Occidental Petroleum (OXY) 10-K 3 Mar 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Billions, except Share data, unless otherwise specified	Dec. 31, 2013	Jan. 31, 2014	Jun. 30, 2013
Document and Entity Information	'	'	'
Entity Registrant Name	'OCCIDENTAL PETROLEUM CORP /DE/	'	'
Entity Central Index Key	'0000797468	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Public Float	'	'	$70.60
Entity Common Stock, Shares Outstanding	'	794,747,955	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
CURRENT ASSETS	'	'
Cash and cash equivalents	$3,393	$1,592
Trade receivables, net of reserves of $17 in 2013 and $16 in 2012	5,674	4,916
Inventories	1,200	1,344
Other current assets	1,056	1,640
Total current assets	11,323	9,492
INVESTMENTS IN UNCONSOLIDATED ENTITIES	1,459	1,894
PROPERTY, PLANT AND EQUIPMENT	'	'
Oil and gas segment	72,367	65,417
Chemical segment	6,446	6,054
Midstream, marketing and other segment	8,684	7,191
Corporate	1,555	1,434
GROSS PROPERTY, PLANT AND EQUIPMENT	89,052	80,096
Accumulated depreciation, depletion and amortization	-33,231	-28,032
TOTAL PROPERTY, PLANT AND EQUIPMENT	55,821	52,064
LONG-TERM RECEIVABLES AND OTHER ASSETS, NET	840	760
TOTAL ASSETS	69,443	64,210
CURRENT LIABILITIES	'	'
Current maturities of long-term debt	'	600
Accounts payable	5,520	4,708
Accrued liabilities	2,556	1,966
Domestic and foreign income taxes	358	16
Total current liabilities	8,434	7,290
LONG-TERM DEBT, NET	6,939	7,023
DEFERRED CREDITS AND OTHER LIABILITIES	'	'
Deferred domestic and foreign income taxes	7,197	6,039
Other	3,501	3,810
Total deferred credits and other liabilities	10,698	9,849
CONTINGENT LIABILITIES AND COMMITMENTS	'	'
STOCKHOLDERS' EQUITY	'	'
Common stock, $0.20 per share par value, authorized shares: 1.1 billion, outstanding shares: 2013 - 889,919,058 and 2012 - 888,801,436	178	178
Treasury stock: 2013 - 93,928,179 shares and 2012 - 83,287,187 shares	-6,095	-5,091
Additional paid-in capital	7,515	7,441
Retained earnings	41,831	37,990
Accumulated other comprehensive loss	-303	-502
Total equity attributable to common stock	43,126	40,016
Noncontrolling interest	246	32
Total equity	43,372	40,048
TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$69,443	$64,210

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
CONSOLIDATED CONDENSED BALANCE SHEETS	'	'
Trade receivables, reserves (in dollars)	$17	$16
Common stock, per share par value (in dollars per share)	$0.20	$0.20
Common stock, authorized shares	1,100,000,000	1,100,000,000
Common stock, outstanding shares	889,919,058	888,801,436
Treasury stock, shares	93,928,179	83,287,187

Consolidated_Statements_of_Inc

Consolidated Statements of Income (USD $)	12 Months Ended
In Millions, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
REVENUES AND OTHER INCOME	'	'	'
Net sales	$24,455	$24,172	$23,939
Interest, dividends and other income	106	81	180
Gain on sale of equity investments	1,175	'	'
TOTAL REVENUES AND OTHER INCOME	25,736	24,253	24,119
COSTS AND OTHER DEDUCTIONS	'	'	'
Cost of sales (excludes depreciation, depletion and amortization of $5,341 in 2013, $4,504 in 2012 and $3,584 in 2011)	7,562	7,844	7,385
Selling, general and administrative and other operating expenses	1,801	1,602	1,523
Depreciation, depletion and amortization	5,347	4,511	3,591
Asset impairments and related items	621	1,751	'
Taxes other than on income	749	680	605
Exploration expense	256	345	258
Interest and debt expense, net	118	130	298
TOTAL COSTS AND OTHER DEDUCTIONS	16,454	16,863	13,660
INCOME BEFORE INCOME TAXES AND OTHER ITEMS	9,282	7,390	10,459
Provision for domestic and foreign income taxes	-3,755	-3,118	-4,201
Income from equity investments	395	363	382
INCOME FROM CONTINUING OPERATIONS	5,922	4,635	6,640
Discontinued operations, net	-19	-37	131
NET INCOME	$5,903	$4,598	$6,771
BASIC EARNINGS PER COMMON SHARE	'	'	'
Income from continuing operations (in dollars per share)	$7.35	$5.72	$8.16
Discontinued operations, net (in dollars per share)	($0.02)	($0.05)	$0.16
BASIC EARNINGS PER COMMON SHARE (in dollars per share)	$7.33	$5.67	$8.32
DILUTED EARNINGS PER COMMON SHARE	'	'	'
Income from continuing operations (in dollars per share)	$7.34	$5.71	$8.16
Discontinued operations, net (in dollars per share)	($0.02)	($0.04)	$0.16
DILUTED EARNINGS PER COMMON SHARE (in dollars per share)	$7.32	$5.67	$8.32
DIVIDENDS PER COMMON SHARE (in dollars per share)	$2.56	$2.16	$1.84

Consolidated_Statements_of_Inc1

Consolidated Statements of Income (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Consolidated Statements of Income	'	'	'
Cost of sales, depreciation, depletion and amortization	$5,341	$4,504	$3,584

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Consolidated Statements of Comprehensive Income	'		'		'
Net income	$5,903		$4,598		$6,771
Other comprehensive income (loss) items:	'		'		'
Foreign currency translation gains (losses)	2		-25		-11
Realized foreign currency translation losses	28		'		'
Unrealized (losses) gains on derivatives	-3	[1]	16	[1]	14	[1]
Pension and postretirement gains (losses)	176	[2]	14	[2]	-60	[2]
Reclassification to income of realized (gains) losses on derivatives	-4	[3]	-24	[3]	98	[3]
Other comprehensive income (loss), net of tax	199	[4]	-19	[4]	41	[4]
Comprehensive income	$6,102		$4,579		$6,812
[1]	Net of tax of $2, $(9) and $(7) in 2013, 2012 and 2011, respectively.
