the economic performance of WES and the obligation to absorb losses or the right to receive benefits that could be significant to WES; therefore, Occidental is considered the primary beneficiary and consolidates WES and all of its consolidated subsidiaries. WES maintains its own capital structure that is separate from Occidental, consisting of its own debt instruments and publicly traded common units. All intercompany transactions have been eliminated. The assets of WES and its subsidiaries cannot be used by Occidental for general corporate purposes and are included in and disclosed parenthetically on Occidental's consolidated condensed balance sheets, if material. The carrying amount of liabilities related to WES for which the creditors do not have recourse to Occidental's assets are also included in and disclosed parenthetically on Occidental's Consolidated Condensed Balance Sheets, if material. All outstanding debt for WES at September 30, 2019, including any borrowings under the WES revolving credit facility (WES RCF) and WES Term Loan Facility, is recourse to the general partner of Western Midstream Operating, LP (WES Operating), which in turn has been indemnified in certain circumstances by certain indirect wholly owned subsidiaries of Occidental for such liabilities. See Note 9 - Long-Term Debt . WES's sources of liquidity include cash and cash equivalents, cash flows generated from operations, interest income from a note receivable from Anadarko, borrowings under the WES RCF, the issuance of additional partnership units, and debt offerings. Concurrent with the closing of its May 2008 initial public offering, WES Operating loaned Anadarko $260 million in exchange for a 30-year note bearing interest at a fixed annual rate of 6.50% , payable quarterly. The note receivable and related interest income are eliminated in consolidation. Noncontrolling Interest WES is a publicly traded limited partnership with its common units traded on the New York Stock Exchange (NYSE) under the ticker symbol "WES." WES also owns the entire non-economic general partner interest and a 98% limited partner interest in WES Operating, a Delaware limited partnership formed by Anadarko in 2007 to acquire, own, develop and operate midstream assets. In addition, Occidental has a 2% limited partner interest in WES Operating and its ownership is held through the investment in WES. At September 30, 2019, Occidental’s ownership interest in WES consisted of the entire non-economic general partner interest and a 55.4% limited partner interest. The noncontrolling interest primarily consists of the 44.6% limited partner interest of WES owned by the public. Discontinued Operations In connection with the Merger, Occidental agreed to sell to TOTAL S.A. (Total) all of the assets, liabilities, businesses, and operations of Anadarko's operations in Algeria, Ghana, Mozambique and South Africa (collectively, the Africa Assets) for $8.8 billion , subject to certain purchase price adjustments. In August 2019, a purchase and sale agreement was executed for these Africa Assets. This transaction is conditioned on the receipt of required regulatory approvals, as well as other customary closing conditions. On September 27, 2019, Occidental completed the sale of Anadarko’s Mozambique LNG assets to Total for $4.2 billion . The assets and liabilities for Algeria, Ghana and South Africa, are presented as held for sale at September 30, 2019. The results of operations of the Africa Assets are presented as discontinued operations, see Note 4 - Acquisitions, Dispositions, and Other . Unless otherwise indicated, information presented in the Notes to the Consolidated Condensed Financial Statements relates only to Occidental's continuing operations. Information related to discontinued operations is included in Note 4 - Acquisitions, Dispositions, and Other , and in some instances, where appropriate, is included as a separate disclosure within the individual Notes to the Consolidated Condensed Financial Statements. Goodwill and Other Intangible Assets Goodwill resulting from the Merger was assigned to WES Midstream and represents the excess of the purchase price over the estimated fair value of the assets acquired and liabilities assumed. Goodwill is subject to annual impairment testing. Changes in goodwill may result from, among other things, finalization of preliminary purchase price allocations, impairments, additional acquisitions, or divestitures. See Note 3 - The Merger . Other intangible assets represent contractual rights obtained in connection with the Merger that had favorable contractual terms relative to market terms as well as customer-related intangible assets, including customer relationships. Other intangible assets are amortized over their estimated useful lives and are assessed for impairment with the associated long-lived asset group whenever impairment indicators are present. See Note 3 - The Merger . Supplemental Cash Flow Information Occidental paid international and domestic state income taxes of $751 million and $838 million during the nine months ended September 30, 2019, and 2018, respectively. Occidental received domestic state tax refunds of $2 million in each of the nine months ended September 30, 2019, and 2018. No federal income tax payments were made during the nine months ended September 30, 2019, and 2018. Interest paid totaled $610 million and $298 million during the nine months ended September 30, 2019, and 2018, respectively. Cash Equivalents and Restricted Cash Equivalents Occidental considers all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents or restricted cash equivalents. The cash equivalents and restricted cash equivalents balance at September 30, 2019, includes investments in government money market funds in which the carrying value approximates fair value. The following table provides a reconciliation of cash, cash equivalents, restricted cash and restricted cash equivalents as reported at the end of the period in the Consolidated Condensed Statements of Cash Flows for the nine months ended September 30, 2019 to the line items within the Consolidated Condensed Balance Sheet at September 30, 2019. There was no restricted cash or restricted cash equivalents at September 30, 2018 or December 31, 2018. millions September 30, 2019 Cash and cash equivalents $ 4,840 Restricted cash and restricted cash equivalents 454 Cash and restricted cash included in assets held for sale 16 Restricted cash and restricted cash equivalents included in long-term receivables and other assets, net 55 Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents $ 5,365

Accounting and Disclosure Chang

Accounting and Disclosure Changes	9 Months Ended
	Sep. 30, 2019
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Accounting and Disclosure Changes	Accounting and Disclosure Changes In January 2019, Occidental adopted the new lease standard Accounting Standards Codification Topic 842 - Leases (ASC 842). The new standard requires Occidental to recognize most leases, including operating leases, on the balance sheet. The new rules require lessees to recognize a right-of-use asset (ROU) and lease liability for all leases with lease terms of more than 12 months. Occidental adopted the standard using the modified retrospective approach, including adopting several optional practical expedients. See Note 10 - Lease Commitments

The Merger

The Merger	9 Months Ended
	Sep. 30, 2019
Business Combinations [Abstract]
The Merger	The Merger On May 9, 2019, Occidental entered into the Merger Agreement with Anadarko. On August 8, 2019, Anadarko’s stockholders voted to approve the Merger and it was made effective the same day. The Merger added to Occidental's oil and gas portfolio, primarily in the Permian Basin, DJ Basin and Gulf of Mexico, and a controlling interest in WES. In exchange for each share of Anadarko common stock, Anadarko stockholders received $59.00 in cash and 0.2934 of a share of Occidental common stock, plus cash in lieu of any fractional share of Occidental common stock that otherwise would have been issued, based on the average price of $46.31 per share of Occidental common stock on the NYSE on August 8, 2019. In connection with the Merger, Occidental issued $13.0 billion of new senior unsecured notes, $8.8 billion of term loans (the Term Loans) and 100,000 shares of series A preferred stock (the Preferred Stock) with a warrant to purchase 80 million shares of Occidental common stock at an exercise price of $62.50 (the Warrant) for $10 billion . In addition, Occidental increased its existing $3.0 billion revolving credit facility by an additional $2.0 billion in commitments. See Note 9 - Long-term Debt and Note 14 - Stockholders' Equity for additional information. The Merger constitutes a business combination and was accounted for using the acquisition method of accounting. The following table presents the Merger consideration paid to Anadarko stockholders as a result of the Merger: millions, except per share amounts Total shares of Anadarko common stock eligible for Merger consideration 491.6 Cash consideration (per share of common stock and shares underlying Anadarko stock-based awards eligible for Merger consideration) $ 59.00 Cash portion of Merger consideration $ 29,002 Total shares of Anadarko common stock and shares underlying Anadarko stock-based awards eligible for Merger consideration 492.0 Exchange ratio (per share of Anadarko common stock) 0.2934 Total shares of Occidental common stock issued to Anadarko stockholders 144 Average share price of Occidental common stock at August 8, 2019 $ 46.31 Stock portion of Merger consideration $ 6,684 Total Merger consideration $ 35,686 The following table sets forth the preliminary allocation of the Merger consideration. Certain data necessary to complete the purchase price allocation is not yet available, and includes, but is not limited to, final appraisals of assets acquired and liabilities assumed, valuation of pre-merger contingencies and final tax returns that provide underlying tax basis of assets acquired and liabilities assumed. Occidental will finalize the purchase price allocation during the 12-month period following the Merger date, during which time the value of the assets and liabilities may be revised as appropriate. millions As of August 8, 2019 Fair value of assets acquired: Current assets $ 3,590 Anadarko's Africa Assets held for sale 10,746 Investments in unconsolidated entities 2,430 Property, plant and equipment, net - Anadarko 48,771 Property, plant and equipment, net - WES Midstream 9,475 Other assets 797 Intangible assets - WES Midstream 2,400 Amount attributable to assets acquired $ 78,209 Fair value of liabilities assumed: Current liabilities $ 3,677 Liabilities of Anadarko's Africa Assets held for sale 2,329 Long-term debt - Anadarko 12,829 Long-term debt - WES Midstream 7,407 Deferred income taxes 10,040 Asset retirement obligations 2,728 Pension and post retirement obligations 1,125 Non-current derivative liabilities 1,279 Other long-term liabilities 2,308 Amount attributable to liabilities assumed $ 43,722 Net assets $ 34,487 Less: Fair value of noncontrolling interests in WES Midstream 4,875 Fair value of net assets acquired 29,612 Goodwill - WES Midstream 6,074 Total Merger consideration $ 35,686 The aggregate purchase price noted above was allocated to the major categories of assets and liabilities acquired based upon their preliminary estimated fair values at the date of the Merger. The valuation of certain assets, including property and intangible assets, are based on preliminary appraisals. The majority of measurements of assets acquired and liabilities assumed, other than debt, are based on inputs that are not observable in the market and thus represent Level 3 inputs. The fair value of acquired properties and equipment is based on both available market data and a cost approach. Oil and natural gas properties were valued using either available market data based on the nature of the properties and the location or an income approach. Intangible assets primarily consist of third-party customer contracts, the fair value of which was determined using an income approach. Deferred income taxes represent the tax effects of differences in the tax basis and merger-date fair values of assets acquired and liabilities assumed. The measurement of debt instruments was based on unadjusted quoted prices in an active market and are primarily Level 1; approximately $6.1 billion of the assumed debt is considered Level 2. The value of derivative instruments was based on observable inputs, primarily forward commodity-price and interest-rate curves and is considered Level 2. The excess of the purchase price over the preliminary estimated fair value of the net tangible and identifiable intangible assets acquired totaled $6.1 billion in goodwill. Goodwill is attributable to the difference in the WES Midstream market capitalization value at the date of the Merger and the WES Midstream net assets acquired, and primarily represents the intrinsic value of the customer relationship between WES Midstream and Occidental. With the completion of the Merger, Occidental acquired proved and unproved properties of approximately $18.2 billion and $26.0 billion , respectively, primarily associated with the Permian Basin, DJ Basin, Gulf of Mexico and Powder River Basin. The remaining $5.0 billion is related to land, mineral interests and corporate properties. Other intangible assets of $2.4 billion primarily relate to customer contracts associated with the WES Midstream segment. These contracts are amortized over 25 years . The annual aggregate amortization expense for intangible assets is expected to be $108 million . From the date of the Merger through September 30, 2019, revenues and net loss attributable to common stockholders associated with Anadarko assets totaled $1.5 billion and $400 million , respectively. The following summarizes the unaudited pro forma condensed financial information of Occidental as if the Merger had occurred on January 1, 2018: Three months ended September 30 Nine months ended September 30 millions, except per-share amounts 2019 2018 2019 2018 Revenues $ 7,335 $ 8,913 $ 22,419 $ 23,095 Net income (loss) attributable to common stockholders $ (427 ) $ 2,060 $ 475 $ 3,405 Net income (loss) attributable to common stockholders per share—basic $ (0.50 ) $ 2.27 $ 0.51 $ 3.74 Net income (loss) attributable to common stockholders per share—diluted $ (0.50 ) $ 2.26 $ 0.50 $ 3.73 The unaudited pro forma information is presented for illustration purposes only and is not necessarily indicative of the operating results that would have occurred had the Merger been completed at January 1, 2018, nor is it necessarily indicative of future operating results of the combined entity. The unaudited pro forma information for 2019 and 2018 is a result of combining the three and nine months statements of operations of Occidental with the pre-merger results from January 1, 2019, and 2018 of Anadarko and includes adjustments for revenues and direct expenses. The pro forma results exclude results from the Africa Assets and the impact of any merger-related costs. The pro forma results include adjustments to DD&A (Depreciation, depletion and amortization) based on the purchase price allocated to property, plant, and equipment and intangibles and the estimated useful lives as well as adjustments to interest expense. The pro forma adjustments include estimates and assumptions based on currently available information. Management believes the estimates and assumptions are reasonable, and the relative effects of the Merger are properly reflected. The unaudited pro forma information does not reflect any cost savings anticipated as a result of the Merger or any merger-related costs. Anadarko Merger-Related Costs The following table summarizes the merger-related costs incurred: millions Three months ended September 30, 2019 Nine months ended September 30, 2019 Employee severance and related cost $ 459 $ 459 Licensing fees for critical seismic data 329 354 Bank, legal and consulting fees 136 161 Total $ 924 $ 974 Employee severance and related cost primarily relates to one-time severance costs and the accelerated vesting of certain Anadarko share-based awards for former Anadarko employees based on the terms of the Merger Agreement and existing change of control provisions within the former Anadarko employment agreements. In addition, employee severance and related cost includes expenses for a voluntary separation program for eligible employees. Occidental initiated this program to align the size and composition of its workforce with its expected future operating and capital plans. Employee notifications related to the voluntary separation program were ongoing at September 30, 2019, with additional expenses associated with the program expected to be incurred throughout the remainder of 2019 and through most of 2020. The seismic licensing fees relate to relicensing of critical seismic data related to the Gulf of Mexico, Permian Basin and DJ Basin that Anadarko had licensed from third-party vendors. The third-party vendors who own the seismic data require a transfer fee in order for Occidental to use the data. Occidental Stock-based Incentive Plans On the date of the Merger, Occidental issued restricted share awards covering 1.7 million shares of common stock in exchange for Anadarko stock-based incentive shares to the former Anadarko employees. These restricted shares vest in periods ranging from one month to 3.5 years and are conditioned solely on the employees' continued service, with a weighted-average grant-date fair value of $47.13 and a weighted-average remaining life of 1.3

Acquisitions, Dispositions, and

Acquisitions, Dispositions, and Other Transactions	9 Months Ended
	Sep. 30, 2019
Discontinued Operations and Disposal Groups and Equity Method And Joint Ventures [Abstract]
Acquisitions, Dispositions, and Other Transactions	Acquisitions, Dispositions and Other Transactions On September 27, 2019, Occidental completed the sale of Anadarko’s Mozambique LNG assets to Total for $4.2 billion , with proceeds used to pay down a portion of the Term Loans. Occidental and Total continue to work toward completing the sales of the remaining Africa Assets. Occidental anticipates that the remaining sales will be completed before June 2020. The carrying amount of the remaining Africa Assets will be adjusted in future periods based on changes in fair value. The results of the Africa Assets are presented as discontinued operations in the Consolidated Condensed Statements of Operations and Cash Flows. The following table presents the amounts reported in discontinued operations, net of income taxes, related to the Africa Assets subsequent to the Merger closing date through September 30, 2019: millions 2019 REVENUES AND OTHER INCOME Net sales $ 228 COSTS AND OTHER DEDUCTIONS Oil and gas operating expense $ 32 Transportation and marketing expense 4 Taxes other than on income 46 Fair value adjustment on assets held for sale 65 Selling, general and administrative 8 Other 4 $ 159 Income before income taxes $ 69 Income tax expense (84 ) Discontinued operations, net of tax $ (15 ) The following table presents the amounts reported in the Consolidated Condensed Balance Sheets as held for sale related to the Africa Assets and other corporate property. millions September 30, 2019 Cash and cash equivalents $ 16 Inventories 207 Other current assets 110 Property, plant and equipment, net 5,863 Operating lease assets 29 Long-term receivables and other assets, net 220 Assets held for sale $ 6,445 Current maturities of debt - finance leases 13 Current operating lease liabilities 11 Accounts payable 217 Accrued liabilities 152 Long-term debt, net - finance leases 187 Deferred income taxes 1,281 Asset retirement obligations 142 Other 200 Liabilities of assets held for sale $ 2,203 Net assets held for sale $ 4,242 Sale of Plains Investment On September 23, 2019, Occidental sold its remaining equity investment in Plains All American Pipeline, L.P. and Plains GP Holdings, L.P. (together, Plains) for net proceeds of $646 million , which resulted in a pre-tax gain of $111 million . The proceeds were used to pay down a portion of the Term Loans. Ecopetrol Joint Venture On July 31, 2019, Occidental and Ecopetrol entered into definitive agreements to form a joint venture to develop approximately 97,000 net acres of Occidental’s Midland Basin properties in the Permian Basin. Ecopetrol will pay $750 million in cash at closing and $750 million of carried capital in exchange for a 49 -percent interest in the new venture. Occidental will own a 51 -percent interest and operate the joint venture. During the carry period, Ecopetrol will pay 75 -percent of Occidental’s share of capital expenditures, up to $750 million

Revenue Recognition

Revenue Recognition	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Revenue Recognition Revenue from customers is recognized when obligations under the terms of a contract with our customers are satisfied; this generally occurs with the delivery of oil, gas, NGL, chemicals or services, such as transportation. As of September 30, 2019 , trade receivables, net, of $5.9 billion represent rights to payment for which Occidental has satisfied its obligations under a contract and its right to payment is conditioned only on the passage of time. The following table shows a reconciliation of revenue from customers to total net sales: Three months ended September 30 Nine months ended September 30 millions 2019 2018 2019 2018 Revenue from customers $ 5,231 $ 4,257 $ 12,397 $ 11,813 All other revenues (a) 456 959 1,714 1,249 Net sales $ 5,687 $ 5,216 $ 14,111 $ 13,062 (a) Includes net marketing derivatives, oil collars and calls, and chemical exchange contracts. Disaggregation of Revenue from Contracts with Customers The following table presents Occidental's revenue from customers by segment, product and geographical area. The Oil and Gas segment typically sells its oil, gas and NGL at the lease or concession area. WES Midstream's operations are entirely in the United States. Chemical revenues are shown by geographic area based on the location of the sale. Excluding net marketing revenue, Marketing and Other Midstream revenues are shown by the location of sale: millions United States Middle East Latin America Other International Eliminations Total Three months ended September 30, 2019 Oil and Gas Oil $ 2,453 $ 683 $ 177 $ — $ — $ 3,313 NGL 177 63 — — — 240 Gas 125 78 5 — — 208 Other (18 ) 3 — — — (15 ) Segment total $ 2,737 $ 827 $ 182 $ — $ — $ 3,746 Chemical $ 1,009 $ — $ 36 $ 16 $ — $ 1,061 Marketing and Other Midstream Gas processing 93 81 — — — 174 Power and other 198 — — 37 — 235 Segment total $ 291 $ 81 $ — $ 37 $ — $ 409 WES Midstream $ 383 $ — $ — $ — $ — $ 383 Eliminations $ — $ — $ — $ — $ (368 ) $ (368 ) Consolidated $ 4,420 $ 908 $ 218 $ 53 $ (368 ) $ 5,231 millions United States Middle East Latin America Other International Eliminations Total Three months ended September 30, 2018 Oil and Gas Oil $ 1,326 $ 1,016 $ 197 $ — $ — $ 2,539 NGL 139 77 — — — 216 Gas 47 80 5 — — 132 Other 3 — (1 ) — — 2 Segment total $ 1,515 $ 1,173 $ 201 $ — $ — $ 2,889 Chemical $ 1,112 $ — $ 51 $ 21 $ — $ 1,184 Marketing and Other Midstream Gas processing 148 108 — — — 256 Pipelines 115 — — — — 115 Power and other 38 — — — — 38 Segment total $ 301 $ 108 $ — $ — $ — $ 409 Eliminations $ — $ — $ — $ — $ (225 ) $ (225 ) Consolidated $ 2,928 $ 1,281 $ 252 $ 21 $ (225 ) $ 4,257 millions United States Middle East Latin America Other International Eliminations Total Nine months ended September 30, 2019 Oil and Gas Oil $ 5,105 $ 2,266 $ 524 $ — $ — $ 7,895 NGL 339 196 — — — 535 Gas 180 233 14 — — 427 Other (40 ) (2 ) — — — (42 ) Segment total $ 5,584 $ 2,693 $ 538 $ — $ — $ 8,815 Chemical $ 2,937 $ — $ 119 $ 53 $ — $ 3,109 Marketing and Other Midstream Gas processing 302 272 — — — 574 Power and other 274 — — 37 — 311 Segment total $ 576 $ 272 $ — $ 37 $ — $ 885 WES Midstream $ 383 $ — $ — $ — $ — $ 383 Eliminations $ — $ — $ — $ — $ (795 ) $ (795 ) Consolidated $ 9,480 $ 2,965 $ 657 $ 90 $ (795 ) $ 12,397 millions United States Middle East Latin America Other International Eliminations Total Nine months ended September 30, 2018 Oil and Gas Oil $ 3,907 $ 2,507 $ 547 $ — $ — $ 6,961 NGL 339 192 — — — 531 Gas 141 218 12 — — 371 Other 10 1 — — — 11 Segment total $ 4,397 $ 2,918 $ 559 $ — $ — $ 7,874 Chemical $ 3,294 $ — $ 154 $ 59 $ — $ 3,507 Marketing and Other Midstream Gas processing 416 308 — — — 724 Pipelines 310 — — — — 310 Power and other 84 — — — — 84 Segment total $ 810 $ 308 $ — $ — $ — $ 1,118 Eliminations $ — $ — $ — $ — $ (686 ) $ (686 ) Consolidated $ 8,501 $ 3,226 $ 713 $ 59 $ (686 ) $ 11,813 Contract Liabilities Contract liabilities relate to WES fees and capital reimbursements that are charged to customers for only a portion of the contract term and must be recognized as revenues over the expected period of benefit, fixed and variable fees that are received from customers but revenue recognition is deferred under midstream cost of service contracts, and hard-minerals bonus payments received from customers that must be recognized as revenue over the expected period of benefit. The following table summarizes current period activity related to contract liabilities from contracts with customers: millions Balance at December 31, 2018 $ — Increase due to contract liabilities acquired with Anadarko 154 Increase due to cash received, excluding revenues recognized in the period 9 Decrease due to revenue recognized (13 ) Balance at September 30, 2019 $ 150 Transaction Price Allocated to Remaining Performance Obligations Revenue expected to be recognized from certain performance obligations that are unsatisfied as of September 30, 2019, is reflected in the table below. Occidental applies the optional exemptions in Topic 606 and does not disclose consideration for remaining performance obligations with an original expected duration of one year or less or for variable consideration related to unsatisfied performance obligations. As a result, the following table represents a small portion of Occidental's expected future consolidated revenues, as future revenue from the sale of most products and services is dependent on future production or variable customer volume and variable commodity prices for that volume: millions Oil and Gas WES Midstream Eliminations Total Remainder of 2019 $ 26 $ 193 $ (127 ) $ 92 2020 103 863 (589 ) 377 2021 103 912 (645 ) 370 2022 7 963 (703 ) 267 2023 7 915 (690 ) 232 Thereafter 60 4,399 (3,768 ) 691 Total $ 306 $ 8,245 $ (6,522 ) $ 2,029