[2]	Net of tax of $(101), $(8) and $34 in 2013, 2012 and 2011, respectively. See Note 13, Retirement and Postretirement Benefit Plans, for additional information.
[3]	Net of tax of $2, $14 and $(56) in 2013, 2012 and 2011, respectively.
[4]	There were no other comprehensive income (loss) items related to noncontrolling interests in 2013, 2012 and 2011.

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Consolidated Statements of Comprehensive Income	'	'	'
Unrealized (losses) gains on derivatives, tax	$2	($9)	($7)
Pension and postretirement gains (losses), tax	-101	-8	34
Reclassification to income of realized (gains) losses on derivatives, tax	$2	$14	($56)

Consolidated_Statements_of_Sto

Consolidated Statements of Stockholders' Equity (USD $)	Total		Common Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interest
In Millions, unless otherwise specified
Balance at Dec. 31, 2010	$32,484		$177	($4,228)	$7,191	$29,868	($524)	'
Increase (Decrease) in Stockholders' Equity	'		'	'	'	'	'	'
Net income	6,771		'	'	'	6,771	'	'
Other comprehensive income (loss), net of tax	41	[1]	'	'	'	'	41	'
Dividends on common stock	-1,497		'	'	'	-1,497	'	'
Issuance of common stock and other, net	95		'	'	95	'	'	'
Purchases of treasury stock	-274		'	-274	'	'	'	'
Balance at Dec. 31, 2011	37,620		177	-4,502	7,286	35,142	-483	'
Increase (Decrease) in Stockholders' Equity	'		'	'	'	'	'	'
Net income	4,598		'	'	'	4,598	'	'
Other comprehensive income (loss), net of tax	-19	[1]	'	'	'	'	-19	'
Dividends on common stock	-1,750		'	'	'	-1,750	'	'
Issuance of common stock and other, net	156		1	'	155	'	'	'
Noncontrolling interest contributions	32		'	'	'	'	'	32	[2]
Purchases of treasury stock	-589		'	-589	'	'	'	'
Balance at Dec. 31, 2012	40,048		178	-5,091	7,441	37,990	-502	32
Increase (Decrease) in Stockholders' Equity	'		'	'	'	'	'	'
Net income	5,903		'	'	'	5,903	'	'
Other comprehensive income (loss), net of tax	199	[1]	'	'	'	'	199	'
Dividends on common stock	-2,062		'	'	'	-2,062	'	'
Issuance of common stock and other, net	74		'	'	74	'	'	'
Noncontrolling interest contributions	214		'	'	'	'	'	214	[2]
Purchases of treasury stock	-1,004		'	-1,004	'	'	'	'
Balance at Dec. 31, 2013	$43,372		$178	($6,095)	$7,515	$41,831	($303)	$246
[1]	There were no other comprehensive income (loss) items related to noncontrolling interests in 2013, 2012 and 2011.
[2]	Reflects contributions from the noncontrolling interest in a pipeline company.