Inventories

Inventories	9 Months Ended
	Sep. 30, 2019
Inventory Disclosure [Abstract]
Inventories	Inventories Commodity inventory and finished goods primarily represents crude oil, which is carried at the lower of weighted-average cost or market value, and caustic soda and chlorine, which are valued under the last-in, first-out (LIFO) method. Inventories consisted of the following: millions September 30, 2019 December 31, 2018 Raw materials $ 67 $ 74 Materials and supplies 916 445 Commodity inventory and finished goods 665 788 1,648 1,307 Revaluation to LIFO (47 ) (47 ) Total $ 1,601 $ 1,260

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments Occidental uses a variety of derivative financial instruments and physical contracts to manage its exposure to commodity-price fluctuations and transportation commitments, to fix margins on the future sale of stored commodity volumes and interest rate risks. Occidental also enters into derivative financial instruments for trading purposes. Occidental may elect normal purchases and normal sales exclusions when physically delivered commodities are purchased or sold to a customer. Occidental occasionally applies cash flow hedge accounting treatment to derivative financial instruments to lock in margins on the forecasted sales of its natural gas storage volumes, and at times for other strategies, such as to lock rates on forecasted debt issuances. Derivatives are carried at fair value and on a net basis when a legal right of offset exists with the same counterparty. Derivatives Not Designated as Hedging Instruments As of September 30, 2019, Occidental's derivatives not designated as hedges consist of three-way oil collars and call options, interest rate swaps, marketing derivatives and the Warrant. Derivative instruments that are derivatives not designated as hedging instruments are required to be recorded on the statement of operations and balance sheet at fair value. Changes in fair value will impact Occidental's earnings through mark-to-market adjustments until the physical commodity is delivered or the financial instrument is settled. The fair value does not reflect the realized or cash value of the instrument. Three-way Oil Collars and Call Options In July 2019, Occidental entered into three-way costless collar derivative instruments for 2020 and additional call options in 2021 to manage its near-term exposure to cash-flow variability from commodity-price risks. A three-way collar is a combination of three options: a sold call, a purchased put and a sold put. The sold call establishes the ceiling price that Occidental will receive for the contracted commodity volume for a defined period of time. The purchased put establishes the floor price that Occidental will receive for the contracted volumes unless the market price for the commodity falls below the sold put strike price, at which point the floor price equals the reference price plus the difference between the purchased put strike price and the sold put strike price for a defined period of time. Occidental entered into the 2021 call options to substantially improve the ceiling price that Occidental will receive for the contracted commodity volumes in 2020. In the Merger, Occidental also assumed three-way costless collars that expire throughout the rest of 2019. Net gains and losses associated with collars and calls are recognized currently in net sales. Hedge accounting was not elected for these contracts. Occidental had the following collars and calls outstanding at September 30, 2019 : Collars and Calls, not designated as hedges 2019 Settlement Three-way collars (Oil MMBL) 8.0 Average price per barrel (NYMEX/Brent oil pricing) Ceiling sold price (call) $ 72.98 Floor purchased price (put) $ 56.72 Floor sold price (put) $ 46.72 2020 Settlement Three-way collars (Oil MMBL) 109.8 Average price per barrel (Brent oil pricing) Ceiling sold price (call) $ 74.09 Floor purchased price (put) $ 55.00 Floor sold price (put) $ 45.00 2021 Settlement Call Options sold (Oil MMBL) 109.5 Average price per barrel (Brent oil pricing) Ceiling sold price (call) $ 74.09 Occidental Interest Rate Swaps (Excluding WES Midstream) Occidental acquired interest rate swap contracts in the Merger. The contracts lock in a fixed interest rate in exchange for a floating interest rate indexed to three-month London Inter-Bank Offered Rate (LIBOR) throughout the reference period. Net gains and losses associated with interest rate derivative instruments not designated as hedging instruments are recognized currently in losses on interest rate swaps and warrants, net. Occidental had the following outstanding interest rate swaps at September 30, 2019 : millions except percentages Mandatory Weighted-Average Notional Principal Amount Reference Period Termination Date Interest Rate $ 125 September 2016 - 2046 October 2019 6.782 % $ 550 September 2016 - 2046 September 2020 6.418 % $ 125 September 2016 - 2046 September 2022 6.835 % $ 100 September 2017 - 2047 September 2020 6.891 % $ 250 September 2017 - 2047 September 2021 6.570 % $ 450 September 2017 - 2047 September 2023 6.445 % Depending on market conditions, liability-management actions or other factors, Occidental may enter into offsetting interest rate swap positions or settle or amend certain or all of the currently outstanding interest rate swaps. Derivative settlements and collateralization are classified as cash flows from operating activities unless the derivatives contain an other-than-insignificant financing element, in which case the settlements and collateralization are classified as cash flows from financing activities. As a result of prior extensions of reference-period start dates without settlement of the related interest rate derivative obligations, the interest rate derivatives in Occidental's portfolio contain an other-than-insignificant financing element, and therefore, any settlements, collateralization or cash payments for amendments related to these extended interest rate derivatives are classified as cash flows from financing activities. Net cash payments related to settlements and amendments of interest rate swap agreements were $43 million during the period from August 8, 2019, through September 30, 2019 . Subsequent to September 30, 2019, Occidental settled interest rate swaps that had a mandatory termination date of October 11, 2019, and a notional value of $125 million . WES Interest Rate Swaps In the Merger, Occidental also acquired interest rate swap contracts held by WES. WES exchanged a floating interest rate indexed to the three-month LIBOR for a fixed interest rate. Net gains and losses associated with these interest rate derivative instruments are recognized currently in losses on interest rate swaps and warrants, net. The following interest rate swaps were outstanding at September 30, 2019 : millions except percentages Mandatory Weighted-Average Notional Principal Amount Reference Period Termination Date Interest Rate $ 375 December 2019 - 2024 December 2019 2.662 % $ 375 December 2019 - 2029 December 2019 2.802 % $ 375 December 2019 - 2049 December 2019 2.885 % Depending on market conditions, liability-management actions, or other factors, WES may settle or amend certain or all of the currently outstanding interest rate swaps. Marketing Derivatives Occidental's marketing derivative instruments not designated as hedges are physical and financial forward contracts which typically settle within three months . A substantial majority of Occidental's physically settled derivative contracts are index-based and carry no mark-to-market valuation in earnings. These instruments settle at a weighted-average contract price of $58.39 per barrel and $2.22 per thousand cubic feet (Mcf) for crude oil and natural gas, respectively, at September 30, 2019 . The weighted-average contract price was $58.81 per barrel and $3.18 per Mcf for crude oil and natural gas, respectively, at December 31, 2018. Net gains and losses associated with marketing derivative instruments not designated as hedging instruments are recognized currently in net sales. The following table summarizes net long/(short) volumes associated with the outstanding marketing commodity derivatives not designated as hedging instruments as of September 30, 2019 , and December 31, 2018 . 2019 2018 Crude Oil Commodity Contracts Volume (MMBL) 36 61 Natural Gas Commodity Contracts Volume (Bcf) (128 ) (142 ) The Warrant The Warrant issued with the Preferred Stock in connection with the Merger is exercisable at the holder's option, in whole or in part, until the first anniversary of the date on which no shares of Preferred Stock remain outstanding at which point the Warrant expires. The holder of the Warrant may require net cash settlement if certain shareholder and regulatory approvals to issue Occidental common stock are not obtained on a timely basis. The initial fair value of the Warrant, $188 million , was measured at the date of the Merger using the Black Scholes option model. The following inputs were used in the Black Scholes option model; the expected life is based on the estimated term of the Warrant, the volatility factor is based on historical volatilities of Occidental common stock, and the call option price for Occidental common stock at $62.50 . The fair value of the Warrant is remeasured each reporting period based on changes in the inputs above. Derivatives Designated as Hedging Instruments Net gains and losses attributable to derivative instruments subject to cash flow hedge accounting reside in accumulated other comprehensive loss and are reclassified to earnings as the transactions to which the derivatives relate are recognized in earnings. Cash Flow Hedges Occidental’s marketing operations store natural gas purchased from third parties at Occidental’s leased storage facilities. Derivative instruments are used to fix margins on the future sales of the stored volumes. As of September 30, 2019 , Occidental had approximately 5 billion cubic feet (Bcf) of natural gas held in storage, and had cash flow hedges for the forecast sales, to be settled by physical delivery, of approximately 3 Bcf of stored natural gas. As of December 31, 2018 , Occidental had approximately 5 Bcf of natural gas held in storage, and had cash flow hedges for the forecasted sales, to be settled by physical delivery, of approximately 4 Bcf of stored natural gas. The fair value of the cash flow hedges associated with stored natural gas was immaterial at September 30, 2019 and December 31, 2018. The ineffective portion recognized through earnings was immaterial for the nine months ended September 30, 2019 , and the year ended December 31, 2018. In June 2019, in anticipation of issuing debt in the third quarter to partially finance the cash portion of the Merger consideration, Occidental entered into a series of U.S. treasury locks which were designated as cash flow hedges. In August 2019, the U.S. treasury locks were unwound with the issuance of the $13.0 billion new senior unsecured notes, and the resulting after-tax accumulated other comprehensive loss of $125 million will be amortized to interest expense over the life of the underlying senior notes. Fair Value of Derivatives The following tables present the fair values of Occidental’s outstanding derivatives. Fair values are presented at gross amounts, including when the derivatives are subject to master netting arrangements, and are presented on a net basis in the Consolidated Condensed Balance Sheets. Balance Sheet Classification Fair-Value Measurements Using Netting (a) Total Fair Value millions Level 1 Level 2 Level 3 September 30, 2019 Oil Collars and Calls Other current assets $ — $ 217 $ — $ (4 ) $ 213 Accrued liabilities — 3 — (3 ) — Deferred credits and other liabilities - other — 97 — — 97 Marketing Derivatives Other current assets 838 97 — (861 ) 74 Long-term receivables and other assets, net 70 12 — (70 ) 12 Accrued liabilities 827 45 — (861 ) 11 Deferred credits and other liabilities - other 71 1 — (70 ) 2 Interest Rate Swaps (excluding WES) Other current assets — 14 — — 14 Long-term receivables and other assets, net — 13 — — 13 Accrued liabilities — 882 — — 882 Deferred credits and other liabilities - other — 879 — — 879 WES Interest Rate Swaps Accrued liabilities — 171 — — 171 Warrant Deferred credits and other liabilities - other — 168 — — 168 December 31, 2018 Marketing Derivatives Other current assets $ 2,531 $ 110 $ — $ (2,392 ) $ 249 Long-term receivables and other assets, net 5 9 — (6 ) 8 Accrued liabilities 2,357 101 — (2,392 ) 66 Deferred credits and other liabilities - other 6 2 — (6 ) 2 (a) These amounts do not include collateral. As of September 30, 2019 , $359 million of collateral has been netted against derivative liabilities related to interest rate swaps. Occidental had $ 36 million of initial margin deposited with brokers as of September 30, 2019 , related to marketing derivatives. As of December 31, 2018, $ 45 million collateral received has been netted against derivative assets, and collateral posted of $ 1 million has been netted against derivative liabilities. Occidental had $ 178 million of initial margin deposited with brokers as of December 31, 2018. Initial margin is included in other current assets in the Consolidated Condensed Balance Sheets and has not been reflected in these derivative fair-value tables. Gains and Losses on Derivatives The following table presents the effect of Occidental's derivative instruments on the Consolidated Condensed Statements of Operations: Income Statement Classification Three months ended September 30 Nine months ended September 30 millions 2019 2018 2019 2018 Oil Collars and Calls Net sales $ 75 $ — $ 75 $ — Marketing Derivatives Net sales 91 36 (119 ) 8 Interest Rate Swaps (Excluding WES) Losses on interest rate swaps and warrants, net (45 ) — (45 ) — Interest Rate Swaps (WES) Losses on interest rate swaps and warrants, net (8 ) — (8 ) — Warrants Gains on interest rate swaps and warrants, net 20 — 20 — Credit Risk Occidental's counterparty credit risk related to the physical delivery of energy commodities results from its customers' potential inability to meet their settlement commitments. Occidental manages credit risk by selecting counterparties that it believes to be financially strong, by entering into netting arrangements with counterparties and by requiring collateral or other credit risk mitigants, as appropriate. Occidental actively evaluates the creditworthiness of its counterparties, assigns appropriate credit limits and monitors credit exposures against those assigned limits. Occidental also enters into future contracts through regulated exchanges with select clearinghouses and brokers, which are subject to minimal credit risk as a significant portion of these transactions settle on a daily margin basis. Certain over-the-counter derivative instruments contain credit-risk-contingent features, primarily tied to credit ratings for Occidental or its counterparties, which may affect the amount of collateral that each party would need to post. The aggregate fair value of derivative instruments with credit-risk-related contingent features for which a net liability position existed at September 30, 2019 was $1.6 billion (net of $0.3 billion collateral), primarily related to acquired interest-rate swaps, and $68 million (net of $1 million of collateral) existed at December 31, 2018 .

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair-Value Measurements Occidental has categorized its assets and liabilities that are measured at fair value in a three-level fair-value hierarchy, based on the inputs to the valuation techniques: Level 1 — using quoted prices in active markets for the assets or liabilities; Level 2 — using observable inputs other than quoted prices for the assets or liabilities; and Level 3 — using unobservable inputs. Transfers between levels, if any, are recognized at the end of each reporting period. Fair Values — Recurring In January 2012, Occidental entered into a long-term contract to purchase CO 2 . This contract contains a price adjustment clause that is linked to changes in NYMEX crude oil prices. Occidental determined that the portion of this contract linked to NYMEX oil prices is not clearly and closely related to the host contract, and Occidental therefore bifurcated this embedded pricing feature from its host contract and accounts for it at fair value in the Consolidated Condensed Financial Statements. The following tables provide fair-value measurement information for embedded derivatives that are measured on a recurring basis: millions Fair-Value Measurements Using Embedded derivatives Level 1 Level 2 Level 3 Netting and Total Fair As of September 30, 2019 Accrued liabilities $ — $ 54 $ — $ — $ 54 Deferred credits and other liabilities - other — 73 — — 73 As of December 31, 2018 Accrued liabilities $ — $ 66 $ — $ — $ 66 Deferred credits and other liabilities - other — 116 — — 116 Fair-Values — Nonrecurring During the nine months ended September 30, 2019 , Occidental measured assets and liabilities at merger-date fair value on a nonrecurring basis related to the Merger. See Note 3 - The Merger for more detail. During the three and nine months ended September 30, 2019, Occidental's Oil and Gas segment recognized pre-tax impairment and related charges of $285 million related to domestic undeveloped leases that were set to expire in the near term, where Occidental had no plans to pursue exploration activities, and $40 million related to Occidental's mutually agreed early termination of its Qatar Idd El Shargi South Dome (ISSD) contract. During 2018, Occidental recognized pre-tax impairment and related charges of $416 million primarily related to Idd El Shargi North Dome (ISND) and ISSD proved properties and inventory. The fair value of the proved properties was measured based on the income approach, which incorporated a number of assumptions involving expectations of future cash flows. These assumptions included estimates of future product prices, which Occidental based on forward price curves, estimates of oil and gas reserves, estimates of future expected operating and capital costs and a risk-adjusted discount rate of 10 percent. These inputs are categorized as Level 3 in the fair-value hierarchy. Other Financial Instruments The carrying amounts of cash and cash equivalents and other on-balance-sheet financial instruments, other than long-term, fixed-rate debt, approximate fair value. The cost, if any, to terminate Occidental's off-balance-sheet financial instruments is not significant. Occidental estimates the fair value of fixed-rate debt based on the quoted market prices for those instruments or on quoted market yields for similarly rated debt instruments, taking into account such instruments’ maturities. The estimated fair value of Occidental’s debt as of September 30, 2019 , was $47.8 billion , which included $7.6 billion in debt related to WES. The majority of Occidental's debt is classified as Level 1, with $12.5 billion classified as Level 2. At December 31, 2018 , the estimated fair value of Occidental's debt was $10.3 billion

Long-Term Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt consisted of the following: millions Balance at September 30, 2019 Occidental 4.850% senior notes due 2021 $ 677 2.600% senior notes due 2021 1,500 4.100% senior notes due 2021 1,249 Variable rate bonds due 2021 (3.137% as of September 30, 2019) 500 Variable rate bonds due 2021 (3.437% as of September 30, 2019) 500 2-year variable rate Term Loan due 2021 (3.417% as of September 30, 2019) 3,966 2.700% senior notes due 2022 2,000 3.125% senior notes due 2022 814 2.600% senior notes due 2022 400 Variable rate bonds due 2022 (3.637% as of September 30, 2019) 1,500 2.700% senior notes due 2023 1,191 8.750% medium-term notes due 2023 22 2.900% senior notes due 2024 3,000 6.950% senior notes due 2024 650 3.450% senior notes due 2024 248 3.500% senior notes due 2025 750 5.550% senior notes due 2026 1,100 3.200% senior notes due 2026 1,000 3.400% senior notes due 2026 1,150 7.500% debentures due 2026 112 3.000% senior notes due 2027 750 7.125% debentures due 2027 150 7.000% debentures due 2027 48 6.625% debentures due 2028 14 7.150% debentures due 2028 235 7.200% senior debentures due 2028 82 7.200% debentures due 2029 135 7.950% debentures due 2029 116 8.450% senior debentures due 2029 116 3.500 senior notes due 2029 1,500 Variable rate bonds due 2030 (1.785% as of September 30, 2019) 68 7.500% senior notes due 2031 900 7.875% senior notes due 2031 500 6.450% senior notes due 2036 1,750 Zero Coupon senior notes due 2036 2,271 4.300% senior notes due 2039 750 7.950% senior notes due 2039 325 6.200% senior notes due 2040 750 4.500% senior notes due 2044 625 4.625% senior notes due 2045 750 6.600% senior notes due 2046 1,100 4.400% senior notes due 2046 1,200 4.100% senior notes due 2047 750 4.200% senior notes due 2048 1,000 4.400% senior notes due 2049 750 7.730% debentures due 2096 60 7.500% debentures due 2096 78 7.250% debentures due 2096 49 Total borrowings at face value (a) 39,151 Adjustments to book value: Unamortized premium, net 859 Debt issuance costs (133 ) Long-term finance leases 69 Long-term Debt, net - Occidental $ 39,946 (a) Total borrowings at face value also includes a $310 thousand 7.25% senior note due 2025 millions Balance at September 30, 2019 WES 5.375% senior notes due 2021 $ 500 4.000% senior notes due 2022 670 3.950% senior notes due 2025 500 4.650% senior notes due 2026 500 4.500% senior notes due 2028 400 4.750% senior notes due 2028 400 5.450% senior notes due 2044 600 5.300% senior notes due 2048 700 5.500% senior notes due 2048 350 WES Term Loan Facility (3.420% as of September 30, 2019) 3,000 WES revolving credit facility (3.340% as of September 30,2019) 160 Total borrowings at face value $ 7,780 Adjustments to book value: Unamortized discount net (135 ) Debt issuance costs (8 ) Long-term Debt, net - WES $ 7,637 Occidental Consolidated Total borrowings at face value $ 46,931 Adjustments to book value: Unamortized premium, net 724 Debt issuance costs (141 ) Long-term finance leases 69 Total Occidental Consolidated Long-term Debt $ 47,583 millions Balance at December 31, 2018 Occidental 9.250% senior debentures due 2019 $ 116 4.100% senior notes due 2021 1,249 3.125% senior notes due 2022 813 2.600% senior notes due 2022 400 2.700% senior notes due 2023 1,191 8.750% medium-term notes due 2023 22 3.500% senior notes due 2025 750 3.400% senior notes due 2026 1,150 3.000% senior notes due 2027 750 7.200% senior debentures due 2028 82 8.450% senior debentures due 2029 116 4.625% senior notes due 2045 750 4.400% senior notes due 2046 1,200 4.100% senior notes due 2047 750 4.200% senior notes due 2048 1,000 Variable rate bonds due 2030 (1.9% as of December 31, 2018) 68 10,407 Adjustments to book value: Unamortized discount, net (36 ) Debt issuance costs (54 ) Current maturities (116 ) Total Occidental Consolidated Long-term Debt $ 10,201 Debt Issued On August 8, 2019, Occidental issued $13.0 billion of new senior unsecured notes, consisting of both floating and fixed rate debt. Occidental also borrowed under the Term Loans, which consist of: (1) a 364 -day senior unsecured variable-rate term loan tranche of $4.4 billion and (2) a two-year senior unsecured variable-rate term loan tranche of $4.4 billion . In total, the $21.8 billion in debt issued was used to finance part of the cash portion of the purchase price for the Merger. Debt Assumed as Part of the Merger In the Merger, Occidental assumed Anadarko and WES debt with an outstanding principal balance of $11.9 billion and $4.6 billion , respectively. In addition, WES had borrowings of $2.9 billion under an RCF and term loan facilities at the Merger date. Debt assumed from Anadarko and WES was recorded at fair value at the Merger date, refer to Note 3 - The Merger . In September 2019, Occidental completed its offers to exchange the Anadarko senior notes and debentures assumed as part of the Merger for notes of a corresponding series issued by Occidental and cash, and related solicitation of consents. Of the approximately $11.9 billion in aggregate principal amount of Anadarko senior notes and debentures offered in the exchange, 97 percent , or approximately $11.5 billion , were tendered and accepted in the exchange offers. The portion not exchanged, approximately $400 million , remains outstanding with the original terms. Debt Repayment In September 2019, Occidental paid down $4.8 billion on the Term Loans, primarily using proceeds from the sales of both the Anadarko Mozambique LNG asset and Occidental's equity investment in Plains. WES Debt Debt related to WES included $4.6 billion in senior unsecured notes, $3.0 billion under the WES Term Loan Facility due December 2020, and $160 million drawn against the WES RCF at September 30, 2019. The WES Term Loan Facility has a maturity date of December 31, 2020 and requires that net cash proceeds received from future asset sales and debt or equity offerings must be used to repay amounts outstanding under the facility, with a $1.0 billion exclusion for debt offering proceeds. The WES RCF has a maturity date of February 2024 and a borrowing capacity of $2.0 billion . In September 2019, WES borrowed $1.0 billion under the WES Term Loan Facility and used the funds to repay borrowings under the WES RCF. Revolving Credit Facility On June 3, 2019, Occidental entered into an amendment to its existing $3.0 billion revolving credit facility (Occidental RCF) pursuant to which, among other things, the commitments under the Occidental RCF were increased to $5.0 billion at the closing of the Merger. Borrowings under the Occidental RCF bear interest at various benchmark rates, including LIBOR, plus a margin based on Occidental's senior debt ratings. The facility has similar terms to other debt agreements and does not contain material adverse change clauses or debt-ratings triggers that could restrict Occidental's ability to borrow, or that would permit lenders to terminate their commitments or accelerate debt repayment. The facility provides for the termination of loan commitments and requires immediate repayment of any outstanding amounts if certain events of default occur. Occidental has not drawn down any amounts under the Occidental RCF. Zero Coupon Notes Due 2036 The Zero Coupon senior notes due 2036 (Zero Coupons) have an aggregate principal amount due at maturity of approximately $2.3 billion , reflecting an accretion rate of 5.24% . The Zero Coupons can be put to Occidental in October of each year, in whole or in part, for the then-accreted value of the outstanding Zero Coupons. None of the Zero Coupons were put to Occidental in October 2019. The Zero Coupons can next be put to Occidental in October 2020, which, if put in whole, would be $992 million at such date. Occidental has the ability and intent to refinance these obligations using long-term debt should a put be exercised.

Lease Commitments

Lease Commitments	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Lease Commitments	Lease Commitments On January 1, 2019, Occidental adopted ASC 842 using the modified retrospective approach, which provided a method for recording existing leases at adoption and did not require restatement of prior year amounts and disclosures, which continue to be reflected in accordance with ASC 840. Occidental elected certain practical expedients as follows: • Leases that commenced before the effective date carried forward their historical lease classification. • Existing or expired land easements as of December 31, 2018, were not reassessed to determine whether or not they contained a lease. • Leases with a lease term of 12 months or less from lease commencement date are considered short-term leases and not recorded on the Consolidated Condensed Balance Sheet; however, the lease expenditures recognized are captured and reported as incurred. • For asset classes, except long-term drilling rigs, Occidental elected to account for the lease and non-lease components as a single lease component as the non-lease portions were not significant to separate in determining the lease liability. For long-term drilling rig contracts, Occidental bifurcated the lease and non-lease components using relative fair value as a stand-alone selling price between the asset rental and the services obtained. ASC 842 requires lessees to recognize a ROU asset and lease liability for all long-term leases. A ROU asset represents Occidental’s right to use an underlying asset for the lease term and the associated lease liability represents the discounted obligation of future minimum lease payments. Occidental identifies leases through its accounts payable and contract monitoring process. Operating lease ROU assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease term. The ROU assets include the discounted obligation in addition to any upfront payments or costs incurred during the contract execution of the lease and amortized on a straight-line basis over the course of the lease term. Except for leases with explicitly defined contract terms, Occidental utilizes judgment to assess likelihood of renewals, terminations and purchase options, in order to determine the lease term. Occidental uses the incremental borrowing rate at commencement date to determine the present value of lease payments. The incremental borrowing rate equates to the rate of interest that Occidental would have to pay to borrow on a collateralized basis over a similar term an amount equal to the lease payments in a similar economic environment. Certain leases include variable lease payments which are over and above the minimum lease liability used to derive the ROU asset and lease liability and are based on the underlying asset’s operations. These variable lease costs are reported in the lease cost classification table. Recognition, measurement, and presentation of expenses and cash flows arising from a lease will depend on classification as a finance or operating lease. The criteria for distinguishing between finance and operating leases are substantially similar to the criteria under ASC 840. For Occidental operations, adoption of ASC 842 resulted in recording of net lease assets and lease liabilities of $772 million as of January 1, 2019. There was no material impact to net income, cash flows, or stockholders’ equity. Merger Impact ASC 805 Business Combinations requires lease-related assets and liabilities acquired to be measured as if the lease were new at the merger date. Occidental measured the Anadarko legacy lease agreements using an updated incremental borrowing rate curve. This resulted in legacy Anadarko assets and liabilities of $498 million and $574 million , respectively, excluding the Africa Assets at the Merger date. These agreements are still under further review for above-or below-market impacts. The following table reconciles the undiscounted cash flows related to the operating and finance lease liabilities assumed in the Merger and recorded on the Consolidated Condensed Balance Sheet at the Merger date: millions Operating Leases Finance Leases Total Remainder of 2019 $ 90 $ 7 $ 97 2020 172 25 197 2021 64 15 79 2022 42 12 54 2023 28 7 35 Thereafter 136 42 178 Total lease payments 532 108 640 Less: Interest (44 ) (22 ) (66 ) Total lease liabilities $ 488 $ 86 $ 574 Additionally, Occidental has elected short-term lease treatment for those acquired lease contracts which, at the Merger date, have a remaining lease term of 12 months or less. For the leases acquired through the Merger, Occidental will retain the previous lease classification. Nature of Leases Occidental’s operating lease agreements include leases for oil and gas exploration and development equipment, including offshore and onshore drilling rigs of $186 million , compressors of $174 million and other field equipment of $97 million , which are recorded gross on the Consolidated Condensed Balance Sheet and in the lease cost disclosures below. Contract expiration terms generally range from two to seven years . Further, actual expenditures are netted against joint-interest recoveries on the income statement through the normal joint-interest billing process. Occidental’s leases also include pipelines, rail cars, storage facilities, easements and real estate of $682 million , which typically are not associated with joint-interest recoveries. Real estate leases have contract expiration terms ranging from 1 to 16 years . Occidental’s finance lease agreements include leases for oil and gas exploration and development equipment, as well as real estate offices, compressors, and field equipment of approximately $100 million . The following table presents lease balances and their location on the Consolidated Condensed Balance Sheet at September 30, 2019: millions Balance sheet location 2019 Assets: Operating Operating lease assets $ 1,078 Finance Property, plant and equipment 97 Total lease assets $ 1,175 Liabilities: Current Operating Current operating lease liabilities $ 463 Finance Current maturities of long-term debt 31 Non-current Operating Deferred credits and other liabilities - Operating lease liabilities 676 Finance Long-term debt, net - Occidental 69 Total lease liabilities $ 1,239 At September 30, 2019 , Occidental's leases expire based on the following schedule: Operating Finance millions Leases (a) Leases (b) Total Remainder of 2019 $ 119 $ 8 $ 127 2020 390 38 428 2021 197 15 212 2022 129 12 141 2023 94 7 101 Thereafter 311 42 353 Total lease payments 1,240 122 1,362 Less: Interest (101 ) (22 ) (123 ) Total lease liabilities $ 1,139 $ 100 $ 1,239 (a) The weighted-average remaining lease term is 5.3 years and the weighted-average discount rate is 2.79% . (b) The weighted-average remaining lease term is 6.4 years and the weighted-average discount rate is 4.92% . At December 31, 2018 , future undiscounted net minimum fixed lease payments for non-cancellable operating leases, prepared in accordance with accounting standards prior to the adoption of ASC 842, were as follows: Operating millions Leases 2019 $ 186 2020 147 2021 96 2022 68 2023 49 Thereafter 158 Total minimum lease payments (a) $ 704 (a) The amount represents the future undiscounted cash flows at December 31, 2018, excluding any amount associated with the Merger. The following tables present Occidental's total lease cost and classifications, as well as cash paid for amounts included in the measurement of operating and finance lease liabilities. Lease cost classification (a) Three months ended September 30, 2019 Nine months ended September 30, 2019 millions Operating lease costs (b) Property, plant and equipment, net $ 139 $ 321 Cost of sales 133 271 Selling, general and administrative expenses 26 61 Finance lease cost Amortization of ROU assets 5 11 Interest on lease liabilities 1 1 $ 304 $ 665 (a) Amounts reflected are gross before joint-interest recoveries. (b) Includes short-term lease cost of $139 million and $295 million for the three and nine months ended September 30, 2019, respectively, and variable lease cost of $55 million and $115 million for the three and nine months ended September 30, 2019, respectively. millions Nine months ended September 30, 2019 Operating cash flows $ 162 Investing cash flows 83 Financing cash flows 11
Lease Commitments	Lease Commitments On January 1, 2019, Occidental adopted ASC 842 using the modified retrospective approach, which provided a method for recording existing leases at adoption and did not require restatement of prior year amounts and disclosures, which continue to be reflected in accordance with ASC 840. Occidental elected certain practical expedients as follows: • Leases that commenced before the effective date carried forward their historical lease classification. • Existing or expired land easements as of December 31, 2018, were not reassessed to determine whether or not they contained a lease. • Leases with a lease term of 12 months or less from lease commencement date are considered short-term leases and not recorded on the Consolidated Condensed Balance Sheet; however, the lease expenditures recognized are captured and reported as incurred. • For asset classes, except long-term drilling rigs, Occidental elected to account for the lease and non-lease components as a single lease component as the non-lease portions were not significant to separate in determining the lease liability. For long-term drilling rig contracts, Occidental bifurcated the lease and non-lease components using relative fair value as a stand-alone selling price between the asset rental and the services obtained. ASC 842 requires lessees to recognize a ROU asset and lease liability for all long-term leases. A ROU asset represents Occidental’s right to use an underlying asset for the lease term and the associated lease liability represents the discounted obligation of future minimum lease payments. Occidental identifies leases through its accounts payable and contract monitoring process. Operating lease ROU assets and liabilities are recognized at commencement date based on the present value of lease payments over the lease term. The ROU assets include the discounted obligation in addition to any upfront payments or costs incurred during the contract execution of the lease and amortized on a straight-line basis over the course of the lease term. Except for leases with explicitly defined contract terms, Occidental utilizes judgment to assess likelihood of renewals, terminations and purchase options, in order to determine the lease term. Occidental uses the incremental borrowing rate at commencement date to determine the present value of lease payments. The incremental borrowing rate equates to the rate of interest that Occidental would have to pay to borrow on a collateralized basis over a similar term an amount equal to the lease payments in a similar economic environment. Certain leases include variable lease payments which are over and above the minimum lease liability used to derive the ROU asset and lease liability and are based on the underlying asset’s operations. These variable lease costs are reported in the lease cost classification table. Recognition, measurement, and presentation of expenses and cash flows arising from a lease will depend on classification as a finance or operating lease. The criteria for distinguishing between finance and operating leases are substantially similar to the criteria under ASC 840. For Occidental operations, adoption of ASC 842 resulted in recording of net lease assets and lease liabilities of $772 million as of January 1, 2019. There was no material impact to net income, cash flows, or stockholders’ equity. Merger Impact ASC 805 Business Combinations requires lease-related assets and liabilities acquired to be measured as if the lease were new at the merger date. Occidental measured the Anadarko legacy lease agreements using an updated incremental borrowing rate curve. This resulted in legacy Anadarko assets and liabilities of $498 million and $574 million , respectively, excluding the Africa Assets at the Merger date. These agreements are still under further review for above-or below-market impacts. The following table reconciles the undiscounted cash flows related to the operating and finance lease liabilities assumed in the Merger and recorded on the Consolidated Condensed Balance Sheet at the Merger date: millions Operating Leases Finance Leases Total Remainder of 2019 $ 90 $ 7 $ 97 2020 172 25 197 2021 64 15 79 2022 42 12 54 2023 28 7 35 Thereafter 136 42 178 Total lease payments 532 108 640 Less: Interest (44 ) (22 ) (66 ) Total lease liabilities $ 488 $ 86 $ 574 Additionally, Occidental has elected short-term lease treatment for those acquired lease contracts which, at the Merger date, have a remaining lease term of 12 months or less. For the leases acquired through the Merger, Occidental will retain the previous lease classification. Nature of Leases Occidental’s operating lease agreements include leases for oil and gas exploration and development equipment, including offshore and onshore drilling rigs of $186 million , compressors of $174 million and other field equipment of $97 million , which are recorded gross on the Consolidated Condensed Balance Sheet and in the lease cost disclosures below. Contract expiration terms generally range from two to seven years . Further, actual expenditures are netted against joint-interest recoveries on the income statement through the normal joint-interest billing process. Occidental’s leases also include pipelines, rail cars, storage facilities, easements and real estate of $682 million , which typically are not associated with joint-interest recoveries. Real estate leases have contract expiration terms ranging from 1 to 16 years . Occidental’s finance lease agreements include leases for oil and gas exploration and development equipment, as well as real estate offices, compressors, and field equipment of approximately $100 million . The following table presents lease balances and their location on the Consolidated Condensed Balance Sheet at September 30, 2019: millions Balance sheet location 2019 Assets: Operating Operating lease assets $ 1,078 Finance Property, plant and equipment 97 Total lease assets $ 1,175 Liabilities: Current Operating Current operating lease liabilities $ 463 Finance Current maturities of long-term debt 31 Non-current Operating Deferred credits and other liabilities - Operating lease liabilities 676 Finance Long-term debt, net - Occidental 69 Total lease liabilities $ 1,239 At September 30, 2019 , Occidental's leases expire based on the following schedule: Operating Finance millions Leases (a) Leases (b) Total Remainder of 2019 $ 119 $ 8 $ 127 2020 390 38 428 2021 197 15 212 2022 129 12 141 2023 94 7 101 Thereafter 311 42 353 Total lease payments 1,240 122 1,362 Less: Interest (101 ) (22 ) (123 ) Total lease liabilities $ 1,139 $ 100 $ 1,239 (a) The weighted-average remaining lease term is 5.3 years and the weighted-average discount rate is 2.79% . (b) The weighted-average remaining lease term is 6.4 years and the weighted-average discount rate is 4.92% . At December 31, 2018 , future undiscounted net minimum fixed lease payments for non-cancellable operating leases, prepared in accordance with accounting standards prior to the adoption of ASC 842, were as follows: Operating millions Leases 2019 $ 186 2020 147 2021 96 2022 68 2023 49 Thereafter 158 Total minimum lease payments (a) $ 704 (a) The amount represents the future undiscounted cash flows at December 31, 2018, excluding any amount associated with the Merger. The following tables present Occidental's total lease cost and classifications, as well as cash paid for amounts included in the measurement of operating and finance lease liabilities. Lease cost classification (a) Three months ended September 30, 2019 Nine months ended September 30, 2019 millions Operating lease costs (b) Property, plant and equipment, net $ 139 $ 321 Cost of sales 133 271 Selling, general and administrative expenses 26 61 Finance lease cost Amortization of ROU assets 5 11 Interest on lease liabilities 1 1 $ 304 $ 665 (a) Amounts reflected are gross before joint-interest recoveries. (b) Includes short-term lease cost of $139 million and $295 million for the three and nine months ended September 30, 2019, respectively, and variable lease cost of $55 million and $115 million for the three and nine months ended September 30, 2019, respectively. millions Nine months ended September 30, 2019 Operating cash flows $ 162 Investing cash flows 83 Financing cash flows 11

Lawsuits, Claims, Commitments a

Lawsuits, Claims, Commitments and Contingencies	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Lawsuits, Claims, Commitments and Contingencies	Lawsuits, Claims, Commitments and Contingencies Legal Matters Occidental or certain of its subsidiaries are involved, in the normal course of business, in lawsuits, claims and other legal proceedings that seek, among other things, compensation for alleged personal injury, breach of contract, property damage or other losses, punitive damages, civil penalties, or injunctive or declaratory relief. Occidental or certain of its subsidiaries also are involved in proceedings under Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) and similar federal, state, local and foreign environmental laws. These environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, punitive damages, civil penalties and injunctive relief. Usually Occidental or such subsidiaries are among many companies in these environmental proceedings and have to date been successful in sharing response costs with other financially sound companies. Further, some lawsuits, claims and legal proceedings involve acquired or disposed assets with respect to which a third party or Occidental retains liability or indemnifies the other party for conditions that existed prior to the transaction. In accordance with applicable accounting guidance, Occidental accrues reserves for outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the liability can be reasonably estimated. In Note 12 - Environmental Liabilities and Expenditures , Occidental has disclosed its reserve balances for environmental remediation matters that satisfy this criteria. Reserve balances for matters, other than environmental remediation, that satisfy this criteria as of September 30, 2019 , and December 31, 2018, were not material to Occidental’s Consolidated Condensed Balance Sheets. In 2016, Occidental received payments from the Republic of Ecuador of approximately $1.0 billion pursuant to a November 2015 arbitration award for Ecuador’s 2006 expropriation of Occidental's Participation Contract for Block 15. The awarded amount represented a recovery of 60 percent of the value of Block 15. In 2017, Andes Petroleum Ecuador Ltd. (Andes) filed a demand for arbitration, claiming it is entitled to a 40 percent share of the judgment amount obtained by Occidental. Occidental contends that Andes is not entitled to any of the amounts paid under the 2015 arbitration award because Occidental’s recovery was limited to Occidental’s own 60 percent economic interest in the block. The merits hearing is scheduled for May 2020. Occidental intends to vigorously defend against this claim in arbitration. On May 30, 2019, a complaint was filed in the Court of Chancery of the State of Delaware by purported Occidental stockholders High River Limited Partnership, Icahn Partners Master Fund LP and Icahn Partners LP (the “Icahn Complainants”), captioned High River Ltd. P’ship v. Occidental Petroleum Corp., C.A. No. 2019-0403-JRS, seeking inspection of Occidental’s books and records pursuant to Section 220 of the Delaware General Corporation Law. In the complaint, the Icahn Complainants noted that they had accumulated over $1.6 billion of Occidental Common Stock. On June 14, 2019, Occidental filed an answer to the complaint in the Court of Chancery of the State of Delaware. A trial was held on September 20, 2019, and the parties are awaiting a ruling. The ultimate outcome and impact of outstanding lawsuits, claims and proceedings on Occidental cannot be predicted. Management believes that the resolution of these matters will not, individually or in the aggregate, have a material adverse effect on Occidental's Consolidated Condensed Balance Sheets. If unfavorable outcomes of these matters were to occur, future results of operations or cash flows for any particular quarterly or annual period could be materially adversely affected. Occidental’s estimates are based on information known about the legal matters and its experience in contesting, litigating and settling similar matters. Occidental reassesses the probability and estimability of contingent losses as new information becomes available. Tax Matters During the course of its operations, Occidental is subject to audit by tax authorities for varying periods in various federal, state, local and foreign tax jurisdictions. With the Merger, Occidental maintains two separate federal consolidated groups. For the legacy Occidental group, taxable years through 2016 for United States federal income tax purposes have been audited by the United States Internal Revenue Service (IRS) pursuant to its Compliance Assurance Program and subsequent taxable years are currently under review. Taxable years through 2009 have been audited for state income tax purposes. While a single foreign tax jurisdiction is open for 2002 and subsequent years, all other significant audit matters in foreign jurisdictions have been resolved through 2010. For Anadarko, taxable years through 2016 for United States federal and state income tax purposes have been audited by the IRS and respective state taxing authorities. While the local country audit of a single foreign tax jurisdiction is open for tax years 2011 through 2013, there are no outstanding significant audit matters in foreign jurisdictions. During the course of tax audits, disputes have arisen and other disputes may arise as to facts and matters of law. Occidental believes that the resolution of outstanding tax matters would not have a material adverse effect on its consolidated financial position or results of operations. The tax deduction for the Tronox Adversary Proceeding (Tronox) settlement payment contributed to a net operating loss reported on Anadarko’s 2015 federal income tax return that was subsequently carried back to previous years and resulted in a tentative cash refund of $881 million of prior taxes paid, which was received in 2016. While Occidental believes it is entitled to this refund, in accordance with ASC 740's guidance on the accounting for uncertain tax positions, as of September 30, 2019, Occidental has recorded no tax benefit on the tentative cash tax refund of prior federal taxes paid of $881 million . As a result, should Occidental not ultimately prevail on the issue, there would be no tax expense recorded for financial statement purposes other than future interest. However, in that event Occidental would be required to repay approximately $917 million ( $898 million federal and $19 million in state taxes) plus accrued interest of approximately $171 million . Indemnities to Third Parties Occidental, its subsidiaries, or both, have indemnified various parties against specified liabilities those parties might incur in the future in connection with purchases and other transactions that they have entered into with Occidental. These indemnities usually are contingent upon the other party incurring liabilities that reach specified thresholds. As of September 30, 2019 , Occidental is not aware of circumstances that it believes would reasonably be expected to lead to indemnity claims that would result in payments materially in excess of reserves. Purchase Obligations and Commitments Occidental, its subsidiaries, or both, have entered into agreements providing for future payments to secure terminal and pipeline capacity, drilling rigs and services, electrical power, steam and certain chemical raw materials. Occidental has certain other commitments under contracts, guarantees and joint ventures, including purchase commitments for goods and services at market-related prices and certain other contingent liabilities. As of September 30, 2019, there were no material changes to Occidental's legacy purchase obligations since disclosure in the 2018 Form 10-K. In the Merger, Occidental assumed purchase obligations of approximately $5.2 billion , which included approximately $315 million , $1.0 billion , $907 million , $735 million , $589 million and $1.6 billion that will be paid for the remainder of 2019, 2020, 2021, 2022, 2023, and 2024 and thereafter, respectively. These amounts were discounted at 3.88% . These purchase obligations are related to long-term and work-related commitments for drilling wells, obtaining and processing seismic data, and fulfilling rig commitments, as well as various processing, transportation, storage, and purchase agreements to access markets and provide flexibility to sell its oil, natural gas, and NGL in certain areas.