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOW FROM OPERATING ACTIVITIES	'	'	'
Net income	$5,903	$4,598	$6,771
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Discontinued operations, net	19	37	-131
Depreciation, depletion and amortization of assets	5,347	4,511	3,591
Deferred income tax provision	1,187	1,128	1,436
Other noncash charges to income	299	195	190
Asset impairments and related items	621	1,751	'
Gain on sale of equity investments	-1,175	'	'
Undistributed earnings from equity investments	-3	-30	-33
Dry hole expenses	142	279	160
Changes in operating assets and liabilities:	'	'	'
(Increase) decrease in receivables	-755	472	-360
Decrease (increase) in inventories	87	-265	-50
Decrease in other current assets	60	127	95
Increase (decrease) in accounts payable and accrued liabilities	500	-1,086	657
Increase (decrease) in current domestic and foreign income taxes	369	1	-174
Other operating, net	382	-370	154
Operating cash flow from continuing operations	12,983	11,348	12,306
Operating cash flow from discontinued operations, net of taxes	-56	-36	-25
Net cash provided by operating activities	12,927	11,312	12,281
CASH FLOW FROM INVESTING ACTIVITIES	'	'	'
Capital expenditures	-9,037	-10,226	-7,518
Payments for purchases of assets and businesses	-643	-2,490	-4,909
Sales of equity investments and assets, net	1,619	4	50
Other, net	-132	57	-96
Investing cash flow from continuing operations	-8,193	-12,655	-12,473
Investing cash flow from discontinued operations	'	'	2,570
Net cash used by investing activities	-8,193	-12,655	-9,903
CASH FLOW FROM FINANCING ACTIVITIES	'	'	'
Payments of long-term debt	-690	'	-1,523
Proceeds from long-term debt	'	1,736	2,111
Proceeds from issuance of common stock	30	85	50
Purchases of treasury stock	-943	-583	-274
Contributions from (distributions to) noncontrolling interest	214	32	-121
Cash dividends paid	-1,553	-2,128	-1,436
Other, net	9	12	18
Net cash used by financing activities	-2,933	-846	-1,175
Increase (decrease) in cash and cash equivalents	1,801	-2,189	1,203
Cash and cash equivalents - beginning of year	1,592	3,781	2,578
Cash and cash equivalents - end of year	$3,393	$1,592	$3,781

SUMMARY_OF_SIGNIFICANT_ACCOUNT

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	12 Months Ended
	Dec. 31, 2013
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
	NOTE 1	SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
	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.  Occidental’s principal businesses consist of the oil and gas, chemical and midstream, marketing and other (midstream and marketing) segments.  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 midstream and marketing  segment  gathers, processes, transports, stores, purchases and markets oil, condensate, NGLs, natural gas, carbon dioxide (CO2) and power.  It also trades around its assets, including transportation and storage capacity, and trades oil, NGLs, gas and other commodities.  Additionally, the midstream and marketing segment invests in entities that conduct similar activities.
	PRINCIPLES OF CONSOLIDATION
	The consolidated financial statements have been prepared in conformity with United States generally accepted accounting principles (GAAP) and include the accounts of OPC, its subsidiaries and its undivided interests in oil and gas exploration and production ventures.  Occidental accounts for its share of oil and gas exploration and production ventures, in which it has a direct working interest, by reporting its proportionate share of assets, liabilities, revenues, costs and cash flows within the relevant lines on the balance sheets, income statements and cash flow statements.
	Certain financial statements, notes and supplementary data for prior years have been reclassified to conform to the 2013 presentation.
	INVESTMENTS IN UNCONSOLIDATED ENTITIES
	Occidental’s percentage interest in the underlying net assets of affiliates as to which it exercises significant influence without having a controlling interest (excluding oil and gas ventures in which Occidental holds an undivided interest) are accounted for under the equity method.  Occidental reviews equity-method investments for impairment whenever events or changes in circumstances indicate that an other-than-temporary decline in value may have occurred.  The amount of impairment, if any, is based on quoted market prices, when available, or other valuation techniques, including discounted cash flows.
	REVENUE RECOGNITION
	Revenue is recognized from oil and gas production when title has passed to the customer, which occurs when the product is shipped.  In international locations where oil is shipped by tanker, title passes when the tanker is loaded or product is received by the customer, depending on the shipping terms.  This process occasionally causes a difference between actual production in a reporting period and sales volumes that have been recognized as revenue.
	Revenue from chemical product sales is recognized when the product is shipped and title has passed to the customer.  Certain incentive programs may provide for payments or credits to be made to customers based on the volume of product purchased over a defined period.  Total customer incentive payments over a given period are estimated and recorded as a reduction to revenue ratably over the contract period.  Such estimates are evaluated and revised as warranted.
	Revenue from marketing and trading activities is recognized on net settled transactions upon completion of contract terms and, for physical deliveries, upon title transfer.  For unsettled transactions, contracts are recorded at fair value and changes in fair value are reflected in net sales.  Revenue from all marketing and trading activities is reported on a net basis.
	Occidental records revenue net of any taxes, such as sales taxes, that are assessed by governmental authorities on Occidental’s customers.
	RISKS AND UNCERTAINTIES
	The process of preparing consolidated financial statements in conformity with GAAP requires Occidental’s management to make informed estimates and judgments regarding certain types of financial statement balances and disclosures.  Such estimates primarily relate to unsettled transactions and events as of the date of the consolidated financial statements and judgments on expected outcomes as well as the materiality of transactions and balances.  Changes in facts and circumstances or discovery of new information relating to such transactions and events may result in revised estimates and judgments and actual results may differ from estimates upon settlement.  Management believes that these estimates and judgments provide a reasonable basis for the fair presentation of Occidental’s financial statements.