Environmental Liabilities and E

Environmental Liabilities and Expenditures	9 Months Ended
	Sep. 30, 2019
Environmental Remediation Obligations [Abstract]
Environmental Liabilities and Expenditures	Environmental Liabilities and Expenditures Occidental’s operations are subject to stringent federal, state, local, and international laws and regulations related to improving or maintaining environmental quality. The laws that require or address environmental remediation, including the CERCLA and similar federal, state, local and international laws, may apply retroactively and regardless of fault, the legality of the original activities or the current ownership or control of sites. Occidental or certain of its subsidiaries participate in or actively monitor a range of remedial activities and government or private proceedings under these laws with respect to alleged past practices at operating, closed and third-party sites. Remedial activities may include one or more of the following: investigation involving sampling, modeling, risk assessment or monitoring; cleanup measures including removal, treatment or disposal; or operation and maintenance of remedial systems. The environmental proceedings seek funding or performance of remediation and, in some cases, compensation for alleged property damage, punitive damages, civil penalties, injunctive relief and government oversight costs. As of September 30, 2019 , Occidental participated in or monitored remedial activities or proceedings at 185 sites. The following table presents Occidental’s current and non-current environmental remediation reserves as of September 30, 2019 . The current portion, $ 149 million , is included in accrued liabilities and the non-current portion, $ 905 million , in deferred credits and other liabilities - environmental remediation reserves. The reserves are grouped as environmental remediation sites listed or proposed for listing by the United States Environmental Protection Agency (EPA) on the CERCLA National Priorities List (NPL) sites and three categories of non-NPL sites — third-party sites, Occidental-operated sites and closed or non-operated Occidental sites. Occidental continues to evaluate environmental liabilities assumed through the Merger with an initial determination that it will participate in or monitor remedial activities or proceedings at 42 sites. The underlying reserve balance for the environmental sites assumed through the Merger will change as more site-specific information and clean-up measures becomes available. Number of Sites Reserve Balance millions ) NPL sites 34 $ 452 Third-party sites 66 223 Occidental-operated sites 14 110 Closed or non-operated Occidental sites 29 127 Environmental sites assumed from the Merger 42 142 Total 185 $ 1,054 As of September 30, 2019 , Occidental’s environmental reserves exceeded $10 million each at 19 of the 185 sites described above, and 112 of the sites had reserves from zero to $1 million each. Based on current estimates, Occidental expects to expend funds corresponding to approximately 40 percent of the environmental reserves at the sites described above over the next three to four years and the remaining balance at these sites over the subsequent 10 or more years. Occidental believes its range of reasonably possible additional losses beyond those liabilities recorded for environmental remediation at these sites could be up to $1.2 billion . Other than the sites assumed through the Merger, the status of Occidental's involvement with the sites and related significant assumptions, including those sites indemnified by Maxus Energy Corporation (Maxus), has not changed materially since December 31, 2018. Maxus Environmental Sites When Occidental acquired Diamond Shamrock Chemicals Company (DSCC) in 1986, Maxus, a subsidiary of YPF S.A. (YPF), agreed to indemnify Occidental for a number of environmental sites, including the Diamond Alkali Superfund Site (Site) along a portion of the Passaic River. On September 17, 2016, Maxus and several affiliated companies filed for Chapter 11 bankruptcy in Federal District Court in the State of Delaware. Prior to filing for bankruptcy, Maxus defended and indemnified Occidental in connection with clean-up and other costs associated with the sites subject to the indemnity, including the Site. In March 2016, the EPA issued a Record of Decision (ROD) specifying remedial actions required for the lower 8.3 miles of the Lower Passaic River. The ROD does not address any potential remedial action for the upper nine miles of the Lower Passaic River or Newark Bay. During the third quarter of 2016, and following Maxus’s bankruptcy filing, Occidental and the EPA entered into an Administrative Order on Consent (AOC) to complete the design of the proposed clean-up plan outlined in the ROD at an estimated cost of $165 million . The EPA announced that it will pursue similar agreements with other potentially responsible parties. Occidental has accrued a reserve relating to its estimated allocable share of the costs to perform the design and remediation called for in the AOC and the ROD, as well as for certain other Maxus-indemnified sites. Occidental's accrued estimated environmental reserve does not consider any recoveries for indemnified costs. Occidental’s ultimate share of this liability may be higher or lower than the reserved amount, and is subject to final design plans and the resolution of Occidental's allocable share with other potentially responsible parties. Occidental continues to evaluate the costs to be incurred to comply with the AOC, the ROD, and to perform remediation at other Maxus-indemnified sites in light of the Maxus bankruptcy and the share of ultimate liability of other potentially responsible parties. In June 2018, Occidental filed a complaint under CERCLA in Federal District Court in the State of New Jersey against numerous potentially responsible parties for reimbursement of amounts incurred or to be incurred to comply with the AOC, the ROD, or to perform other remediation activities at the Site.

Retirement and Postretirement B

Retirement and Postretirement Benefit Plans	9 Months Ended
	Sep. 30, 2019
Retirement Benefits [Abstract]
Retirement and Postretirement Benefit Plans	Retirement and Postretirement Benefit Plans Occidental has various defined benefit pension plans for certain domestic union, non-union hourly and foreign national employees. In addition, Occidental also provides medical and other benefits for certain active, retired and disabled employees and their eligible dependents. In conjunction with the Merger, Occidental acquired certain Anadarko contributory and non-contributory defined benefit pension plans, which include both qualified and supplemental plans, and plans that provide health care and life insurance benefits for certain retired employees. The Anadarko pension and postretirement obligations were remeasured as of the Merger date. The disclosures below exclude the Africa Assets classified as held for sale as of September 30, 2019. The remeasurement resulted in an increase to the benefit obligation of $193 million . Accumulated other comprehensive income balances of $390 million were eliminated in purchase price accounting. Net periodic benefit costs related to pension benefits included a curtailment gain of $34 million and a $10 million cost of special termination benefits for both the three and nine months ended September 30, 2019. The curtailment gain and cost of special termination benefits for 2019 relate to the separation program initiated in conjunction with the Merger. Excluding these items, net periodic benefit costs related to pension benefits were $15 million and $19 million for the three and nine months ended September 30, 2019, respectively, compared to $2 million and $4 million for the same periods in 2018. Net periodic benefit costs related to postretirement benefits were $19 million and $48 million for the three and nine months ended September 30, 2019, respectively, compared to $15 million and $55 million for the same periods in 2018. Occidental contributed approximately $7 million and $2 million in the three months ended September 30, 2019 , and 2018 , respectively, and approximately $8 million and $4 million in the nine months ended September 30, 2019 , and 2018 , respectively, to its defined benefit plans.

Stockholders' Equity

Stockholders' Equity	9 Months Ended
	Sep. 30, 2019
Stockholders' Equity Note [Abstract]
Stockholders' Equity	Stockholders' Equity The following table is a summary of common stock issuances: shares in thousands Common Stock Balance at December 31, 2018 895,116 Issued in the ordinary course 2,394 Issued as part of the Merger (a) 146,131 Balance at September 30, 2019 1,043,641 (a) Includes approximately 2 million shares of common stock issued to a benefits trust for former Anadarko employees treated as treasury stock at September 30, 2019. Occidental has authorized 50 million shares of preferred stock with a par value of $1.00 per share. On August 8, 2019, in connection with the Merger, Occidental issued 100,000 shares of a new series A preferred stock (the Preferred Stock), having a face value of $100,000 per share. Dividends on the Preferred Stock will accrue on the face value at a rate per annum of 8 percent, but will be paid only when, as, and if declared by Occidental’s Board of Directors. At any time, when such dividends have not been paid in full, the unpaid amounts will accrue dividends, compounded quarterly, at a rate per annum of 9 percent. Following the payment in full of any accrued but unpaid dividends, the dividend rate will remain at 9 percent per annum. On October 15, 2019, Occidental paid approximately $149 million in Preferred Stock dividends. At September 30, 2019, Occidental had 100,000 shares of preferred stock issued and outstanding, and none were outstanding at December 31, 2018. The following table presents the calculation of basic and diluted net income (loss) attributable to common stockholders per share: Three months ended September 30 Nine months ended September 30 millions except per-share amounts 2019 2018 2019 2018 Net income (loss) attributable to common stockholders $ (912 ) $ 1,869 $ 354 $ 3,425 Less: Net income allocated to participating securities — 8 1 16 Net income (loss), net of participating securities $ (912 ) $ 1,861 $ 353 $ 3,409 Weighted average number of basic shares 845.7 761.7 781.1 764.3 Net income (loss) attributable to common stockholders per share—basic $ (1.08 ) $ 2.44 $ 0.45 $ 4.46 Net income (loss), net of participating securities $ (912 ) $ 1,861 $ 353 $ 3,409 Weighted average number of basic shares 845.7 761.7 781.1 764.3 Dilutive securities — 1.6 1.1 1.5 Total diluted weighted-average common shares 845.7 763.3 782.2 765.8 Net income (loss) attributable to common stockholders per share—diluted $ (1.08 ) $ 2.44 $ 0.45 $ 4.45 Accumulated other comprehensive loss consisted of the following after-tax amounts: millions Gains and (losses) on derivatives Pension and postretirement benefit plans Foreign currency translation adjustments Total Balance at December 31, 2018 $ 5 $ (170 ) $ (7 ) $ (172 ) Other comprehensive loss, before reclassifications (130 ) (30 ) — (160 ) Balance at September 30, 2019 $ (125 ) $ (200 ) $ (7 ) $ (332 )

Industry Segments

Industry Segments	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Industry Segments	Industry Segments Occidental conducts its operations through four segments: (1) Oil and Gas; (2) Chemical; (3) Marketing and Other Midstream; and (4) WES Midstream. Income taxes, interest income, interest expense, environmental remediation expenses, Anadarko merger-related costs and unallocated corporate expenses are included under Corporate and Eliminations. Intersegment sales eliminate upon consolidation and are generally made at prices approximating those that the selling entity would be able to obtain in third-party transactions. The following tables present Occidental’s industry segments: millions Oil and Gas Chemical Marketing and Other Midstream WES Midstream (a) Corporate and Eliminations Total Three months ended September 30, 2019 Net sales $ 3,821 $ 1,071 $ 780 $ 383 $ (368 ) $ 5,687 Income (loss) from continuing operations before income taxes $ 221 $ 207 $ 266 $ 134 $ (1,449 ) (b) $ (621 ) Income tax expense — — — — (116 ) (116 ) Income (loss) from continuing operations $ 221 $ 207 $ 266 $ 134 $ (1,565 ) $ (737 ) Three months ended September 30, 2018 Net sales $ 2,889 $ 1,185 $ 1,367 $ — $ (225 ) $ 5,216 Income (loss) from continuing operations before income taxes $ 767 $ 321 $ 1,698 $ — $ (207 ) $ 2,579 Income tax expense — — — — (710 ) (710 ) Income (loss) from continuing operations $ 767 $ 321 $ 1,698 $ — $ (917 ) $ 1,869 Nine months ended September 30, 2019 Net sales $ 8,890 $ 3,128 $ 2,505 $ 383 $ (795 ) $ 14,111 Income (loss) from continuing operations before income taxes $ 1,431 $ 680 $ 876 $ 134 $ (1,945 ) (b) $ 1,176 Income tax expense — — — (647 ) (647 ) Income (loss) from continuing operations $ 1,431 $ 680 $ 876 $ 134 $ (2,592 ) $ 529 Nine months ended September 30, 2018 Net sales $ 7,874 $ 3,515 $ 2,359 $ — $ (686 ) $ 13,062 Income (loss) from continuing operations before income taxes $ 2,297 $ 936 $ 2,127 $ — $ (584 ) $ 4,776 Income tax expense — — — (1,351 ) (1,351 ) Income (loss) from continuing operations $ 2,297 $ 936 $ 2,127 $ — $ (1,935 ) $ 3,425 (a) The WES Midstream segment results represent the period from August 8, 2019, the Merger date, through September 30, 2019. (b) The three months ended September 30, 2019 includes merger-related costs of $924 million and amortized debt financing fees of $65 million . The nine months ended September 30, 2019 includes merger-related costs of $974 million and amortized debt financing fees of $122 million .

General (Policies)

General (Policies)	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation The unaudited consolidated financial statements have been prepared in conformity with United States Generally Accepted Accounting Principles (GAAP) and include the accounts of OPC, its subsidiaries, VIEs for which Occidental is the primary beneficiary, and its undivided interests in oil and gas exploration and production ventures. Occidental has made its disclosures in accordance with GAAP as they apply to interim reporting, and condensed or omitted, as permitted by the Securities and Exchange Commission's rules and regulations, certain information and disclosures normally included in consolidated financial statements and notes. These unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and the notes thereto in Occidental's Annual Report on Form 10-K for the year ended December 31, 2018 (the 2018 Form 10-K). The Merger, including the addition of WES Midstream as a new reporting segment, introduced different revenue and expense streams to Occidental's legacy operations. As a result, changes were made to the structure of certain financial statements, notes and supplementary data to provide clarity and to conform to the current presentation.
Variable Interest Entities	Variable Interest Entities Occidental, through its ownership of the general partner interest in WES, has the power to direct the activities that significantly affect the economic performance of WES and the obligation to absorb losses or the right to receive benefits that could be significant to WES; therefore, Occidental is considered the primary beneficiary and consolidates WES and all of its consolidated subsidiaries. WES maintains its own capital structure that is separate from Occidental, consisting of its own debt instruments and publicly traded common units. All intercompany transactions have been eliminated. The assets of WES and its subsidiaries cannot be used by Occidental for general corporate purposes and are included in and disclosed parenthetically on Occidental's consolidated condensed balance sheets, if material. The carrying amount of liabilities related to WES for which the creditors do not have recourse to Occidental's assets are also included in and disclosed parenthetically on Occidental's Consolidated Condensed Balance Sheets, if material. All outstanding debt for WES at September 30, 2019, including any borrowings under the WES revolving credit facility (WES RCF) and WES Term Loan Facility, is recourse to the general partner of Western Midstream Operating, LP (WES Operating), which in turn has been indemnified in certain circumstances by certain indirect wholly owned subsidiaries of Occidental for such liabilities. See Note 9 - Long-Term Debt . WES's sources of liquidity include cash and cash equivalents, cash flows generated from operations, interest income from a note receivable from Anadarko, borrowings under the WES RCF, the issuance of additional partnership units, and debt offerings.
Discontinued Operations	Discontinued Operations In connection with the Merger, Occidental agreed to sell to TOTAL S.A. (Total) all of the assets, liabilities, businesses, and operations of Anadarko's operations in Algeria, Ghana, Mozambique and South Africa (collectively, the Africa Assets) for $8.8 billion , subject to certain purchase price adjustments. In August 2019, a purchase and sale agreement was executed for these Africa Assets. This transaction is conditioned on the receipt of required regulatory approvals, as well as other customary closing conditions. On September 27, 2019, Occidental completed the sale of Anadarko’s Mozambique LNG assets to Total for $4.2 billion . The assets and liabilities for Algeria, Ghana and South Africa, are presented as held for sale at September 30, 2019. The results of operations of the Africa Assets are presented as discontinued operations, see Note 4 - Acquisitions, Dispositions, and Other . Unless otherwise indicated, information presented in the Notes to the Consolidated Condensed Financial Statements relates only to Occidental's continuing operations. Information related to discontinued operations is included in Note 4 - Acquisitions, Dispositions, and Other , and in some instances, where appropriate, is included as a separate disclosure within the individual Notes to the Consolidated Condensed Financial Statements.
Goodwill and Other Intangible Assets	Goodwill and Other Intangible Assets Goodwill resulting from the Merger was assigned to WES Midstream and represents the excess of the purchase price over the estimated fair value of the assets acquired and liabilities assumed. Goodwill is subject to annual impairment testing. Changes in goodwill may result from, among other things, finalization of preliminary purchase price allocations, impairments, additional acquisitions, or divestitures. See Note 3 - The Merger . Other intangible assets represent contractual rights obtained in connection with the Merger that had favorable contractual terms relative to market terms as well as customer-related intangible assets, including customer relationships. Other intangible assets are amortized over their estimated useful lives and are assessed for impairment with the associated long-lived asset group whenever impairment indicators are present. See Note 3 - The Merger .
Accounting and Disclosure Changes	Accounting and Disclosure Changes In January 2019, Occidental adopted the new lease standard Accounting Standards Codification Topic 842 - Leases (ASC 842). The new standard requires Occidental to recognize most leases, including operating leases, on the balance sheet. The new rules require lessees to recognize a right-of-use asset (ROU) and lease liability for all leases with lease terms of more than 12 months. Occidental adopted the standard using the modified retrospective approach, including adopting several optional practical expedients. See Note 10 - Lease Commitments

General (Tables)

General (Tables)	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Schedule of Restrictions on Cash and Cash Equivalents	The following table provides a reconciliation of cash, cash equivalents, restricted cash and restricted cash equivalents as reported at the end of the period in the Consolidated Condensed Statements of Cash Flows for the nine months ended September 30, 2019 to the line items within the Consolidated Condensed Balance Sheet at September 30, 2019. There was no restricted cash or restricted cash equivalents at September 30, 2018 or December 31, 2018. millions September 30, 2019 Cash and cash equivalents $ 4,840 Restricted cash and restricted cash equivalents 454 Cash and restricted cash included in assets held for sale 16 Restricted cash and restricted cash equivalents included in long-term receivables and other assets, net 55 Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents $ 5,365
Schedule of Cash and Cash Equivalents	The following table provides a reconciliation of cash, cash equivalents, restricted cash and restricted cash equivalents as reported at the end of the period in the Consolidated Condensed Statements of Cash Flows for the nine months ended September 30, 2019 to the line items within the Consolidated Condensed Balance Sheet at September 30, 2019. There was no restricted cash or restricted cash equivalents at September 30, 2018 or December 31, 2018. millions September 30, 2019 Cash and cash equivalents $ 4,840 Restricted cash and restricted cash equivalents 454 Cash and restricted cash included in assets held for sale 16 Restricted cash and restricted cash equivalents included in long-term receivables and other assets, net 55 Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents $ 5,365

The Merger (Tables)

The Merger (Tables)	9 Months Ended
	Sep. 30, 2019
Business Combinations [Abstract]
Schedule of Purchase Consideration	The following table presents the Merger consideration paid to Anadarko stockholders as a result of the Merger: millions, except per share amounts Total shares of Anadarko common stock eligible for Merger consideration 491.6 Cash consideration (per share of common stock and shares underlying Anadarko stock-based awards eligible for Merger consideration) $ 59.00 Cash portion of Merger consideration $ 29,002 Total shares of Anadarko common stock and shares underlying Anadarko stock-based awards eligible for Merger consideration 492.0 Exchange ratio (per share of Anadarko common stock) 0.2934 Total shares of Occidental common stock issued to Anadarko stockholders 144 Average share price of Occidental common stock at August 8, 2019 $ 46.31 Stock portion of Merger consideration $ 6,684 Total Merger consideration $ 35,686
Schedule of Preliminary Purchase Price Allocation	The following table sets forth the preliminary allocation of the Merger consideration. Certain data necessary to complete the purchase price allocation is not yet available, and includes, but is not limited to, final appraisals of assets acquired and liabilities assumed, valuation of pre-merger contingencies and final tax returns that provide underlying tax basis of assets acquired and liabilities assumed. Occidental will finalize the purchase price allocation during the 12-month period following the Merger date, during which time the value of the assets and liabilities may be revised as appropriate. millions As of August 8, 2019 Fair value of assets acquired: Current assets $ 3,590 Anadarko's Africa Assets held for sale 10,746 Investments in unconsolidated entities 2,430 Property, plant and equipment, net - Anadarko 48,771 Property, plant and equipment, net - WES Midstream 9,475 Other assets 797 Intangible assets - WES Midstream 2,400 Amount attributable to assets acquired $ 78,209 Fair value of liabilities assumed: Current liabilities $ 3,677 Liabilities of Anadarko's Africa Assets held for sale 2,329 Long-term debt - Anadarko 12,829 Long-term debt - WES Midstream 7,407 Deferred income taxes 10,040 Asset retirement obligations 2,728 Pension and post retirement obligations 1,125 Non-current derivative liabilities 1,279 Other long-term liabilities 2,308 Amount attributable to liabilities assumed $ 43,722 Net assets $ 34,487 Less: Fair value of noncontrolling interests in WES Midstream 4,875 Fair value of net assets acquired 29,612 Goodwill - WES Midstream 6,074 Total Merger consideration $ 35,686
Pro Forma Information	The following summarizes the unaudited pro forma condensed financial information of Occidental as if the Merger had occurred on January 1, 2018: Three months ended September 30 Nine months ended September 30 millions, except per-share amounts 2019 2018 2019 2018 Revenues $ 7,335 $ 8,913 $ 22,419 $ 23,095 Net income (loss) attributable to common stockholders $ (427 ) $ 2,060 $ 475 $ 3,405 Net income (loss) attributable to common stockholders per share—basic $ (0.50 ) $ 2.27 $ 0.51 $ 3.74 Net income (loss) attributable to common stockholders per share—diluted $ (0.50 ) $ 2.26 $ 0.50 $ 3.73
Schedule of Merger-Related Costs	The following table summarizes the merger-related costs incurred: millions Three months ended September 30, 2019 Nine months ended September 30, 2019 Employee severance and related cost $ 459 $ 459 Licensing fees for critical seismic data 329 354 Bank, legal and consulting fees 136 161 Total $ 924 $ 974

Acquisitions, Dispositions, a_2

Acquisitions, Dispositions, and Other Transactions (Tables)	9 Months Ended
	Sep. 30, 2019
Discontinued Operations and Disposal Groups and Equity Method And Joint Ventures [Abstract]
Summary of Revenues, Costs and Assets Held for Sale of Discontinued Operations	The following table presents the amounts reported in discontinued operations, net of income taxes, related to the Africa Assets subsequent to the Merger closing date through September 30, 2019: millions 2019 REVENUES AND OTHER INCOME Net sales $ 228 COSTS AND OTHER DEDUCTIONS Oil and gas operating expense $ 32 Transportation and marketing expense 4 Taxes other than on income 46 Fair value adjustment on assets held for sale 65 Selling, general and administrative 8 Other 4 $ 159 Income before income taxes $ 69 Income tax expense (84 ) Discontinued operations, net of tax $ (15 ) The following table presents the amounts reported in the Consolidated Condensed Balance Sheets as held for sale related to the Africa Assets and other corporate property. millions September 30, 2019 Cash and cash equivalents $ 16 Inventories 207 Other current assets 110 Property, plant and equipment, net 5,863 Operating lease assets 29 Long-term receivables and other assets, net 220 Assets held for sale $ 6,445 Current maturities of debt - finance leases 13 Current operating lease liabilities 11 Accounts payable 217 Accrued liabilities 152 Long-term debt, net - finance leases 187 Deferred income taxes 1,281 Asset retirement obligations 142 Other 200 Liabilities of assets held for sale $ 2,203 Net assets held for sale $ 4,242

Revenue Recognition (Tables)

Revenue Recognition (Tables)	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Schedule of reconciliation of revenue from customers to total net sales	The following table shows a reconciliation of revenue from customers to total net sales: Three months ended September 30 Nine months ended September 30 millions 2019 2018 2019 2018 Revenue from customers $ 5,231 $ 4,257 $ 12,397 $ 11,813 All other revenues (a) 456 959 1,714 1,249 Net sales $ 5,687 $ 5,216 $ 14,111 $ 13,062 (a) Includes net marketing derivatives, oil collars and calls, and chemical exchange contracts.
Schedule of revenue from customers by segment, product, and geographical area	Excluding net marketing revenue, Marketing and Other Midstream revenues are shown by the location of sale: millions United States Middle East Latin America Other International Eliminations Total Three months ended September 30, 2019 Oil and Gas Oil $ 2,453 $ 683 $ 177 $ — $ — $ 3,313 NGL 177 63 — — — 240 Gas 125 78 5 — — 208 Other (18 ) 3 — — — (15 ) Segment total $ 2,737 $ 827 $ 182 $ — $ — $ 3,746 Chemical $ 1,009 $ — $ 36 $ 16 $ — $ 1,061 Marketing and Other Midstream Gas processing 93 81 — — — 174 Power and other 198 — — 37 — 235 Segment total $ 291 $ 81 $ — $ 37 $ — $ 409 WES Midstream $ 383 $ — $ — $ — $ — $ 383 Eliminations $ — $ — $ — $ — $ (368 ) $ (368 ) Consolidated $ 4,420 $ 908 $ 218 $ 53 $ (368 ) $ 5,231 millions United States Middle East Latin America Other International Eliminations Total Three months ended September 30, 2018 Oil and Gas Oil $ 1,326 $ 1,016 $ 197 $ — $ — $ 2,539 NGL 139 77 — — — 216 Gas 47 80 5 — — 132 Other 3 — (1 ) — — 2 Segment total $ 1,515 $ 1,173 $ 201 $ — $ — $ 2,889 Chemical $ 1,112 $ — $ 51 $ 21 $ — $ 1,184 Marketing and Other Midstream Gas processing 148 108 — — — 256 Pipelines 115 — — — — 115 Power and other 38 — — — — 38 Segment total $ 301 $ 108 $ — $ — $ — $ 409 Eliminations $ — $ — $ — $ — $ (225 ) $ (225 ) Consolidated $ 2,928 $ 1,281 $ 252 $ 21 $ (225 ) $ 4,257 millions United States Middle East Latin America Other International Eliminations Total Nine months ended September 30, 2019 Oil and Gas Oil $ 5,105 $ 2,266 $ 524 $ — $ — $ 7,895 NGL 339 196 — — — 535 Gas 180 233 14 — — 427 Other (40 ) (2 ) — — — (42 ) Segment total $ 5,584 $ 2,693 $ 538 $ — $ — $ 8,815 Chemical $ 2,937 $ — $ 119 $ 53 $ — $ 3,109 Marketing and Other Midstream Gas processing 302 272 — — — 574 Power and other 274 — — 37 — 311 Segment total $ 576 $ 272 $ — $ 37 $ — $ 885 WES Midstream $ 383 $ — $ — $ — $ — $ 383 Eliminations $ — $ — $ — $ — $ (795 ) $ (795 ) Consolidated $ 9,480 $ 2,965 $ 657 $ 90 $ (795 ) $ 12,397 millions United States Middle East Latin America Other International Eliminations Total Nine months ended September 30, 2018 Oil and Gas Oil $ 3,907 $ 2,507 $ 547 $ — $ — $ 6,961 NGL 339 192 — — — 531 Gas 141 218 12 — — 371 Other 10 1 — — — 11 Segment total $ 4,397 $ 2,918 $ 559 $ — $ — $ 7,874 Chemical $ 3,294 $ — $ 154 $ 59 $ — $ 3,507 Marketing and Other Midstream Gas processing 416 308 — — — 724 Pipelines 310 — — — — 310 Power and other 84 — — — — 84 Segment total $ 810 $ 308 $ — $ — $ — $ 1,118 Eliminations $ — $ — $ — $ — $ (686 ) $ (686 ) Consolidated $ 8,501 $ 3,226 $ 713 $ 59 $ (686 ) $ 11,813
Schedule of contract with customer liabilities activity	The following table summarizes current period activity related to contract liabilities from contracts with customers: millions Balance at December 31, 2018 $ — Increase due to contract liabilities acquired with Anadarko 154 Increase due to cash received, excluding revenues recognized in the period 9 Decrease due to revenue recognized (13 ) Balance at September 30, 2019 $ 150
Schedule of expected revenue recognition from satisfaction of performance obligations	As a result, the following table represents a small portion of Occidental's expected future consolidated revenues, as future revenue from the sale of most products and services is dependent on future production or variable customer volume and variable commodity prices for that volume: millions Oil and Gas WES Midstream Eliminations Total Remainder of 2019 $ 26 $ 193 $ (127 ) $ 92 2020 103 863 (589 ) 377 2021 103 912 (645 ) 370 2022 7 963 (703 ) 267 2023 7 915 (690 ) 232 Thereafter 60 4,399 (3,768 ) 691 Total $ 306 $ 8,245 $ (6,522 ) $ 2,029

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2019
Inventory Disclosure [Abstract]
Schedule of inventories	Inventories consisted of the following: millions September 30, 2019 December 31, 2018 Raw materials $ 67 $ 74 Materials and supplies 916 445 Commodity inventory and finished goods 665 788 1,648 1,307 Revaluation to LIFO (47 ) (47 ) Total $ 1,601 $ 1,260

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of Derivative Instruments	The following interest rate swaps were outstanding at September 30, 2019 : millions except percentages Mandatory Weighted-Average Notional Principal Amount Reference Period Termination Date Interest Rate $ 375 December 2019 - 2024 December 2019 2.662 % $ 375 December 2019 - 2029 December 2019 2.802 % $ 375 December 2019 - 2049 December 2019 2.885 % Occidental had the following collars and calls outstanding at September 30, 2019 : Collars and Calls, not designated as hedges 2019 Settlement Three-way collars (Oil MMBL) 8.0 Average price per barrel (NYMEX/Brent oil pricing) Ceiling sold price (call) $ 72.98 Floor purchased price (put) $ 56.72 Floor sold price (put) $ 46.72 2020 Settlement Three-way collars (Oil MMBL) 109.8 Average price per barrel (Brent oil pricing) Ceiling sold price (call) $ 74.09 Floor purchased price (put) $ 55.00 Floor sold price (put) $ 45.00 2021 Settlement Call Options sold (Oil MMBL) 109.5 Average price per barrel (Brent oil pricing) Ceiling sold price (call) $ 74.09 Occidental had the following outstanding interest rate swaps at September 30, 2019 : millions except percentages Mandatory Weighted-Average Notional Principal Amount Reference Period Termination Date Interest Rate $ 125 September 2016 - 2046 October 2019 6.782 % $ 550 September 2016 - 2046 September 2020 6.418 % $ 125 September 2016 - 2046 September 2022 6.835 % $ 100 September 2017 - 2047 September 2020 6.891 % $ 250 September 2017 - 2047 September 2021 6.570 % $ 450 September 2017 - 2047 September 2023 6.445 %
Summary of net sales related to the outstanding commodity derivative instruments	The following table summarizes net long/(short) volumes associated with the outstanding marketing commodity derivatives not designated as hedging instruments as of September 30, 2019 , and December 31, 2018 . 2019 2018 Crude Oil Commodity Contracts Volume (MMBL) 36 61 Natural Gas Commodity Contracts Volume (Bcf) (128 ) (142 )
Gross and net fair values of outstanding derivatives	The following tables present the fair values of Occidental’s outstanding derivatives. Fair values are presented at gross amounts, including when the derivatives are subject to master netting arrangements, and are presented on a net basis in the Consolidated Condensed Balance Sheets. Balance Sheet Classification Fair-Value Measurements Using Netting (a) Total Fair Value millions Level 1 Level 2 Level 3 September 30, 2019 Oil Collars and Calls Other current assets $ — $ 217 $ — $ (4 ) $ 213 Accrued liabilities — 3 — (3 ) — Deferred credits and other liabilities - other — 97 — — 97 Marketing Derivatives Other current assets 838 97 — (861 ) 74 Long-term receivables and other assets, net 70 12 — (70 ) 12 Accrued liabilities 827 45 — (861 ) 11 Deferred credits and other liabilities - other 71 1 — (70 ) 2 Interest Rate Swaps (excluding WES) Other current assets — 14 — — 14 Long-term receivables and other assets, net — 13 — — 13 Accrued liabilities — 882 — — 882 Deferred credits and other liabilities - other — 879 — — 879 WES Interest Rate Swaps Accrued liabilities — 171 — — 171 Warrant Deferred credits and other liabilities - other — 168 — — 168 December 31, 2018 Marketing Derivatives Other current assets $ 2,531 $ 110 $ — $ (2,392 ) $ 249 Long-term receivables and other assets, net 5 9 — (6 ) 8 Accrued liabilities 2,357 101 — (2,392 ) 66 Deferred credits and other liabilities - other 6 2 — (6 ) 2 (a)
Schedule of Gains and Losses on Derivatives	Gains and Losses on Derivatives The following table presents the effect of Occidental's derivative instruments on the Consolidated Condensed Statements of Operations: Income Statement Classification Three months ended September 30 Nine months ended September 30 millions 2019 2018 2019 2018 Oil Collars and Calls Net sales $ 75 $ — $ 75 $ — Marketing Derivatives Net sales 91 36 (119 ) 8 Interest Rate Swaps (Excluding WES) Losses on interest rate swaps and warrants, net (45 ) — (45 ) — Interest Rate Swaps (WES) Losses on interest rate swaps and warrants, net (8 ) — (8 ) — Warrants Gains on interest rate swaps and warrants, net 20 — 20 —

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2019
Fair Value Disclosures [Abstract]
Assets and liabilities measured at fair value on a recurring basis	The following tables provide fair-value measurement information for embedded derivatives that are measured on a recurring basis: millions Fair-Value Measurements Using Embedded derivatives Level 1 Level 2 Level 3 Netting and Total Fair As of September 30, 2019 Accrued liabilities $ — $ 54 $ — $ — $ 54 Deferred credits and other liabilities - other — 73 — — 73 As of December 31, 2018 Accrued liabilities $ — $ 66 $ — $ — $ 66 Deferred credits and other liabilities - other — 116 — — 116

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Schedule of Long-term Debt	Long-term debt consisted of the following: millions Balance at September 30, 2019 Occidental 4.850% senior notes due 2021 $ 677 2.600% senior notes due 2021 1,500 4.100% senior notes due 2021 1,249 Variable rate bonds due 2021 (3.137% as of September 30, 2019) 500 Variable rate bonds due 2021 (3.437% as of September 30, 2019) 500 2-year variable rate Term Loan due 2021 (3.417% as of September 30, 2019) 3,966 2.700% senior notes due 2022 2,000 3.125% senior notes due 2022 814 2.600% senior notes due 2022 400 Variable rate bonds due 2022 (3.637% as of September 30, 2019) 1,500 2.700% senior notes due 2023 1,191 8.750% medium-term notes due 2023 22 2.900% senior notes due 2024 3,000 6.950% senior notes due 2024 650 3.450% senior notes due 2024 248 3.500% senior notes due 2025 750 5.550% senior notes due 2026 1,100 3.200% senior notes due 2026 1,000 3.400% senior notes due 2026 1,150 7.500% debentures due 2026 112 3.000% senior notes due 2027 750 7.125% debentures due 2027 150 7.000% debentures due 2027 48 6.625% debentures due 2028 14 7.150% debentures due 2028 235 7.200% senior debentures due 2028 82 7.200% debentures due 2029 135 7.950% debentures due 2029 116 8.450% senior debentures due 2029 116 3.500 senior notes due 2029 1,500 Variable rate bonds due 2030 (1.785% as of September 30, 2019) 68 7.500% senior notes due 2031 900 7.875% senior notes due 2031 500 6.450% senior notes due 2036 1,750 Zero Coupon senior notes due 2036 2,271 4.300% senior notes due 2039 750 7.950% senior notes due 2039 325 6.200% senior notes due 2040 750 4.500% senior notes due 2044 625 4.625% senior notes due 2045 750 6.600% senior notes due 2046 1,100 4.400% senior notes due 2046 1,200 4.100% senior notes due 2047 750 4.200% senior notes due 2048 1,000 4.400% senior notes due 2049 750 7.730% debentures due 2096 60 7.500% debentures due 2096 78 7.250% debentures due 2096 49 Total borrowings at face value (a) 39,151 Adjustments to book value: Unamortized premium, net 859 Debt issuance costs (133 ) Long-term finance leases 69 Long-term Debt, net - Occidental $ 39,946 (a) Total borrowings at face value also includes a $310 thousand 7.25% senior note due 2025 millions Balance at September 30, 2019 WES 5.375% senior notes due 2021 $ 500 4.000% senior notes due 2022 670 3.950% senior notes due 2025 500 4.650% senior notes due 2026 500 4.500% senior notes due 2028 400 4.750% senior notes due 2028 400 5.450% senior notes due 2044 600 5.300% senior notes due 2048 700 5.500% senior notes due 2048 350 WES Term Loan Facility (3.420% as of September 30, 2019) 3,000 WES revolving credit facility (3.340% as of September 30,2019) 160 Total borrowings at face value $ 7,780 Adjustments to book value: Unamortized discount net (135 ) Debt issuance costs (8 ) Long-term Debt, net - WES $ 7,637 Occidental Consolidated Total borrowings at face value $ 46,931 Adjustments to book value: Unamortized premium, net 724 Debt issuance costs (141 ) Long-term finance leases 69 Total Occidental Consolidated Long-term Debt $ 47,583 millions Balance at December 31, 2018 Occidental 9.250% senior debentures due 2019 $ 116 4.100% senior notes due 2021 1,249 3.125% senior notes due 2022 813 2.600% senior notes due 2022 400 2.700% senior notes due 2023 1,191 8.750% medium-term notes due 2023 22 3.500% senior notes due 2025 750 3.400% senior notes due 2026 1,150 3.000% senior notes due 2027 750 7.200% senior debentures due 2028 82 8.450% senior debentures due 2029 116 4.625% senior notes due 2045 750 4.400% senior notes due 2046 1,200 4.100% senior notes due 2047 750 4.200% senior notes due 2048 1,000 Variable rate bonds due 2030 (1.9% as of December 31, 2018) 68 10,407 Adjustments to book value: Unamortized discount, net (36 ) Debt issuance costs (54 ) Current maturities (116 ) Total Occidental Consolidated Long-term Debt $ 10,201

Lease Commitments (Tables)

Lease Commitments (Tables)	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Schedule of Operating Lease Maturities	The following table reconciles the undiscounted cash flows related to the operating and finance lease liabilities assumed in the Merger and recorded on the Consolidated Condensed Balance Sheet at the Merger date: millions Operating Leases Finance Leases Total Remainder of 2019 $ 90 $ 7 $ 97 2020 172 25 197 2021 64 15 79 2022 42 12 54 2023 28 7 35 Thereafter 136 42 178 Total lease payments 532 108 640 Less: Interest (44 ) (22 ) (66 ) Total lease liabilities $ 488 $ 86 $ 574 At September 30, 2019 , Occidental's leases expire based on the following schedule: Operating Finance millions Leases (a) Leases (b) Total Remainder of 2019 $ 119 $ 8 $ 127 2020 390 38 428 2021 197 15 212 2022 129 12 141 2023 94 7 101 Thereafter 311 42 353 Total lease payments 1,240 122 1,362 Less: Interest (101 ) (22 ) (123 ) Total lease liabilities $ 1,139 $ 100 $ 1,239 (a) The weighted-average remaining lease term is 5.3 years and the weighted-average discount rate is 2.79% . (b) The weighted-average remaining lease term is 6.4 years and the weighted-average discount rate is 4.92% .
Schedule of Finance Lease Maturities	At September 30, 2019 , Occidental's leases expire based on the following schedule: Operating Finance millions Leases (a) Leases (b) Total Remainder of 2019 $ 119 $ 8 $ 127 2020 390 38 428 2021 197 15 212 2022 129 12 141 2023 94 7 101 Thereafter 311 42 353 Total lease payments 1,240 122 1,362 Less: Interest (101 ) (22 ) (123 ) Total lease liabilities $ 1,139 $ 100 $ 1,239 (a) The weighted-average remaining lease term is 5.3 years and the weighted-average discount rate is 2.79% . (b) The weighted-average remaining lease term is 6.4 years and the weighted-average discount rate is 4.92% . The following table reconciles the undiscounted cash flows related to the operating and finance lease liabilities assumed in the Merger and recorded on the Consolidated Condensed Balance Sheet at the Merger date: millions Operating Leases Finance Leases Total Remainder of 2019 $ 90 $ 7 $ 97 2020 172 25 197 2021 64 15 79 2022 42 12 54 2023 28 7 35 Thereafter 136 42 178 Total lease payments 532 108 640 Less: Interest (44 ) (22 ) (66 ) Total lease liabilities $ 488 $ 86 $ 574
Schedule of Lease Related Assets and Liabilities	The following table presents lease balances and their location on the Consolidated Condensed Balance Sheet at September 30, 2019: millions Balance sheet location 2019 Assets: Operating Operating lease assets $ 1,078 Finance Property, plant and equipment 97 Total lease assets $ 1,175 Liabilities: Current Operating Current operating lease liabilities $ 463 Finance Current maturities of long-term debt 31 Non-current Operating Deferred credits and other liabilities - Operating lease liabilities 676 Finance Long-term debt, net - Occidental 69 Total lease liabilities $ 1,239
Schedule of Future Net Minimum Fixed Lease Payments	At December 31, 2018 , future undiscounted net minimum fixed lease payments for non-cancellable operating leases, prepared in accordance with accounting standards prior to the adoption of ASC 842, were as follows: Operating millions Leases 2019 $ 186 2020 147 2021 96 2022 68 2023 49 Thereafter 158 Total minimum lease payments (a) $ 704 (a) The amount represents the future undiscounted cash flows at December 31, 2018, excluding any amount associated with the Merger.
Schedule of Lease Costs	The following tables present Occidental's total lease cost and classifications, as well as cash paid for amounts included in the measurement of operating and finance lease liabilities. Lease cost classification (a) Three months ended September 30, 2019 Nine months ended September 30, 2019 millions Operating lease costs (b) Property, plant and equipment, net $ 139 $ 321 Cost of sales 133 271 Selling, general and administrative expenses 26 61 Finance lease cost Amortization of ROU assets 5 11 Interest on lease liabilities 1 1 $ 304 $ 665 (a) Amounts reflected are gross before joint-interest recoveries. (b) Includes short-term lease cost of $139 million and $295 million for the three and nine months ended September 30, 2019, respectively, and variable lease cost of $55 million and $115 million for the three and nine months ended September 30, 2019, respectively. millions Nine months ended September 30, 2019 Operating cash flows $ 162 Investing cash flows 83 Financing cash flows 11

Environmental Liabilities and_2

Environmental Liabilities and Expenditures (Tables)	9 Months Ended
	Sep. 30, 2019
Environmental Remediation Obligations [Abstract]
Schedule of current and non-current environmental remediation reserves by categories of sites	The following table presents Occidental’s current and non-current environmental remediation reserves as of September 30, 2019 . The current portion, $ 149 million , is included in accrued liabilities and the non-current portion, $ 905 million , in deferred credits and other liabilities - environmental remediation reserves. The reserves are grouped as environmental remediation sites listed or proposed for listing by the United States Environmental Protection Agency (EPA) on the CERCLA National Priorities List (NPL) sites and three categories of non-NPL sites — third-party sites, Occidental-operated sites and closed or non-operated Occidental sites. Occidental continues to evaluate environmental liabilities assumed through the Merger with an initial determination that it will participate in or monitor remedial activities or proceedings at 42 sites. The underlying reserve balance for the environmental sites assumed through the Merger will change as more site-specific information and clean-up measures becomes available. Number of Sites Reserve Balance millions ) NPL sites 34 $ 452 Third-party sites 66 223 Occidental-operated sites 14 110 Closed or non-operated Occidental sites 29 127 Environmental sites assumed from the Merger 42 142 Total 185 $ 1,054