	Occidental establishes a valuation allowance against net operating losses and other deferred tax assets to the extent it believes the future benefit from these assets will not be realized in the statutory carryforward periods.  Realization of deferred tax assets, including any net operating loss carryforwards, is dependent upon Occidental generating sufficient future taxable income and reversal of temporary differences in jurisdictions where such assets originate.
	The accompanying consolidated financial statements include assets of approximately $13.7 billion as of December 31, 2013, and net sales of approximately $8.2 billion for the year ended December 31, 2013, relating to Occidental’s operations in countries outside North America.  Occidental operates some of its oil and gas business in countries that occasionally have experienced political instability, nationalizations, corruption, armed conflict, terrorism, insurgency, civil unrest, security problems, labor unrest, OPEC production restrictions, equipment import restrictions and sanctions, all of which increase Occidental’s risk of loss or delayed or restricted production or may result in other adverse consequences.  Occidental attempts to conduct its affairs so as to mitigate its exposure to such risks and would seek compensation in the event of nationalization.
	Because Occidental’s major products are commodities, significant changes in the prices of oil and gas and chemical products may have a significant impact on Occidental’s results of operations.
	Also, see “Property, Plant and Equipment” below.
	CASH AND CASH EQUIVALENTS
	Cash equivalents are short-term, highly liquid investments that are readily convertible to cash.  Cash equivalents were approximately $2.9 billion and $1.0 billion at December 31, 2013 and 2012, respectively.
	INVESTMENTS
	Available-for-sale securities are recorded at fair value with any unrealized gains or losses included in accumulated other comprehensive income/loss (AOCI).  Trading securities are recorded at fair value with unrealized and realized gains or losses included in net sales.
	INVENTORIES
	Materials and supplies are valued at weighted-average cost and are reviewed periodically for obsolescence.  Oil, NGL and natural gas inventories are valued at the lower of cost or market.
	For the chemical segment, Occidental’s finished goods inventories are valued at the lower of cost or market.  For most of its domestic inventories, other than materials and supplies, the chemical segment uses the last-in, first-out (LIFO) method as it better matches current costs and current revenue.  For other countries, Occidental uses the first-in, first-out method (if the costs of goods are specifically identifiable) or the average-cost method (if the costs of goods are not specifically identifiable).
	PROPERTY, PLANT AND EQUIPMENT
	Oil and Gas
	The carrying value of Occidental’s property, plant and equipment (PP&E) represents the cost incurred to acquire or develop the asset, including any asset retirement obligations and capitalized interest, net of accumulated depreciation, depletion and amortization (DD&A) and any impairment charges.  For assets acquired, PP&E cost is based on fair values at the acquisition date.  Asset retirement obligations and interest costs incurred in connection with qualifying capital expenditures are capitalized and amortized over the lives of the related assets.
	Occidental uses the successful efforts method to account for its oil and gas properties.  Under this method, Occidental capitalizes costs of acquiring properties, costs of drilling successful exploration wells and development costs.  The costs of exploratory wells are initially capitalized pending a determination of whether proved reserves have been found.  If proved reserves have been found, the costs of exploratory wells remain capitalized.  Otherwise, Occidental charges the costs of the related wells to expense.  In some cases, a determination of proved reserves cannot be made at the completion of drilling, requiring additional testing and evaluation of the wells.  Occidental generally expenses the costs of such exploratory wells if a determination of proved reserves has not been made within a 12-month period after drilling is complete.
	The following table summarizes the activity of capitalized exploratory well costs for continuing operations for the years ended December 31:
	In millions		2013			2012			2011
	Balance — Beginning of Year		$	124		$	189		$	77
	Additions to capitalized exploratory well costs pending the determination of proved reserves		337			400			333
	Reclassifications to property, plant and equipment based on the determination of proved reserves		(271		)	(389		)	(201		)
	Capitalized exploratory well costs charged to expense		(50		)	(76		)	(20		)
	Balance — End of Year		$	140		$	124		$	189
	Occidental expenses annual lease rentals, the costs of injectants used in production and geological, geophysical and seismic costs as incurred.
	Occidental determines depreciation and depletion of oil and gas producing properties by the unit-of-production method.  It amortizes acquisition costs over total proved reserves, and capitalized development and successful exploration costs over proved developed reserves.
	Proved oil and gas reserves are those quantities of oil and gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation.  Occidental has no proved oil and gas reserves for which the determination of economic producibility is subject to the completion of major additional capital expenditures.
	Additionally, Occidental performs impairment tests with respect to its proved properties when product prices decline other than temporarily, reserve estimates change significantly, other significant events occur or management’s plans change with respect to these properties in a manner that may impact Occidental’s ability to realize the recorded asset amounts.  Impairment tests incorporate a number of assumptions involving expectations of undiscounted future cash flows, which can change significantly over time.  These assumptions include estimates of future product prices, which Occidental bases on forward price curves and, when applicable, contractual prices, estimates of oil and gas reserves and estimates of future expected operating and development costs.  Any impairment loss would be calculated as the excess of the asset’s net book value over its estimated fair value.