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	9 Months Ended
	Sep. 30, 2019
Stockholders' Equity Note [Abstract]
Summary of common stock issuances	The following table is a summary of common stock issuances: shares in thousands Common Stock Balance at December 31, 2018 895,116 Issued in the ordinary course 2,394 Issued as part of the Merger (a) 146,131 Balance at September 30, 2019 1,043,641 (a) Includes approximately 2 million shares of common stock issued to a benefits trust for former Anadarko employees treated as treasury stock at September 30, 2019.
Calculation of basic and diluted EPS	The following table presents the calculation of basic and diluted net income (loss) attributable to common stockholders per share: Three months ended September 30 Nine months ended September 30 millions except per-share amounts 2019 2018 2019 2018 Net income (loss) attributable to common stockholders $ (912 ) $ 1,869 $ 354 $ 3,425 Less: Net income allocated to participating securities — 8 1 16 Net income (loss), net of participating securities $ (912 ) $ 1,861 $ 353 $ 3,409 Weighted average number of basic shares 845.7 761.7 781.1 764.3 Net income (loss) attributable to common stockholders per share—basic $ (1.08 ) $ 2.44 $ 0.45 $ 4.46 Net income (loss), net of participating securities $ (912 ) $ 1,861 $ 353 $ 3,409 Weighted average number of basic shares 845.7 761.7 781.1 764.3 Dilutive securities — 1.6 1.1 1.5 Total diluted weighted-average common shares 845.7 763.3 782.2 765.8 Net income (loss) attributable to common stockholders per share—diluted $ (1.08 ) $ 2.44 $ 0.45 $ 4.45
Components of accumulated other comprehensive loss	Accumulated other comprehensive loss consisted of the following after-tax amounts: millions Gains and (losses) on derivatives Pension and postretirement benefit plans Foreign currency translation adjustments Total Balance at December 31, 2018 $ 5 $ (170 ) $ (7 ) $ (172 ) Other comprehensive loss, before reclassifications (130 ) (30 ) — (160 ) Balance at September 30, 2019 $ (125 ) $ (200 ) $ (7 ) $ (332 )

Industry Segments (Tables)

Industry Segments (Tables)	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Schedule of industry segments	The following tables present Occidental’s industry segments: millions Oil and Gas Chemical Marketing and Other Midstream WES Midstream (a) Corporate and Eliminations Total Three months ended September 30, 2019 Net sales $ 3,821 $ 1,071 $ 780 $ 383 $ (368 ) $ 5,687 Income (loss) from continuing operations before income taxes $ 221 $ 207 $ 266 $ 134 $ (1,449 ) (b) $ (621 ) Income tax expense — — — — (116 ) (116 ) Income (loss) from continuing operations $ 221 $ 207 $ 266 $ 134 $ (1,565 ) $ (737 ) Three months ended September 30, 2018 Net sales $ 2,889 $ 1,185 $ 1,367 $ — $ (225 ) $ 5,216 Income (loss) from continuing operations before income taxes $ 767 $ 321 $ 1,698 $ — $ (207 ) $ 2,579 Income tax expense — — — — (710 ) (710 ) Income (loss) from continuing operations $ 767 $ 321 $ 1,698 $ — $ (917 ) $ 1,869 Nine months ended September 30, 2019 Net sales $ 8,890 $ 3,128 $ 2,505 $ 383 $ (795 ) $ 14,111 Income (loss) from continuing operations before income taxes $ 1,431 $ 680 $ 876 $ 134 $ (1,945 ) (b) $ 1,176 Income tax expense — — — (647 ) (647 ) Income (loss) from continuing operations $ 1,431 $ 680 $ 876 $ 134 $ (2,592 ) $ 529 Nine months ended September 30, 2018 Net sales $ 7,874 $ 3,515 $ 2,359 $ — $ (686 ) $ 13,062 Income (loss) from continuing operations before income taxes $ 2,297 $ 936 $ 2,127 $ — $ (584 ) $ 4,776 Income tax expense — — — (1,351 ) (1,351 ) Income (loss) from continuing operations $ 2,297 $ 936 $ 2,127 $ — $ (1,935 ) $ 3,425 (a) The WES Midstream segment results represent the period from August 8, 2019, the Merger date, through September 30, 2019. (b) The three months ended September 30, 2019 includes merger-related costs of $924 million and amortized debt financing fees of $65 million . The nine months ended September 30, 2019 includes merger-related costs of $974 million and amortized debt financing fees of $122 million .

General (Details)

General (Details)	1 Months Ended	9 Months Ended		12 Months Ended
	May 31, 2008USD ($)	Sep. 30, 2019USD ($)segment	Sep. 30, 2018USD ($)	Dec. 31, 2016USD ($)	Sep. 27, 2019USD ($)	Aug. 08, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Noncontrolling Interest [Line Items]
Number of reporting segments | segment		4
Interest paid		$ 610,000,000	$ 298,000,000
Cash and cash equivalents		4,840,000,000					$ 3,033,000,000
Restricted cash and restricted cash equivalents		454,000,000					0
Cash and restricted cash included in assets held for sale		16,000,000
Restricted cash and restricted cash equivalents included in long-term receivables and other assets, net		55,000,000
Cash, Cash Equivalents, Restricted Cash, and Restricted Cash Equivalents		5,365,000,000	2,954,000,000				$ 3,033,000,000	$ 1,672,000,000
Foreign and State
Noncontrolling Interest [Line Items]
Income taxes paid		751,000,000	838,000,000
State
Noncontrolling Interest [Line Items]
Domestic tax refunds		2,000,000	2,000,000
Federal
Noncontrolling Interest [Line Items]
Income taxes paid		$ 0	$ 0
Western Midstream Operating, LP
Noncontrolling Interest [Line Items]
Ownership interest		2.00%
WES Midstream
Noncontrolling Interest [Line Items]
Ownership interest		55.40%
WES Midstream | Western Midstream Operating, LP
Noncontrolling Interest [Line Items]
Ownership interest		98.00%
Public Ownership | WES Midstream
Noncontrolling Interest [Line Items]
Ownership interest		44.60%
Anadarko | Western Midstream Operating, LP
Noncontrolling Interest [Line Items]
Note receivable	$ 260,000,000
Notes Payable | Western Midstream Operating, LP
Noncontrolling Interest [Line Items]
Debt instrument term	30 years
Fixed annual rate, payable quarterly	6.50%
Mozambique LNG Assets | Discontinued Operations, Disposed of by Sale
Noncontrolling Interest [Line Items]
Discontinued operations, consideration receivable					$ 4,200,000,000
Anadarko
Noncontrolling Interest [Line Items]
Domestic tax refunds				$ 881,000,000
Anadarko | Africa Assets | Discontinued Operations, Held-for-sale
Noncontrolling Interest [Line Items]
Discontinued operations, consideration receivable						$ 8,800,000,000

The Merger - Narrative (Details

The Merger - Narrative (Details) - USD ($)	Aug. 08, 2019	Sep. 30, 2019	Sep. 30, 2019	Aug. 07, 2019	Jun. 04, 2019	Jun. 03, 2019
Revolving Credit Facility
Business Acquisition [Line Items]
Revolving credit facility, maximum borrowing capacity				$ 3,000,000,000
Anadarko
Business Acquisition [Line Items]
Cash of acquirer in exchange for acquiree (usd per share)	$ 59
Exchange ratio	0.2934
Closing price per share, common stock (usd per share)	$ 46.31
Debt issuance, face amount	$ 21,800,000,000
Amount from exercise of warrants	10,000,000,000
Long-term debt	12,829,000,000
Goodwill	6,074,000,000
Property, plant and equipment, net	48,771,000,000
Other intangible assets acquired	2,400,000,000
Aggregate amortization expense for intangible assets	108,000,000
Revenues from date of merger		$ 1,500,000,000
Net loss attributable to common shareholders from date of merger		$ 400,000,000
Anadarko | Customer Contracts
Business Acquisition [Line Items]
Other intangible assets acquired	$ 2,400,000,000
Amortization period	25 years
Anadarko | Level 2
Business Acquisition [Line Items]
Long-term debt	$ 6,100,000,000
Anadarko | Revolving Credit Facility
Business Acquisition [Line Items]
Revolving credit facility, maximum borrowing capacity					$ 5,000,000,000	$ 3,000,000,000
Revolving credit facility, additional commitment	2,000,000,000
Anadarko | Senior Notes
Business Acquisition [Line Items]
Debt issuance, face amount	13,000,000,000
Anadarko | The Term Loans
Business Acquisition [Line Items]
Debt issuance, face amount	$ 8,800,000,000
Series A Preferred Stock | Anadarko
Business Acquisition [Line Items]
Shares issued	100,000
Common Stock | Anadarko
Business Acquisition [Line Items]
Closing price per share, common stock (usd per share)	$ 46.31
Shares issued	144,000,000
Number of securities called by warrant (in shares)	80,000,000
Exercise price of warrant (usd per share)	$ 62.50
Proved Properties | Anadarko
Business Acquisition [Line Items]
Property, plant and equipment, net	$ 18,200,000,000
Unproved Properties | Anadarko
Business Acquisition [Line Items]
Property, plant and equipment, net	26,000,000,000
Land, Mineral Interests and Corporate Properties | Anadarko
Business Acquisition [Line Items]
Property, plant and equipment, net	$ 5,000,000,000
Restricted Stock Awards | Anadarko
Business Acquisition [Line Items]
Restricted stock issued on date of Merger (in shares)	1,700,000
Weighted-average grant-date fair value (usd per share)	$ 47.13
Weighted-average grant-date fair value, remaining life	1 year 3 months 18 days
Restricted Stock Awards | Anadarko | Minimum
Business Acquisition [Line Items]
Restricted shares vesting period			1 month
Restricted Stock Awards | Anadarko | Maximum
Business Acquisition [Line Items]
Restricted shares vesting period			3 years 6 months

The Merger - Schedule of Purcha

The Merger - Schedule of Purchase Consideration Paid (Details) - Anadarko $ / shares in Units, $ in Millions	Aug. 08, 2019USD ($)$ / sharesshares
Business Acquisition [Line Items]
Total shares of common stock eligible for merger consideration (in shares)	491,600,000
Cash consideration (per share of common stock and shares underlying Anadarko stock-based awards eligible for merger consideration) (usd per share) | $ / shares	$ 59
Cash portion of Merger consideration | $	$ 29,002
Total shares of common stock and shares underlying Anadarko stock-based awards eligible for merger consideration (n shares)	492,000,000
Exchange ratio (per share of Anadarko common stock)	0.2934
Average share price of Occidental common stock at August 8, 2019 (usd per share) | $ / shares	$ 46.31
Total Merger consideration | $	$ 35,686
Common Stock
Business Acquisition [Line Items]
Total shares of Occidental common stock issued	144,000,000
Average share price of Occidental common stock at August 8, 2019 (usd per share) | $ / shares	$ 46.31
Stock portion of Merger consideration | $	$ 6,684

The Merger - Preliminary Purcha

The Merger - Preliminary Purchase Price Allocation (Details) - Anadarko $ in Millions	Aug. 08, 2019USD ($)
Fair value of assets acquired:
Current assets	$ 3,590
Anadarko's Africa Assets held for sale	10,746
Investments in unconsolidated entities	2,430
Property, plant and equipment, net	48,771
Other assets	797
Intangible assets - WES Midstream	2,400
Amount attributable to assets acquired	78,209
Fair value of liabilities assumed:
Current liabilities	3,677
Liabilities of Anadarko's Africa Assets held for sale	2,329
Long-term debt	12,829
Deferred income taxes	10,040
Asset retirement obligations	2,728
Pension and post retirement obligations	1,125
Non-current derivative liabilities	1,279
Other long-term liabilities	2,308
Amount attributable to liabilities assumed	43,722
Net assets	34,487
Less: Fair value of noncontrolling interests in WES Midstream	4,875
Fair value of net assets acquired	29,612
Goodwill - WES Midstream	6,074
Total Merger consideration	35,686
WES Midstream
Fair value of assets acquired:
Property, plant and equipment, net	9,475
Fair value of liabilities assumed:
Long-term debt	$ 7,407

The Merger - Pro Forma Informat

The Merger - Pro Forma Information (Details) - Anadarko - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Business Acquisition [Line Items]
Revenues	$ 7,335	$ 8,913	$ 22,419	$ 23,095
Net income (loss) attributable to common stockholders	$ (427)	$ 2,060	$ 475	$ 3,405
Net income (loss) attributable to common stockholders per share—basic (in usd per share)	$ (0.50)	$ 2.27	$ 0.51	$ 3.74
Net income (loss) attributable to common stockholders per share—diluted (in usd per share)	$ (0.50)	$ 2.26	$ 0.50	$ 3.73

The Merger - Merger-Related Cos

The Merger - Merger-Related Costs (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Business Acquisition [Line Items]
Total	$ 924	$ 0	$ 974	$ 0
Anadarko
Business Acquisition [Line Items]
Employee severance and related cost	459		459
Licensing fees for critical seismic data	329		354
Bank, legal and consulting fees	136		161
Total	$ 924		$ 974

Acquisitions, Dispositions, a_3

Acquisitions, Dispositions, and Other Transactions - Narrative (Details) ft² in Thousands, $ in Millions	Sep. 23, 2019USD ($)	Jul. 31, 2019USD ($)ft²	Sep. 27, 2019USD ($)
Mozambique LNG Assets | Discontinued Operations, Disposed of by Sale
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Sale for substantially all of assets, liabilities, businesses, and operations			$ 4,200
Plains All American Pipeline, LP
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of equity method investments	$ 646
Pre-tax gain on sale of pipeline	$ 111
Ecopetrol Joint Venture
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Area of development in joint venture | ft²		97
Ownership percentage in joint venture		51.00%
Ecopetrol | Ecopetrol Joint Venture
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Amount due at closing		$ 750
Carried capital		$ 750
Minority interest in new venture		49.00%
Percentage share of capital expenditures		75.00%
Share of capital expenditures (up to)		$ 750

Acquisitions, Dispositions, a_4

Acquisitions, Dispositions, and Other Transactions - Summary of Revenues and Costs from Discontinued Operations (Details) - USD ($) $ in Millions	2 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
COSTS AND OTHER DEDUCTIONS
Discontinued operations, net of tax		$ (15)	$ 0	$ (15)	$ 0
Anadarko's Africa Assets | Discontinued Operations, Disposed of by Sale
REVENUES AND OTHER INCOME
Net sales	$ 228
COSTS AND OTHER DEDUCTIONS
Oil and gas operating expense	32
Transportation and marketing expense	4
Taxes other than on income	46
Fair value adjustment on assets held for sale	65
Selling, general and administrative	8
Other	4
Costs and other deductions, net	159
Income before income taxes	69
Income tax expense	(84)
Discontinued operations, net of tax	$ (15)

Acquisitions, Dispositions, a_5

Acquisitions, Dispositions, and Other Transactions - Summary of Assets Held for Sale (Details) - Anadarko's Africa Assets - Discontinued Operations, Disposed of by Sale $ in Millions	Sep. 30, 2019USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and cash equivalents	$ 16
Inventories	207
Other current assets	110
Property, plant and equipment, net	5,863
Operating lease assets	29
Long-term receivables and other assets, net	220
Assets held for sale	6,445
Current maturities of debt - finance leases	13
Current operating lease liabilities	11
Accounts payable	217
Accrued liabilities	152
Long-term debt, net - finance leases	187
Deferred income taxes	1,281
Asset retirement obligations	142
Other	200
Liabilities of assets held for sale	2,203
Net assets held for sale	$ 4,242

Revenue Recognition - Impact of

Revenue Recognition - Impact of Adoption (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Trade receivables, net	$ 5,854	$ 4,893

Revenue Recognition - Reconcili

Revenue Recognition - Reconciliation (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue from customers	$ 5,231	$ 4,257	$ 12,397	$ 11,813
All other revenue	456	959	1,714	1,249
Net sales	$ 5,687	$ 5,216	$ 14,111	$ 13,062

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregation of revenue (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of revenue
Revenue from customers	$ 5,687	$ 5,216	$ 14,111	$ 13,062
Consolidated	5,231	4,257	12,397	11,813
United States
Disaggregation of revenue
Consolidated	4,420	2,928	9,480	8,501
Middle East
Disaggregation of revenue
Consolidated	908	1,281	2,965	3,226
Latin America
Disaggregation of revenue
Consolidated	218	252	657	713
Other International
Disaggregation of revenue
Consolidated	53	21	90	59
Eliminations
Disaggregation of revenue
Revenue from customers	(368)	(225)	(795)	(686)
Consolidated	(368)	(225)	(795)	(686)
Eliminations | United States
Disaggregation of revenue
Revenue from customers	0	0	0	0
Eliminations | Middle East
Disaggregation of revenue
Revenue from customers	0	0	0	0
Eliminations | Latin America
Disaggregation of revenue
Revenue from customers	0	0	0	0
Eliminations | Other International
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas
Disaggregation of revenue
Revenue from customers	3,746	2,889	8,815	7,874
Oil and Gas | Oil
Disaggregation of revenue
Revenue from customers	3,313	2,539	7,895	6,961
Oil and Gas | NGL
Disaggregation of revenue
Revenue from customers	240	216	535	531
Oil and Gas | Gas
Disaggregation of revenue
Revenue from customers	208	132	427	371
Oil and Gas | Other
Disaggregation of revenue
Revenue from customers	(15)	2	(42)	11
Oil and Gas | United States
Disaggregation of revenue
Revenue from customers	2,737	1,515	5,584	4,397
Oil and Gas | United States | Oil
Disaggregation of revenue
Revenue from customers	2,453	1,326	5,105	3,907
Oil and Gas | United States | NGL
Disaggregation of revenue
Revenue from customers	177	139	339	339
Oil and Gas | United States | Gas
Disaggregation of revenue
Revenue from customers	125	47	180	141
Oil and Gas | United States | Other
Disaggregation of revenue
Revenue from customers	(18)	3	(40)	10
Oil and Gas | Middle East
Disaggregation of revenue
Revenue from customers	827	1,173	2,693	2,918
Oil and Gas | Middle East | Oil
Disaggregation of revenue
Revenue from customers	683	1,016	2,266	2,507
Oil and Gas | Middle East | NGL
Disaggregation of revenue
Revenue from customers	63	77	196	192
Oil and Gas | Middle East | Gas
Disaggregation of revenue
Revenue from customers	78	80	233	218
Oil and Gas | Middle East | Other
Disaggregation of revenue
Revenue from customers	3	0	(2)	1
Oil and Gas | Latin America
Disaggregation of revenue
Revenue from customers	182	201	538	559
Oil and Gas | Latin America | Oil
Disaggregation of revenue
Revenue from customers	177	197	524	547
Oil and Gas | Latin America | NGL
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Latin America | Gas
Disaggregation of revenue
Revenue from customers	5	5	14	12
Oil and Gas | Latin America | Other
Disaggregation of revenue
Revenue from customers	0	(1)	0	0
Oil and Gas | Other International
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Other International | Oil
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Other International | NGL
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Other International | Gas
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Other International | Other
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Eliminations
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Eliminations | Oil
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Eliminations | NGL
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Eliminations | Gas
Disaggregation of revenue
Revenue from customers	0	0	0	0
Oil and Gas | Eliminations | Other
Disaggregation of revenue
Revenue from customers	0	0	0	0
Chemical
Disaggregation of revenue
Revenue from customers	1,061	1,184	3,109	3,507
Chemical | United States
Disaggregation of revenue
Revenue from customers	1,009	1,112	2,937	3,294
Chemical | Middle East
Disaggregation of revenue
Revenue from customers	0	0	0	0
Chemical | Latin America
Disaggregation of revenue
Revenue from customers	36	51	119	154
Chemical | Other International
Disaggregation of revenue
Revenue from customers	16	21	53	59
Chemical | Eliminations
Disaggregation of revenue
Revenue from customers	0	0	0	0
Marketing and Other Midstream
Disaggregation of revenue
Revenue from customers	409	409		1,118
Marketing and Other Midstream | Gas Processing
Disaggregation of revenue
Revenue from customers	174	256	574	724
Marketing and Other Midstream | Pipelines
Disaggregation of revenue
Revenue from customers		115	311	310
Marketing and Other Midstream | Power and Other
Disaggregation of revenue
Revenue from customers	235	38	885	84
Marketing and Other Midstream | United States
Disaggregation of revenue
Revenue from customers	291	301		810
Marketing and Other Midstream | United States | Gas Processing
Disaggregation of revenue
Revenue from customers	93	148	302	416
Marketing and Other Midstream | United States | Pipelines
Disaggregation of revenue
Revenue from customers		115	274	310
Marketing and Other Midstream | United States | Power and Other
Disaggregation of revenue
Revenue from customers	198	38	576	84
Marketing and Other Midstream | Middle East
Disaggregation of revenue
Revenue from customers	81	108		308
Marketing and Other Midstream | Middle East | Gas Processing
Disaggregation of revenue
Revenue from customers	81	108	272	308
Marketing and Other Midstream | Middle East | Pipelines
Disaggregation of revenue
Revenue from customers		0	0	0
Marketing and Other Midstream | Middle East | Power and Other
Disaggregation of revenue
Revenue from customers	0	0	272	0
Marketing and Other Midstream | Latin America
Disaggregation of revenue
Revenue from customers	0	0		0
Marketing and Other Midstream | Latin America | Gas Processing
Disaggregation of revenue
Revenue from customers	0	0	0	0
Marketing and Other Midstream | Latin America | Pipelines
Disaggregation of revenue
Revenue from customers		0	0	0
Marketing and Other Midstream | Latin America | Power and Other
Disaggregation of revenue
Revenue from customers	0	0	0	0
Marketing and Other Midstream | Other International
Disaggregation of revenue
Revenue from customers	37	0		0
Marketing and Other Midstream | Other International | Gas Processing
Disaggregation of revenue
Revenue from customers	0	0	0	0
Marketing and Other Midstream | Other International | Pipelines
Disaggregation of revenue
Revenue from customers		0	37	0
Marketing and Other Midstream | Other International | Power and Other
Disaggregation of revenue
Revenue from customers	37	0	37	0
Marketing and Other Midstream | Eliminations
Disaggregation of revenue
Revenue from customers	0	0		0
Marketing and Other Midstream | Eliminations | Gas Processing
Disaggregation of revenue
Revenue from customers	0	0	0	0
Marketing and Other Midstream | Eliminations | Pipelines
Disaggregation of revenue
Revenue from customers		0	0	0
Marketing and Other Midstream | Eliminations | Power and Other
Disaggregation of revenue
Revenue from customers	0	$ 0	0	$ 0
WES Midstream
Disaggregation of revenue
Revenue from customers	383		383
WES Midstream | United States
Disaggregation of revenue
Revenue from customers	383		383
WES Midstream | Middle East
Disaggregation of revenue
Revenue from customers	0		0
WES Midstream | Latin America
Disaggregation of revenue
Revenue from customers	0		0
WES Midstream | Other International
Disaggregation of revenue
Revenue from customers	0		0
WES Midstream | Eliminations
Disaggregation of revenue
Revenue from customers	$ 0		$ 0