	A portion of the carrying value of Occidental’s oil and gas properties is attributable to unproved properties.  At December 31, 2013, the net capitalized costs attributable to unproved properties were $3.6 billion.  The unproved amounts are not subject to DD&A until they are classified as proved properties.  As exploration and development work progresses, if reserves on these properties are proved, capitalized costs attributable to the properties become subject to DD&A.  If the exploration and development work were to be unsuccessful, or management decided not to pursue development of these properties as a result of lower commodity prices, higher development and operating costs, contractual conditions or other factors, the capitalized costs of the related properties would be expensed.  The timing of any writedowns of these unproved properties, if warranted, depends upon management’s plans, the nature, timing and extent of future exploration and development activities and their results.  Occidental believes its current plans and exploration and development efforts will allow it to realize its unproved property balance.
	Chemical
	Occidental’s chemical assets are depreciated using either the unit-of-production or the straight-line method, based upon the estimated useful lives of the facilities.  The estimated useful lives of Occidental’s chemical assets, which range from three years to 50 years, are also used for impairment tests.  The estimated useful lives for the chemical facilities are based on the assumption that Occidental will provide an appropriate level of annual expenditures to ensure productive capacity is sustained.  Such expenditures consist of ongoing routine repairs and maintenance, as well as planned major maintenance activities (PMMA).  Ongoing routine repairs and maintenance expenditures are expensed as incurred. PMMA costs are capitalized and amortized over the period until the next planned overhaul.  Additionally, Occidental incurs capital expenditures that extend the remaining useful lives of existing assets, increase their capacity or operating efficiency beyond the original specification or add value through modification for a different use.  These capital expenditures are not considered in the initial determination of the useful lives of these assets at the time they are placed into service.  The resulting revision, if any, of the asset’s estimated useful life is measured and accounted for prospectively.
	Without these continued expenditures, the useful lives of these assets could decrease significantly.  Other factors that could change the estimated useful lives of Occidental’s chemical assets include sustained higher or lower product prices, which are particularly affected by both domestic and foreign competition, demand, feedstock costs, energy prices, environmental regulations and technological changes.
	Occidental performs impairment tests on its chemical assets whenever events or changes in circumstances lead to a reduction in the estimated useful lives or estimated future cash flows that would indicate that the carrying amount may not be recoverable, or when management’s plans change with respect to those assets.  Any impairment loss would be calculated as the excess of the asset’s net book value over its estimated fair value.
	Midstream and Marketing
	Occidental’s midstream and marketing PP&E is depreciated over the estimated useful lives of the assets, using either the unit-of-production or straight-line method.
	Occidental performs impairment tests on its midstream and marketing assets whenever events or changes in circumstances lead to a reduction in the estimated useful lives or estimated future cash flows that would indicate that the carrying amount may not be recoverable, or when management’s plans change with respect to those assets.  Any impairment loss would be calculated as the excess of the asset’s net book value over its estimated fair value.
	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 reported at the end of each reporting period.
	Fair Values - Recurring
	Occidental primarily applies the market approach for recurring fair value measurements, maximizes its use of observable inputs and minimizes its use of unobservable inputs.  Occidental utilizes the mid-point between bid and ask prices for valuing the majority of its assets and liabilities measured and reported at fair value.  In addition to using market data, Occidental makes assumptions in valuing its assets and liabilities, including assumptions about the risks inherent in the inputs to the valuation technique.  For assets and liabilities carried at fair value, Occidental measures fair value using the following methods:
	Ø              Commodity derivatives – Occidental values exchange-cleared commodity derivatives using closing prices provided by the exchange as of the balance sheet date.  These derivatives are classified as Level 1.  Over-the-Counter (OTC) bilateral financial commodity contracts, foreign exchange contracts, options and physical commodity forward purchase and sale contracts are generally valued using quotations provided by brokers or industry-standard models that consider various inputs, including quoted forward prices for commodities, time value, volatility factors, credit risk and current market and contractual prices for the underlying instruments, as well as other relevant economic measures.  Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable prices at which transactions are executed in the marketplace.  Occidental classifies these measurements as Level 2.
	Ø              Embedded commodity derivatives – Occidental values embedded commodity derivatives based on a market approach that considers various assumptions, including quoted forward commodity prices and market yield curves.  The assumptions used include inputs that are observable and unobservable in the marketplace, and the fair value is designated as Level 3 within the valuation hierarchy.
	Occidental generally uses an income approach to measure fair value when there is not a market-observable price for an identical or similar asset or liability.  This approach utilizes management’s judgments regarding expectations of projected cash flows, and discounts those cash flows using a risk-adjusted discount rate.
	ACCRUED LIABILITIES—CURRENT
	Accrued liabilities include accrued payroll, commissions and related expenses of $459 million and $385 million at December 31, 2013 and 2012, respectively.
	ENVIRONMENTAL LIABILITIES AND EXPENDITURES
	Environmental expenditures that relate to current operations are expensed or capitalized as appropriate.  Occidental records environmental reserves and related charges and expenses for estimated remediation costs that relate to existing conditions from past operations when environmental remediation efforts are probable and the costs can be reasonably estimated.  In determining the reserves and the range of reasonably possible additional losses, Occidental refers to currently available information, including relevant past experience, remedial objectives, available technologies, applicable laws and regulations and cost-sharing arrangements.  Occidental bases environmental reserves on management’s estimate of the most likely cost to be incurred, using the most cost-effective technology reasonably expected to achieve the remedial objective.  Occidental periodically reviews reserves and adjusts them as new information becomes available.  Occidental records environmental reserves on a discounted basis when it deems the aggregate amount and timing of cash payments to be reliably determinable at the time the reserves are established.  The reserve methodology with respect to discounting for a specific site is not modified once it is established.  The amount of discounted environmental reserves is insignificant.  Occidental generally records reimbursements or recoveries of environmental remediation costs in income when received, or when receipt of recovery is highly probable.  As of December 31, 2013, 2012 and 2011, Occidental did not have any accruals for reimbursements or recoveries.
	Many factors could affect Occidental’s future remediation costs and result in adjustments to its environmental reserves and range of reasonably possible additional losses.  The most significant are: (1) cost estimates for remedial activities may be inaccurate; (2) the length of time, type or amount of remediation necessary to achieve the remedial objective may change due to factors such as site conditions, the ability to identify and control contaminant sources or the discovery of additional contamination; (3) a regulatory agency may ultimately reject or modify Occidental’s proposed remedial plan; (4) improved or alternative remediation technologies may change remediation costs; (5) laws and regulations may change remediation requirements or affect cost sharing or allocation of liability; and (6) changes in allocation or cost-sharing arrangements may occur.
	Certain sites involve multiple parties with various cost-sharing arrangements, which fall into the following three categories:  (1) environmental proceedings that result in a negotiated or prescribed allocation of remediation costs among Occidental and other alleged potentially responsible parties; (2) oil and gas ventures in which each participant pays its proportionate share of remediation costs reflecting its working interest; or (3) contractual arrangements, typically relating to purchases and sales of properties, in which the parties to the transaction agree to methods of allocating remediation costs.  In these circumstances, Occidental evaluates the financial viability of the other parties with whom it is alleged to be jointly liable, the degree of their commitment to participate and the consequences to Occidental of their failure to participate when estimating Occidental’s ultimate share of liability.  Occidental records reserves at its expected net cost of remedial activities and, based on these factors, believes that it will not be required to assume a share of liability of such other potentially responsible parties in an amount materially above amounts reserved.
	In addition to the costs of investigations and cleanup measures, which often take in excess of 10 years at Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA) National Priorities List (NPL) sites, Occidental’s reserves include management’s estimates of the costs to operate and maintain remedial systems.  If remedial systems are modified over time in response to significant changes in site-specific data, laws, regulations, technologies or engineering estimates, Occidental reviews and adjusts its reserves accordingly.
ASSET RETIREMENT OBLIGATIONS
Occidental recognizes the fair value of asset retirement obligations in the period in which a determination is made that a legal obligation exists to dismantle an asset and reclaim or remediate the property at the end of its useful life and the cost of the obligation can be reasonably estimated.  The liability amounts are based on future retirement cost estimates and incorporate many assumptions such as time to abandonment, technological changes, future inflation rates and the risk-adjusted discount rate.  When the liability is initially recorded, Occidental capitalizes the cost by increasing the related PP&E balances.  If the estimated future cost of the asset retirement obligation changes, Occidental records an adjustment to both the asset retirement obligation and PP&E.  Over time, the liability is increased and expense is recognized for accretion, and the capitalized cost is depreciated over the useful life of the asset.
At a certain number of its facilities, Occidental has identified conditional asset retirement obligations that are related mainly to plant decommissioning.  Occidental does not know or cannot estimate when it may settle these obligations.  Therefore, Occidental cannot reasonably estimate the fair value of these liabilities.  Occidental will recognize these conditional asset retirement obligations in the periods in which sufficient information becomes available to reasonably estimate their fair values.
The following table summarizes the activity of the asset retirement obligation, of which $1,283 million and $1,212 million is included in deferred credits and other liabilities - other, with the remaining current portion in accrued liabilities at December 31, 2013 and 2012, respectively.
For the years ended December 31, (in millions)		2013			2012
Beginning balance		$	1,266		$	1,089
Liabilities incurred – capitalized to PP&E		101			86
Liabilities settled and paid		(72		)	(58		)
Accretion expense		68			61
Acquisitions, dispositions and other – changes in PP&E		(10		)	50
Revisions to estimated cash flows – changes in PP&E		(21		)	38
Ending balance		$	1,332		$	1,266
DERIVATIVE INSTRUMENTS
Derivatives are carried at fair value and on a net basis when a legal right of offset exists with the same counterparty.  Occidental applies hedge accounting when transactions meet specified criteria for cash-flow hedge treatment and management elects and documents such treatment.  Otherwise, any fair value gains or losses are recognized in earnings in the current period.  For cash-flow hedges, the gain or loss on the effective portion of the derivative is reported as a component of other comprehensive income (OCI) with an offsetting adjustment to the basis of the item being hedged.  Realized gains or losses from cash-flow hedges, and any ineffective portion, are recorded as a component of net sales in the consolidated statements of income.  Ineffectiveness is primarily created by a lack of correlation between the hedged item and the hedging instrument due to location, quality, grade or changes in the expected quantity of the hedged item.  Gains and losses from derivative instruments are reported net in the consolidated statements of income. There were no fair value hedges as of and during the years ended December 31, 2013, 2012 and 2011.