Revenue Recognition - Contract

Revenue Recognition - Contract Liabilities (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Change in Contract with Customer Liability [Roll Forward]
Balance at December 31, 2018	$ 0
Increase due to contract liabilities acquired with Anadarko	154
Increase due to cash received, excluding revenues recognized in the period	9
Decrease due to revenue recognized	(13)
Balance at September 30, 2019	$ 150

Revenue Recognition - Schedule

Revenue Recognition - Schedule of Expected Future Revenue (Details) $ in Millions	Sep. 30, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 92
Remaining performance obligation, period	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01 | Eliminations
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ (127)
Remaining performance obligation, period	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01 | Oil and Gas | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 26
Remaining performance obligation, period	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01 | WES Midstream | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 193
Remaining performance obligation, period	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 377
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Eliminations
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ (589)
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Oil and Gas | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 103
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | WES Midstream | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 863
Remaining performance obligation, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 370
Remaining performance obligation, period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Eliminations
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ (645)
Remaining performance obligation, period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Oil and Gas | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 103
Remaining performance obligation, period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | WES Midstream | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 912
Remaining performance obligation, period	2 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 267
Remaining performance obligation, period	3 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Eliminations
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ (703)
Remaining performance obligation, period	3 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Oil and Gas | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 7
Remaining performance obligation, period	3 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | WES Midstream | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 963
Remaining performance obligation, period	3 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 232
Remaining performance obligation, period	4 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Eliminations
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ (690)
Remaining performance obligation, period	4 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Oil and Gas | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 7
Remaining performance obligation, period	4 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | WES Midstream | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 915
Remaining performance obligation, period	4 years
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 691
Remaining performance obligation, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Eliminations
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ (3,768)
Remaining performance obligation, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Oil and Gas | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 60
Remaining performance obligation, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | WES Midstream | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 4,399
Remaining performance obligation, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 2,029
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Eliminations
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	(6,522)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Oil and Gas | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	306
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | WES Midstream | Operating Segments
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Performance obligation expected to be satisfied	$ 8,245

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Inventory Disclosure [Abstract]
Raw materials	$ 67	$ 74
Materials and supplies	916	445
Commodity inventory and finished goods	665	788
Inventories, gross	1,648	1,307
Revaluation to LIFO	(47)	(47)
Total	$ 1,601	$ 1,260

Derivative Instruments - Summar

Derivative Instruments - Summary of Derivative Instruments (Details) - Crude Oil	Sep. 30, 2019ThousandBarrels / d$ / Barrel
2019 Settlement
Derivative [Line Items]
Derivative instruments (mmbls/day) | ThousandBarrels / d	8,000
2019 Settlement | Short position
Derivative [Line Items]
Ceiling sold price (dollars per barrel)	72.98
Purchase price (dollars per barrel)	46.72
2019 Settlement | Long position
Derivative [Line Items]
Purchase price (dollars per barrel)	56.72
2020 Settlement
Derivative [Line Items]
Derivative instruments (mmbls/day) | ThousandBarrels / d	109,800
2020 Settlement | Short position
Derivative [Line Items]
Ceiling sold price (dollars per barrel)	74.09
Purchase price (dollars per barrel)	45
2020 Settlement | Long position
Derivative [Line Items]
Purchase price (dollars per barrel)	55
2021 Settlement
Derivative [Line Items]
Derivative instruments (mmbls/day) | ThousandBarrels / d	109,500
2021 Settlement | Short position
Derivative [Line Items]
Ceiling sold price (dollars per barrel)	74.09

Derivative Instruments - Intere

Derivative Instruments - Interest-Rate Derivatives (Details) - USD ($) $ in Millions	2 Months Ended
	Sep. 30, 2019	Oct. 11, 2019
Interest Rate Swap, 6.782%
Derivative [Line Items]
Notional Principal Amount	$ 125
Weighted-Average Interest Rate	6.782%
Interest Rate Swap, 6.782% | Subsequent Event
Derivative [Line Items]
Notional Principal Amount		$ 125
Interest Rate Swap, 6.418%
Derivative [Line Items]
Notional Principal Amount	$ 550
Weighted-Average Interest Rate	6.418%
Interest Rate Swap, 6.835%
Derivative [Line Items]
Notional Principal Amount	$ 125
Weighted-Average Interest Rate	6.835%
Interest Rate Swap, 6.891%
Derivative [Line Items]
Notional Principal Amount	$ 100
Weighted-Average Interest Rate	6.891%
Interest Rate Swap, 6.570%
Derivative [Line Items]
Notional Principal Amount	$ 250
Weighted-Average Interest Rate	6.57%
Interest Rate Swap, 6.445%
Derivative [Line Items]
Notional Principal Amount	$ 450
Weighted-Average Interest Rate	6.445%
Interest Rate Swap, 2.662%
Derivative [Line Items]
Notional Principal Amount	$ 375
Weighted-Average Interest Rate	2.662%
Interest Rate Swap, 2.802%
Derivative [Line Items]
Notional Principal Amount	$ 375
Weighted-Average Interest Rate	2.802%
Interest Rate Swap, 2.885%
Derivative [Line Items]
Notional Principal Amount	$ 375
Weighted-Average Interest Rate	2.885%
Interest Rate Swaps
Derivative [Line Items]
Net cash payments related to settlements and amendments	$ 43

Derivative Instruments - Market

Derivative Instruments - Marketing Derivatives and Warrants (Details) $ / shares in Units, $ in Millions	9 Months Ended					12 Months Ended
	Sep. 30, 2019	Sep. 30, 2019Bcf	Sep. 30, 2019MMBbls	Sep. 30, 2019$ / MillionCubicFeet	Sep. 30, 2019$ / Barrel	Dec. 31, 2018Bcf	Dec. 31, 2018MMBbls	Dec. 31, 2018$ / MillionCubicFeet	Dec. 31, 2018$ / Barrel	Aug. 08, 2019USD ($)$ / shares
Marketing Derivatives
Outstanding commodity derivatives contracts not designated as hedging instruments
Derivative instrument settlement period (within)	3 months
Marketing Derivatives | Not designated as hedging instruments
Outstanding commodity derivatives contracts not designated as hedging instruments
Weighted average sales price (dollars per barrel)				2.22	58.39			3.18	58.81
Crude oil | Not designated as hedging instruments | Long position
Outstanding commodity derivatives contracts not designated as hedging instruments
Outstanding net volumes on derivatives not designated as hedges (mmbls/bcf) | MMBbls			36				61
Natural gas | Not designated as hedging instruments | Short position
Outstanding commodity derivatives contracts not designated as hedging instruments
Outstanding net volumes on derivatives not designated as hedges (mmbls/bcf) | Bcf		128				142
Warrant
Outstanding commodity derivatives contracts not designated as hedging instruments
Initial fair value of warrant | $										$ 188
Anadarko | Common Stock
Outstanding commodity derivatives contracts not designated as hedging instruments
Exercise price of warrant (usd per share) | $ / shares										$ 62.50

Derivative Instruments - Cash F

Derivative Instruments - Cash Flow Hedges (Details) $ in Millions		1 Months Ended	3 Months Ended		9 Months Ended
		Aug. 31, 2019USD ($)	Sep. 30, 2019USD ($)Bcf	Sep. 30, 2018USD ($)	Sep. 30, 2019USD ($)Bcf	Sep. 30, 2018USD ($)	Dec. 31, 2018Bcf
Derivative [Line Items]
Natural gas held in storage (in cubic feet) | Bcf			5		5		5
Forecast sale of natural gas from storage designated as cash-flow hedges (in cubic feet) | Bcf			3		3		4
Unrealized loss included in other comprehensive income	[1]		$ (114)	$ (1)	$ (130)	$ (5)
Interest Rate Contract
Derivative [Line Items]
Unrealized loss included in other comprehensive income		$ 125
Interest Rate Contract | Senior Notes
Derivative [Line Items]
Debt issuance, face amount		$ 13,000
[1]	Net of tax of $32 million and zero for the three months ended September 30, 2019 , and 2018, and $36 million and $1 million for the nine months ended September 30, 2019 , and 2018, respectively.

Derivative Instruments - Fair V

Derivative Instruments - Fair Value (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Gross and net fair values of outstanding derivatives (in millions)
Collateral paid netted against derivative liabilities		$ 1
Collateral received netted against derivative assets		45
Collateral deposited with clearinghouses and brokers		178
Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Collateral deposited with clearinghouses and brokers	$ 36
Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Collateral paid netted against derivative liabilities	359
Other current assets | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Netting, asset	(4)
Total net fair value, asset	213
Other current assets | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Netting, asset	(861)	(2,392)
Total net fair value, asset	74	249
Other current assets | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Netting, asset	0
Total net fair value, asset	14
Long-term receivables and other assets, net | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Netting, asset	(70)	(6)
Total net fair value, asset	12	8
Long-term receivables and other assets, net | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Netting, asset	0
Total net fair value, asset	13
Accrued liabilities | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Netting and collateral, liability	(3)
Total net fair value, liability	0
Accrued liabilities | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Netting and collateral, liability	(861)	(2,392)
Total net fair value, liability	11	66
Accrued liabilities | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Netting and collateral, liability	0
Total net fair value, liability	882
Accrued liabilities | Interest Rate Swaps | WES Midstream
Gross and net fair values of outstanding derivatives (in millions)
Netting and collateral, liability	0
Total net fair value, liability	171
Deferred credits and other liabilities - other | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Netting and collateral, liability	0
Total net fair value, liability	97
Deferred credits and other liabilities - other | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Netting and collateral, liability	(70)	(6)
Total net fair value, liability	2	2
Deferred credits and other liabilities - other | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Netting and collateral, liability	0
Total net fair value, liability	879
Deferred credits and other liabilities - other | Warrant
Gross and net fair values of outstanding derivatives (in millions)
Netting and collateral, liability	0
Total net fair value, liability	168
Level 1 | Other current assets | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	0
Level 1 | Other current assets | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	838	2,531
Level 1 | Other current assets | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	0
Level 1 | Long-term receivables and other assets, net | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	70	5
Level 1 | Long-term receivables and other assets, net | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	0
Level 1 | Accrued liabilities | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 1 | Accrued liabilities | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	827	2,357
Level 1 | Accrued liabilities | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 1 | Accrued liabilities | Interest Rate Swaps | WES Midstream
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 1 | Deferred credits and other liabilities - other | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 1 | Deferred credits and other liabilities - other | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	71	6
Level 1 | Deferred credits and other liabilities - other | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 1 | Deferred credits and other liabilities - other | Warrant
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 2 | Other current assets | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	217
Level 2 | Other current assets | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	97	110
Level 2 | Other current assets | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	14
Level 2 | Long-term receivables and other assets, net | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	12	9
Level 2 | Long-term receivables and other assets, net | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	13
Level 2 | Accrued liabilities | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	3
Level 2 | Accrued liabilities | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	45	101
Level 2 | Accrued liabilities | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	882
Level 2 | Accrued liabilities | Interest Rate Swaps | WES Midstream
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	171
Level 2 | Deferred credits and other liabilities - other | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	97
Level 2 | Deferred credits and other liabilities - other | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	1	2
Level 2 | Deferred credits and other liabilities - other | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	879
Level 2 | Deferred credits and other liabilities - other | Warrant
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	168
Level 3 | Other current assets | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	0
Level 3 | Other current assets | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	0	0
Level 3 | Other current assets | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	0
Level 3 | Long-term receivables and other assets, net | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	0	0
Level 3 | Long-term receivables and other assets, net | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative asset, gross	0
Level 3 | Accrued liabilities | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 3 | Accrued liabilities | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0	0
Level 3 | Accrued liabilities | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 3 | Accrued liabilities | Interest Rate Swaps | WES Midstream
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 3 | Deferred credits and other liabilities - other | Oil Collars and Calls
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 3 | Deferred credits and other liabilities - other | Marketing Derivatives
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0	$ 0
Level 3 | Deferred credits and other liabilities - other | Interest Rate Swaps
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	0
Level 3 | Deferred credits and other liabilities - other | Warrant
Gross and net fair values of outstanding derivatives (in millions)
Commodity contract derivative liability, gross	$ 0

Derivative Instruments - Gains

Derivative Instruments - Gains and Losses on Derivatives (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on derivatives	$ (33)	$ 0	$ (33)	$ 0
Oil Collars and Calls | Net sales
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on derivatives	75	0	75	0
Marketing Derivatives | Net sales
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on derivatives	91	36	(119)	8
Interest Rate Swaps | Losses on interest rate swaps and warrants, net
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on derivatives	(45)	0	(45)	0
Interest Rate Swaps | Losses on interest rate swaps and warrants, net | WES Midstream
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on derivatives	(8)	0	(8)	0
Warrant | Losses on interest rate swaps and warrants, net
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) on derivatives	$ 20	$ 0	$ 20	$ 0

Derivative Instruments - Credi

Derivative Instruments - Credit Risk (Details) - Not designated as hedging instruments - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Derivative [Line Items]
Aggregate fair value of derivative instruments with credit-risk-related contingent features for which a net liability position existed (net of collateral)	$ 1,600	$ 68
Amount of collateral posted related to derivative instruments with credit-risk-related contingent features	$ 300	$ 1

Fair Value Measurements (Detail

Fair Value Measurements (Details) $ in Millions	3 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2019USD ($)	Dec. 31, 2018USD ($)
Oil and Gas segment
Liabilities:
Impairment and related charges	$ 285	$ 285
ISSD
Liabilities:
Impairment and related charges	40	41
Qatar ISND and ISSD
Liabilities:
Impairment and related charges			$ 416
Total Fair Value
Liabilities:
Estimated fair value of debt	47,800	47,800	10,300
Total Fair Value | WES Midstream
Liabilities:
Estimated fair value of debt	7,600	7,600
Level 2 | Total Fair Value
Liabilities:
Estimated fair value of debt	12,500	12,500
Recurring | Accrued liabilities
Liabilities:
Netting and Collateral	0	0	0
Recurring | Accrued liabilities | Total Fair Value
Liabilities:
Embedded derivatives	54	54	66
Recurring | Accrued liabilities | Level 1
Liabilities:
Embedded derivatives	0	0	0
Recurring | Accrued liabilities | Level 2
Liabilities:
Embedded derivatives	54	54	66
Recurring | Accrued liabilities | Level 3
Liabilities:
Embedded derivatives	0	0	0
Recurring | Deferred credits and other liabilities - other
Liabilities:
Netting and Collateral	0	0	0
Recurring | Deferred credits and other liabilities - other | Total Fair Value
Liabilities:
Embedded derivatives	73	73	116
Recurring | Deferred credits and other liabilities - other | Level 1
Liabilities:
Embedded derivatives	0	0	0
Recurring | Deferred credits and other liabilities - other | Level 2
Liabilities:
Embedded derivatives	73	73	116
Recurring | Deferred credits and other liabilities - other | Level 3
Liabilities:
Embedded derivatives	$ 0	$ 0	$ 0
Non recurring | Measurement Input, Discount Rate
Liabilities:
Risk adjusted discount rate			0.10

Long-Term Debt - Schedule of Lo

Long-Term Debt - Schedule of Long-term Debt (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Aug. 08, 2019	Dec. 31, 2018
Long-term Debt
Long-term debt, gross	$ 46,931,000		$ 10,407,000
Unamortized premium, net	724,000		(36,000)
Debt issuance costs	(141,000)		(54,000)
Long-term finance leases	69,000
Current maturities	(31,000)		(116,000)
LONG-TERM DEBT, NET	$ 47,583,000		10,201,000
Senior Notes | 4.100% senior notes due 2021
Long-term Debt
Interest rate	4.10%
Long-term debt, gross			1,249,000
Senior Notes | 3.125% senior notes due 2022
Long-term Debt
Interest rate	3.125%
Long-term debt, gross			813,000
Senior Notes | 2.600% senior notes due 2022
Long-term Debt
Interest rate	2.60%
Long-term debt, gross			400,000
Senior Notes | 2.700% senior notes due 2023
Long-term Debt
Interest rate	2.70%
Long-term debt, gross			1,191,000
Senior Notes | 3.500% senior notes due 2025
Long-term Debt
Interest rate	3.50%
Long-term debt, gross			750,000
Senior Notes | 3.400% senior notes due 2026
Long-term Debt
Interest rate	3.40%
Long-term debt, gross			1,150,000
Senior Notes | 3.000% senior notes due 2027
Long-term Debt
Interest rate	3.00%
Long-term debt, gross			750,000
Senior Notes | 7.200% senior debentures due 2028
Long-term Debt
Interest rate	7.20%
Long-term debt, gross			82,000
Senior Notes | 8.450% senior debentures due 2029
Long-term Debt
Interest rate	8.45%
Long-term debt, gross			116,000
Senior Notes | Zero Coupon senior notes due 2036
Long-term Debt
Interest rate	5.24%
Senior Notes | 4.625% senior notes due 2045
Long-term Debt
Interest rate	4.625%
Long-term debt, gross			750,000
Senior Notes | 4.400% senior notes due 2046
Long-term Debt
Interest rate	4.40%
Long-term debt, gross			1,200,000
Senior Notes | 4.100% senior notes due 2047
Long-term Debt
Interest rate	4.10%
Long-term debt, gross			750,000
Senior Notes | 4.200% senior notes due 2048
Long-term Debt
Interest rate	4.20%
Long-term debt, gross			1,000,000
Senior Notes | 9.250% senior debentures due 2019
Long-term Debt
Interest rate	9.25%
Long-term debt, gross			$ 116,000
Variable Rate Bonds | Variable rate bonds due 2030 (1.9% as of December 31, 2018)
Long-term Debt
Effective interest rate			1.90%
Long-term debt, gross			$ 68,000
Medium-term Notes | 8.750% medium-term notes due 2023
Long-term Debt
Interest rate	8.75%
Long-term debt, gross			22,000
Occidental
Long-term Debt
Long-term debt, gross	$ 39,151,000
Unamortized premium, net	859,000
Debt issuance costs	(133,000)
Long-term finance leases	69,000
Long-term debt	39,946,000
LONG-TERM DEBT, NET	$ 39,946,000		10,201,000
Occidental | Senior Notes | 4.850% senior notes due 2021
Long-term Debt
Interest rate	4.85%
Long-term debt, gross	$ 677,000
Occidental | Senior Notes | 2.600% senior notes due 2021
Long-term Debt
Interest rate	2.60%
Long-term debt, gross	$ 1,500,000
Occidental | Senior Notes | 4.100% senior notes due 2021
Long-term Debt
Interest rate	4.10%
Long-term debt, gross	$ 1,249,000
Occidental | Senior Notes | 2.700% senior notes due 2022
Long-term Debt
Interest rate	2.70%
Long-term debt, gross	$ 2,000,000
Occidental | Senior Notes | 3.125% senior notes due 2022
Long-term Debt
Interest rate	3.125%
Long-term debt, gross	$ 814,000
Occidental | Senior Notes | 2.600% senior notes due 2022
Long-term Debt
Interest rate	2.60%
Long-term debt, gross	$ 400,000
Occidental | Senior Notes | 2.700% senior notes due 2023
Long-term Debt
Interest rate	2.70%
Long-term debt, gross	$ 1,191,000
Occidental | Senior Notes | 2.900% senior notes due 2024
Long-term Debt
Interest rate	2.90%
Long-term debt, gross	$ 3,000,000
Occidental | Senior Notes | 6.950% senior notes due 2024
Long-term Debt
Interest rate	6.95%
Long-term debt, gross	$ 650,000
Occidental | Senior Notes | 3.450% senior notes due 2024
Long-term Debt
Interest rate	3.45%
Long-term debt, gross	$ 248,000
Occidental | Senior Notes | 3.500% senior notes due 2025
Long-term Debt
Interest rate	3.50%
Long-term debt, gross	$ 750,000
Occidental | Senior Notes | 5.550% senior notes due 2026
Long-term Debt
Interest rate	5.55%
Long-term debt, gross	$ 1,100,000
Occidental | Senior Notes | 3.200% senior notes due 2026
Long-term Debt
Interest rate	3.20%
Long-term debt, gross	$ 1,000,000
Occidental | Senior Notes | 3.400% senior notes due 2026
Long-term Debt
Interest rate	3.40%
Long-term debt, gross	$ 1,150,000
Occidental | Senior Notes | 7.500% debentures due 2026
Long-term Debt
Interest rate	7.50%
Occidental | Senior Notes | 3.000% senior notes due 2027
Long-term Debt
Interest rate	3.00%
Long-term debt, gross	$ 750,000
Occidental | Senior Notes | 7.125% debentures due 2027
Long-term Debt
Interest rate	7.125%
Occidental | Senior Notes | 7.000% debentures due 2027
Long-term Debt
Interest rate	7.00%
Occidental | Senior Notes | 6.625% debentures due 2028
Long-term Debt
Interest rate	6.625%
Occidental | Senior Notes | 7.150% debentures due 2028
Long-term Debt
Interest rate	7.15%
Occidental | Senior Notes | 7.200% senior debentures due 2028
Long-term Debt
Interest rate	7.20%
Long-term debt, gross	$ 82,000
Occidental | Senior Notes | 7.200% debentures due 2029
Long-term Debt
Interest rate	7.20%
Occidental | Senior Notes | 7.950% debentures due 2029
Long-term Debt
Interest rate	7.95%
Occidental | Senior Notes | 8.450% senior debentures due 2029
Long-term Debt
Interest rate	8.45%
Long-term debt, gross	$ 116,000
Occidental | Senior Notes | 3.500 senior notes due 2029
Long-term Debt
Interest rate	3.50%
Long-term debt, gross	$ 1,500,000
Occidental | Senior Notes | 7.500% senior notes due 2031
Long-term Debt
Interest rate	7.50%
Long-term debt, gross	$ 900,000
Occidental | Senior Notes | 7.875% senior notes due 2031
Long-term Debt
Interest rate	7.875%
Long-term debt, gross	$ 500,000
Occidental | Senior Notes | 6.450% senior notes due 2036
Long-term Debt
Interest rate	6.45%
Long-term debt, gross	$ 1,750,000
Occidental | Senior Notes | Zero Coupon senior notes due 2036
Long-term Debt
Long-term debt, gross	$ 2,271,000
Occidental | Senior Notes | 4.300% senior notes due 2039
Long-term Debt
Interest rate	4.30%
Long-term debt, gross	$ 750,000
Occidental | Senior Notes | 7.950% senior notes due 2039
Long-term Debt
Interest rate	7.95%
Long-term debt, gross	$ 325,000
Occidental | Senior Notes | 6.200% senior notes due 2040
Long-term Debt
Interest rate	6.20%
Long-term debt, gross	$ 750,000
Occidental | Senior Notes | 4.500% senior notes due 2044
Long-term Debt
Interest rate	4.50%
Long-term debt, gross	$ 625,000
Occidental | Senior Notes | 4.625% senior notes due 2045
Long-term Debt
Interest rate	4.625%
Long-term debt, gross	$ 750,000
Occidental | Senior Notes | 6.600% senior notes due 2046
Long-term Debt
Interest rate	6.60%
Long-term debt, gross	$ 1,100,000
Occidental | Senior Notes | 4.400% senior notes due 2046
Long-term Debt
Interest rate	4.40%
Long-term debt, gross	$ 1,200,000
Occidental | Senior Notes | 4.100% senior notes due 2047
Long-term Debt
Interest rate	4.10%
Long-term debt, gross	$ 750,000
Occidental | Senior Notes | 4.200% senior notes due 2048
Long-term Debt
Interest rate	4.20%
Long-term debt, gross	$ 1,000,000
Occidental | Senior Notes | 4.400% senior notes due 2049
Long-term Debt
Interest rate	4.40%
Long-term debt, gross	$ 750,000
Occidental | Variable Rate Bonds | Variable rate bonds due 2021
Long-term Debt
Effective interest rate	3.137%
Long-term debt, gross	$ 500,000
Occidental | Variable Rate Bonds | Variable rate bonds due 2021
Long-term Debt
Effective interest rate	3.437%
Long-term debt, gross	$ 500,000
Occidental | Variable Rate Bonds | 2-year variable rate Term Loan due 2021
Long-term Debt
Effective interest rate	3.417%
Occidental | Variable Rate Bonds | Variable rate bonds due 2022
Long-term Debt
Effective interest rate	3.637%
Long-term debt, gross	$ 1,500,000
Occidental | Variable Rate Bonds | Variable rate bonds due 2030
Long-term Debt
Effective interest rate	1.785%
Long-term debt, gross	$ 68,000
Occidental | Medium-term Notes | 8.750% medium-term notes due 2023
Long-term Debt
Interest rate	8.75%
Long-term debt, gross	$ 22,000
Occidental | Debentures | 7.500% debentures due 2026
Long-term Debt
Long-term debt, gross	112,000
Occidental | Debentures | 7.125% debentures due 2027
Long-term Debt
Long-term debt, gross	150,000
Occidental | Debentures | 7.000% debentures due 2027
Long-term Debt
Long-term debt, gross	48,000
Occidental | Debentures | 6.625% debentures due 2028
Long-term Debt
Long-term debt, gross	14,000
Occidental | Debentures | 7.150% debentures due 2028
Long-term Debt
Long-term debt, gross	235,000
Occidental | Debentures | 7.200% debentures due 2029
Long-term Debt
Long-term debt, gross	135,000
Occidental | Debentures | 7.950% debentures due 2029
Long-term Debt
Long-term debt, gross	$ 116,000
Occidental | Debentures | 7.730% debentures due 2096
Long-term Debt
Interest rate	7.73%
Long-term debt, gross	$ 60,000
Occidental | Debentures | 7.500% debentures due 2096
Long-term Debt
Interest rate	7.50%
Long-term debt, gross	$ 78,000
Occidental | Debentures | 7.250% debentures due 2096
Long-term Debt
Interest rate	7.25%
Long-term debt, gross	$ 49,000
Occidental | Debentures | 7.250% senior notes due 2025
Long-term Debt
Interest rate	7.25%
Long-term debt, gross	$ 310
Occidental | The Term Loans | 2-year variable rate Term Loan due 2021
Long-term Debt
Effective interest rate	3.417%
Debt instrument term	2 years
Long-term debt, gross	$ 3,966,000
WES
Long-term Debt
Long-term debt, gross	7,780,000
Unamortized discount net	(135,000)
Debt issuance costs	(8,000)
Long-term debt		$ 4,600,000
LONG-TERM DEBT, NET	7,637,000		$ 0
WES | Senior Notes
Long-term Debt
Long-term debt	$ 4,600,000
WES | Senior Notes | 5.375% senior notes due 2021
Long-term Debt
Interest rate	5.375%
Long-term debt, gross	$ 500,000
WES | Senior Notes | 4.000% senior notes due 2022
Long-term Debt
Interest rate	4.00%
Long-term debt, gross	$ 670,000
WES | Senior Notes | 3.950% senior notes due 2025
Long-term Debt
Interest rate	3.95%
Long-term debt, gross	$ 500,000
WES | Senior Notes | 4.650% senior notes due 2026
Long-term Debt
Interest rate	4.65%
Long-term debt, gross	$ 500,000
WES | Senior Notes | 4.500% senior notes due 2028
Long-term Debt
Interest rate	4.50%
Long-term debt, gross	$ 400,000
WES | Senior Notes | 4.750% senior notes due 2028
Long-term Debt
Interest rate	4.75%
Long-term debt, gross	$ 400,000
WES | Senior Notes | 5.450% senior notes due 2044
Long-term Debt
Interest rate	5.45%
Long-term debt, gross	$ 600,000
WES | Senior Notes | 5.300% senior notes due 2048
Long-term Debt
Interest rate	5.30%
Long-term debt, gross	$ 700,000
WES | Senior Notes | 5.500% senior notes due 2048
Long-term Debt
Interest rate	5.50%
Long-term debt, gross	$ 350,000
WES | The Term Loans
Long-term Debt
Long-term debt	$ 3,000,000
WES | The Term Loans | Term Loan Facility
Long-term Debt
Effective interest rate	3.42%
Long-term debt, gross	$ 3,000,000
WES | Line of Credit | Revolving Credit Facility
Long-term Debt
Effective interest rate	3.34%
Long-term debt, gross	$ 160,000