A hedge is regarded as highly effective such that it qualifies for hedge accounting if, at inception and throughout its life, it is expected that changes in the fair value or cash flows of the hedged item will be offset by 80 to 125 percent of the changes in the fair value or cash flows, respectively, of the hedging instrument.  In the case of hedging a forecast transaction, the transaction must be probable and must present an exposure to variations in cash flows that could ultimately affect reported net income or loss.  Occidental discontinues hedge accounting when it determines that a derivative has ceased to be highly effective as a hedge; when the hedged item matures or is sold or repaid; or when a forecast transaction is no longer deemed probable.
STOCK-BASED INCENTIVE PLANS
Occidental has established several stockholder-approved stock-based incentive plans for certain employees and directors (Plans) that are more fully described in Note 12.  A summary of Occidental’s accounting policy for awards issued under the Plans is as follows.
For cash- and stock-settled restricted stock units or incentive award shares (RSUs), compensation value is initially measured on the grant date using the quoted market price of Occidental’s common stock.  For cash- and stock-settled total shareholder return incentives (TSRIs), compensation value is initially measured on the grant date using estimated payout levels derived from the Monte Carlo valuation model.  Compensation expense for RSUs and TSRIs is recognized on a straight-line basis over the requisite service periods, which is generally over the awards’ respective vesting or performance periods.  Compensation expense for the cash-settled portion of the TSRI awards and related dividends is adjusted quarterly for any changes in stock price and the number of share equivalents expected to be paid based on the relevant performance criteria.  For RSUs, compensation expense for the cash-settled portion of the awards is adjusted for changes in the value of the underlying stock on a quarterly basis.  All such performance or stock-price-related changes are recognized in periodic compensation expense.  The stock-settled portion of these awards is expensed using the initially measured compensation value.
EARNINGS PER SHARE
Occidental’s instruments containing rights to nonforfeitable dividends granted in stock-based awards are considered participating securities prior to vesting and, therefore, have been deducted from earnings in computing basic and diluted EPS under the two-class method.
Basic EPS was computed by dividing net income attributable to common stock, net of income allocated to participating securities, by the weighted-average number of common shares outstanding during each period, net of treasury shares and including vested but unissued shares and share units. The computation of diluted EPS reflects the additional dilutive effect of stock options and unvested stock awards.
RETIREMENT AND POSTRETIREMENT BENEFIT PLANS
Occidental recognizes the overfunded or underfunded amounts of its defined benefit pension and postretirement plans in its financial statements using a December 31 measurement date.
Occidental determines its defined benefit pension and postretirement benefit plan obligations based on various assumptions and discount rates.  The discount rate assumptions used are meant to reflect the interest rate at which the obligations could effectively be settled on the measurement date.  Occidental estimates the rate of return on assets with regard to current market factors but within the context of historical returns.  Occidental funds and expenses negotiated pension increases for domestic union employees over the terms of the applicable collective bargaining agreements.
Pension and any postretirement plan assets are measured at fair value.  Common stock, preferred stock, publicly registered mutual funds, U.S. government securities and corporate bonds are valued using quoted market prices in active markets when available.  When quoted market prices are not available, these investments are valued using pricing models with observable inputs from both active and non-active markets.  Common and collective trusts are valued at the fund units’ net asset value (NAV) provided by the issuer, which represents the quoted price in a non-active market.  Short-term investment funds are valued at the fund units’ NAV provided by the issuer.
SUPPLEMENTAL CASH FLOW INFORMATION
Occidental paid United States federal, state and foreign income taxes for continuing operations of approximately $1.8 billion, $2.4 billion and $2.9 billion during the years ended December 31, 2013, 2012 and 2011, respectively.  Occidental also paid production, property and other taxes of approximately $792 million, $694 million and $635 million during the years ended December 31, 2013, 2012 and 2011, respectively, substantially all of which was in the United States.  Interest paid totaled approximately $238 million, $190 million and $315 million for the years 2013, 2012 and 2011, respectively.  The 2011 interest paid included $154 million of debt extinguishment premiums.
FOREIGN CURRENCY TRANSACTIONS
The functional currency applicable to all of Occidental’s foreign oil and gas operations is the United States dollar since cash flows are denominated principally in United States dollars.  In Occidental’s other operations, Occidental’s use of non-United States dollar functional currencies was not material for all years presented.  The effect of exchange rates on transactions in foreign currencies is included in periodic income.  Occidental reports the exchange rate differences arising from translating foreign-currency-denominated balance sheet accounts to the United States dollar as of the reporting date in other comprehensive income.  Exchange-rate gains and losses for continuing operations were not material for all years presented.