Long-Term Debt - Narrative (Det

Long-Term Debt - Narrative (Details) - USD ($)	Aug. 08, 2019	Sep. 30, 2019	Aug. 07, 2019	Jun. 04, 2019	Jun. 03, 2019
Revolving Credit Facility
Long-term Debt
Revolving credit facility, maximum borrowing capacity			$ 3,000,000,000
Anadarko
Long-term Debt
Debt issuance, face amount	$ 21,800,000,000
Term loan balance	11,900,000,000
Anadarko | Revolving Credit Facility
Long-term Debt
Revolving credit facility balance	2,900,000,000
Revolving credit facility, maximum borrowing capacity				$ 5,000,000,000	$ 3,000,000,000
Senior Notes | Anadarko
Long-term Debt
Debt issuance, face amount	13,000,000,000
Term loan balance	11,900,000,000
Percentage of Anadarko debt tendered and exchanged		97.00%
Amount tendered and exchanged		$ 11,500,000,000
Amount not tendered and exchanged		400,000,000
Senior Notes | Zero Coupon senior notes due 2036
Long-term Debt
Debt issuance, face amount		$ 2,300,000,000
Interest rate		5.24%
Repurchase amount if put in whole		$ 992,000,000
Line of Credit | 364-Day Senior Unsecured Term Loan Facility | Anadarko
Long-term Debt
Debt issuance, face amount	$ 4,400,000,000
Debt instrument term	364 days
Line of Credit | Term Loan Facility | Anadarko
Long-term Debt
Debt issuance, face amount	$ 4,400,000,000
Debt instrument term	2 years
The Term Loans
Long-term Debt
Pay down of term loans		4,800,000,000
The Term Loans | Anadarko
Long-term Debt
Debt issuance, face amount	$ 8,800,000,000
WES
Long-term Debt
Term loan balance	$ 4,600,000,000
WES | Senior Notes
Long-term Debt
Term loan balance		4,600,000,000
WES | Line of Credit
Long-term Debt
Revolving credit facility balance		160,000,000
WES | Line of Credit | Revolving Credit Facility
Long-term Debt
Revolving credit facility, maximum borrowing capacity		2,000,000,000
WES | The Term Loans
Long-term Debt
Term loan balance		3,000,000,000
Exclusion for debt offering proceeds		1,000,000,000
Proceeds from Issuance of Secured Debt		$ 1,000,000,000

Lease Commitments - Narrative (

Lease Commitments - Narrative (Details) - USD ($) $ in Millions	Sep. 30, 2019	Aug. 08, 2019	Jan. 01, 2019
Lessee, Lease, Description [Line Items]
Operating lease assets	$ 1,078
Total lease liabilities	1,139	$ 488
Finance lease agreement	100	86
Offshore and onshore drilling rigs
Lessee, Lease, Description [Line Items]
Operating lease assets	186
Compressors
Lessee, Lease, Description [Line Items]
Operating lease assets	174
Other field equipment
Lessee, Lease, Description [Line Items]
Operating lease assets	$ 97
Oil and gas exploration and development equipment | Minimum
Lessee, Lease, Description [Line Items]
Contract expiration term	2 years
Oil and gas exploration and development equipment | Maximum
Lessee, Lease, Description [Line Items]
Contract expiration term	7 years
Pipelines, rail cars, storage facilities, easements and real estate
Lessee, Lease, Description [Line Items]
Operating lease assets	$ 682
Real estate leases | Minimum
Lessee, Lease, Description [Line Items]
Contract expiration term	1 year
Real estate leases | Maximum
Lessee, Lease, Description [Line Items]
Contract expiration term	16 years
Oil and gas exploration and development equipment, real estate offices, compressors, and field equipment
Lessee, Lease, Description [Line Items]
Finance lease agreement	$ 100
Anadarko
Lessee, Lease, Description [Line Items]
Operating lease assets		498
Total lease liabilities		$ 574
Accounting Standards Update 2016-02
Lessee, Lease, Description [Line Items]
Operating lease assets			$ 772
Total lease liabilities			$ 772

Lease Commitments - Schedule of

Lease Commitments - Schedule of Operating and Finance Lease Maturities (Details) - USD ($) $ in Millions	Sep. 30, 2019	Aug. 08, 2019
Operating Leases
Remainder of 2019	$ 119	$ 90
2020	390	172
2021	197	64
2022	129	42
2023	94	28
Thereafter	311	136
Total lease payments	1,240	532
Less: Interest	(101)	(44)
Total lease liabilities	1,139	488
Finance Leases
Remainder of 2019	8	7
2020	38	25
2021	15	15
2022	12	12
2023	7	7
Thereafter	42	42
Total lease payments	122	108
Less: Interest	(22)	(22)
Total lease liabilities	100	86
Total
Remainder of 2019	127	97
2020	428	197
2021	212	79
2022	141	54
2023	101	35
Thereafter	353	178
Total lease payments	1,362	640
Less: Interest	(123)	(66)
Total lease liabilities	$ 1,239	$ 574
Weighted average lease term, operating lease	5 years 3 months 18 days
Weighted average discount rate, operating lease	2.79%
Weighted average lease term, finance lease	6 years 4 months 24 days
Weighted average discount rate, finance lease	4.92%

Lease Commitments - Lease Asset

Lease Commitments - Lease Assets and Liabilities (Details) $ in Millions	Sep. 30, 2019USD ($)
Assets:
Operating lease assets	$ 1,078
Finance lease assets	97
Total leased assets	1,175
Liabilities:
Operating lease liabilities, current	463
Finance lease liabilities, current	31
Operating lease liabilities, non-current	676
Finance lease liabilities, non-current	69
Total lease liabilities	$ 1,239

Lease Commitments - Schedule _2

Lease Commitments - Schedule of Future Minimum Lease Payments (Details) $ in Millions	Dec. 31, 2018USD ($)
Leases [Abstract]
2019	$ 186
2020	147
2021	96
2022	68
2023	49
Thereafter	158
Total minimum lease payments(a)	$ 704

Lease Commitments - Other Infor

Lease Commitments - Other Information (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Lessee, Lease, Description [Line Items]
Operating lease costs	$ 139	$ 321
Amortization of ROU assets	5	11
Interest on lease liabilities	1	1
Lease, Cost	304	665
Short-term lease cost	139	295
Variable lease cost	55	115
Operating cash flows		162
Investing cash flows		83
Financing cash flows		11
Cost of sales
Lessee, Lease, Description [Line Items]
Operating lease costs	133	271
Selling, general and administrative expenses
Lessee, Lease, Description [Line Items]
Operating lease costs	$ 26	$ 61

Lawsuits, Claims, Commitments_2

Lawsuits, Claims, Commitments and Contingencies (Details) $ in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)	Dec. 31, 2017	Dec. 31, 2016USD ($)	Aug. 08, 2019group	May 30, 2019USD ($)
Lawsuits, commitments and contingencies
Accumulated Occidental common stock						$ 1,600
Number of separate federal consolidated groups | group					2
Potential cash tax	$ 917
Federal
Lawsuits, commitments and contingencies
Potential cash tax	898
State
Lawsuits, commitments and contingencies
Tentative cash tax refund	2	$ 2
Potential cash tax	19
Anadarko
Lawsuits, commitments and contingencies
Tentative cash tax refund				$ 881
Potential accrued interest	$ 171
Arbitration filed by Andes Petroleum Ecuador Ltd
Lawsuits, commitments and contingencies
Proceeds from settlement				$ 1,000
Recovery of amount awarded in settlement amount (as a percent)				60.00%
Percentage of judgment amount claimed			40.00%
Own economic interest (as a percent)			60.00%

Lawsuits, Claims, Commitments_3

Lawsuits, Claims, Commitments and Contingencies - Purchase Obligations (Details) - Anadarko $ in Millions	Sep. 30, 2019USD ($)
Purchase obligations
Total purchase obligations	$ 5,200
Purchase obligations, due in reminder fiscal year 2019	315
Purchase obligations, due in fiscal year 2020	1,000
Purchase obligations, due in fiscal year 2021	907
Purchase obligations, due in fiscal year 2022	735
Purchase obligations, due in fiscal year 2023	589
Purchase obligations, due in fiscal year 2024 and thereafter	$ 1,600
Purchase obligation, discount rate	3.88%

Environmental Liabilities and_3

Environmental Liabilities and Expenditures (Details) $ in Millions	1 Months Ended	3 Months Ended	6 Months Ended	9 Months Ended
	Mar. 31, 2016mi	Sep. 30, 2016USD ($)	Jun. 30, 2019USD ($)category	Sep. 30, 2019USD ($)site	Dec. 31, 2018USD ($)
Environmental remediation reserves
Number of Sites | site				185
Environmental remediation reserves, current, included in accrued liabilities			$ 149
Environmental remediation reserves, non-current, included in deferred credits and other liabilities - other			$ 905	$ 905	$ 762
Number of non-NPL sites categories | category			3
Reserve Balance				$ 1,054
Environmental reserves, exceeding $ ten million, threshold value			$ 10
Environmental reserves, exceeding $ ten million, number of sites | site				19
Environmental reserves, range between zero to $ one million site category, number of sites | site				112
Expected expend funds of environmental reserves (as a percent)				40.00%
Minimum period of expending second half of environmental reserves			10 years
Environmental remediation additional loss range				$ 1,200
Low end of range
Environmental remediation reserves
Period of expending first half of environmental reserves				3 years
High end of range
Environmental remediation reserves
Environmental reserves, range between zero to $ one million site category			$ 1
Period of expending first half of environmental reserves			4 years
NPL sites
Environmental remediation reserves
Number of Sites | site				34
Reserve Balance				$ 452
Third-party sites
Environmental remediation reserves
Number of Sites | site				66
Reserve Balance				$ 223
Occidental-operated sites
Environmental remediation reserves
Number of Sites | site				14
Reserve Balance				$ 110
Closed or non-operated Occidental sites
Environmental remediation reserves
Number of Sites | site				29
Reserve Balance				$ 127
Environmental sites assumed from the Merger
Environmental remediation reserves
Number of Sites | site				42
Reserve Balance				$ 142
Lower Passaic River
Environmental remediation reserves
Stretch of Lower Passaic river requiring remedial actions | mi	8.3
Stretch of Lower Passaic river not covered by remedial actions | mi	9
Clean-up estimated cost		$ 165
Anadarko
Environmental remediation reserves
Number of Sites | site				42

Retirement and Postretirement_2

Retirement and Postretirement Benefit Plans - Components of Net Periodic Benefit Costs (Details) - USD ($) $ in Millions	Aug. 08, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Net Periodic Benefit Costs
Accumulated other comprehensive income eliminated in purchase price accounting	$ 390
Pension Benefit
Net Periodic Benefit Costs
Increase in benefit obligation from remeasurement	$ 193
Curtailment gain		$ 34		$ 10
Net periodic benefit cost		15	$ 2	19	$ 4
Employer contributions		7	2	8	4
Postretirement Benefit
Net Periodic Benefit Costs
Net periodic benefit cost		$ 19	$ 15	$ 48	$ 55

Stockholders' Equity (Details)

Stockholders' Equity (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Common stock issuances
Balance at the beginning of the year (in shares)			895,115,637
Balance at the end of the year (in shares)	1,043,640,621		1,043,640,621
Basic earnings (loss) per common share
Net income (loss) attributable to common stockholders	$ (912)	$ 1,869	$ 354	$ 3,425
Less: Net income allocated to participating securities	0	8	1	16
Net income (loss), net of participating securities	$ (912)	$ 1,861	$ 353	$ 3,409
Weighted average number of basic shares (in shares)	845,700,000	761,700,000	781,100,000	764,300,000
Net income (loss) attributable to common stockholders per share—basic (in usd per share)	$ (1.08)	$ 2.44	$ 0.45	$ 4.46
Diluted earnings (loss) per common share
Net income (loss), net of participating securities	$ (912)	$ 1,861	$ 353	$ 3,409
Weighted average number of basic shares (in shares)	845,700,000	761,700,000	781,100,000	764,300,000
Dilutive securities (in shares)	0	1,600,000	1,100,000	1,500,000
Total diluted weighted average common shares (in shares)	845,700,000	763,300,000	782,200,000	765,800,000
Net income (loss) attributable to common stockholders per share—diluted (in usd per share)	$ (1.08)	$ 2.44	$ 0.45	$ 4.45
Accumulated other comprehensive loss
Beginning balance	$ 21,347	$ 20,931	$ 21,330	$ 20,572
Other comprehensive loss, before reclassifications			(160)
Ending balance	41,005	21,488	$ 41,005	21,488
Anadarko
Common stock issuances
Treasury stock (in shares)			2,000,000
Common Stock
Common stock issuances
Issued in the ordinary course (in shares)			2,394,000
Issued as part of the Merger (in shares)			146,131,000
Accumulated other comprehensive loss
Beginning balance	179	179	$ 179	179
Ending balance	209	179	209	179
Gains and (losses) on derivatives
Accumulated other comprehensive loss
Beginning balance			5
Other comprehensive loss, before reclassifications			(130)
Ending balance	(125)		(125)
Pension and postretirement benefit plans
Accumulated other comprehensive loss
Beginning balance			(170)
Other comprehensive loss, before reclassifications			(30)
Ending balance	(200)		(200)
Foreign currency translation adjustments
Accumulated other comprehensive loss
Beginning balance			(7)
Other comprehensive loss, before reclassifications			0
Ending balance	(7)		(7)
Accumulated Other Comprehensive Loss
Accumulated other comprehensive loss
Beginning balance	(184)	(308)	(172)	(258)
Ending balance	$ (332)	$ (155)	$ (332)	$ (155)

Stockholders' Equity - Narrativ

Stockholders' Equity - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	Oct. 15, 2019	Aug. 08, 2019	Sep. 30, 2019	Dec. 31, 2018
Class of Stock [Line Items]
Preferred stock, authorized shares (in shares)			50,000,000
Preferred stock, par value (in dollars per share)			$ 1	$ 1
Preferred stock, issued (in shares)			100,000
Preferred stock, outstanding (in shares)			100,000	0
Series A Preferred Stock | Subsequent Event
Class of Stock [Line Items]
Payments of preferred stock dividends	$ 149
Anadarko | Series A Preferred Stock
Class of Stock [Line Items]
Issued as part of the Merger (in shares)		100,000
Face value (in usd per share)		$ 100,000
Preferred stock accrual rate per annum		8.00%
Preferred stock accrual rate per annum on unpaid amounts		9.00%

Industry Segments - Schedule of

Industry Segments - Schedule of Industry Segments and Eliminations (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)	Sep. 30, 2019USD ($)segment	Sep. 30, 2018USD ($)
Segment Information
Number of operating segments | segment			4
Net sales	$ 5,687	$ 5,216	$ 14,111	$ 13,062
Income (loss) from continuing operations before income taxes	(621)	2,579	1,176	4,776
Income tax expense	(116)	(710)	(647)	(1,351)
Income (loss) from continuing operations	(737)	1,869	529	3,425
Anadarko merger-related costs	924	0	974	0
Amortization of debt financing fees	65		122
Operating Segments | Oil and Gas
Segment Information
Net sales	3,821	2,889	8,890	7,874
Income (loss) from continuing operations before income taxes	221	767	1,431	2,297
Income tax expense	0	0	0	0
Income (loss) from continuing operations	221	767	1,431	2,297
Operating Segments | Chemical
Segment Information
Net sales	1,071	1,185	3,128	3,515
Income (loss) from continuing operations before income taxes	207	321	680	936
Income tax expense	0	0	0	0
Income (loss) from continuing operations	207	321	680	936
Operating Segments | Marketing and Other Midstream
Segment Information
Net sales	780	1,367	2,505	2,359
Income (loss) from continuing operations before income taxes	266	1,698	876	2,127
Income tax expense	0	0	0	0
Income (loss) from continuing operations	266	1,698	876	2,127
Operating Segments | WES Midstream
Segment Information
Net sales	383	0	383	0
Income (loss) from continuing operations before income taxes	134	0	134	0
Income tax expense	0	0
Income (loss) from continuing operations	134	0	134	0
Corporate and Eliminations
Segment Information
Net sales	(368)	(225)	(795)	(686)
Income (loss) from continuing operations before income taxes	(1,449)	(207)	(1,945)	(584)
Income tax expense	(116)	(710)	(647)	(1,351)
Income (loss) from continuing operations	$ (1,565)	$ (917)	$ (2,592)	$ (1,935)