ACQUISITIONS_DISPOSITIONS_AND_

ACQUISITIONS, DISPOSITIONS AND OTHER TRANSACTIONS	12 Months Ended
	Dec. 31, 2013
ACQUISITIONS, DISPOSITIONS AND OTHER TRANSACTIONS	'
ACQUISITIONS, DISPOSITIONS AND OTHER TRANSACTIONS	'
	NOTE 2	ACQUISITIONS, DISPOSITIONS AND OTHER TRANSACTIONS
	SUBSEQUENT EVENTS
	In February 2014, Occidental entered into an agreement to sell its Hugoton Field operations in Kansas, Oklahoma and Colorado for pre-tax proceeds of $1.4 billion.  Occidental’s average net production from the Hugoton Field properties in 2013 was approximately 110 million cubic feet equivalent of natural gas per day, of which approximately 30 percent was oil. Occidental anticipates the transaction will be completed in the second quarter of 2014 and expects to report a gain on the sale.  In February 2014, the Board of Directors authorized initiation of efforts to separate its California assets into an independent and separately traded company.
	2013
	In October 2013, the Board of Directors authorized the pursuit of the sale of a minority interest in the Middle East/North Africa operations, the strategic alternatives for select assets, including oil and gas interests in the Williston Basin, Hugoton Field, Piceance Basin and other Rocky Mountain assets and the sale of a portion of Occidental’s investment in the Plains All-American Pipeline, L.P. (Plains Pipeline).  Occidental sold a portion of its equity interest in Plains Pipeline for approximately $1.4 billion, resulting in a pre-tax gain of approximately $1.0 billion.
	During the year ended December 31, 2013, Occidental paid approximately $0.5 billion to acquire certain domestic oil and gas properties.
	In October 2013, Occidental and Mexichem, S.A.B. de C.V. (Mexichem) formed Ingleside Ethylene, LLC (Ingleside) to build and operate an ethane steam cracking unit capable of producing 1.2 billion pounds of ethylene per year (Cracker), which is expected to begin operating in 2017.  With the ethylene produced from the Cracker, Occidental will produce vinyl chloride monomer (VCM), of which Mexichem has contracted to purchase a substantial majority.  As of December 31, 2013, Occidental had invested approximately $23 million in Ingleside for its portion of construction costs.
	In May 2013, Occidental sold its investment in Carbocloro, a Brazilian chemical facility.  Occidental received net proceeds of approximately $270 million and recorded a pre-tax gain of $131 million.
	Dr. Ray Irani submitted his resignation as a director, effective as of May 15, 2013, and ceased serving as an executive of Occidental.  In addition, certain other employees and several consulting arrangements were terminated during the second quarter.  As a result of these developments and actions, Occidental recorded a $55 million pre-tax charge in the second quarter for the estimated costs of Dr. Irani’s employment and post-employment benefits, and the termination of other employees and consulting arrangements.  Dr. Irani and Occidental have settled all matters relating to his separation.  The cost of the settlement was consistent with the estimated charge recorded in the second quarter.  Dr. Irani’s employment terminated in December 2013.
	2012
	During the year ended December 31, 2012, Occidental paid approximately $2.3 billion for domestic oil and gas properties in the Permian Basin, Williston Basin, South Texas and California.
	In November 2012, Occidental and Magellan Midstream Partners, L.P. (Magellan) formed BridgeTex Pipeline Company, LLC (BridgeTex) and are proceeding with construction of the BridgeTex Pipeline, which is expected to begin service in mid-2014.  The approximately 450-mile-long pipeline will be capable of transporting approximately 300,000 barrels per day of crude oil between the Permian region (Colorado City, Texas) and Gulf Coast refinery markets.  The BridgeTex Pipeline project also includes construction of approximately 2.6 million barrels of oil storage in aggregate.
	Occidental owns a 50 percent interest in BridgeTex and the remaining 50 percent interest is owned by Magellan, which will be the operator.  BridgeTex was determined to be a variable interest entity because of the difference between Occidental’s economic interests and its decision-making rights. Occidental is the primary beneficiary and consequently consolidates BridgeTex.   This investment is not material to Occidental’s financial statements.  At December 31, 2013 and 2012, the BridgeTex assets and liabilities mainly comprised cash and cash equivalents and PP&E.  As of December 31, 2013, BridgeTex’s total cash, PP&E and non-controlling amounts (reflecting Magellan’s interests) were $82 million, $420 million and $212 million, respectively, and as of December 31, 2012, these amounts were $50 million, $9 million and $32 million, respectively.  BridgeTex’s assets cannot be used for the obligations of, nor do BridgeTex’s creditors have recourse to, OPC or its other subsidiaries.
	2011
	During the year ended December 31, 2011, Occidental acquired producing properties in South Texas for approximately $1.8 billion.  Occidental also acquired approximately $2.6 billion of other domestic oil and gas assets, which included properties in California, as well as the Permian and Williston basins.
	In the first quarter of 2011, Occidental completed the sale of its Argentine oil and gas operations.
	Internationally, in the first quarter of 2011, Occidental acquired a 40-percent participating interest in the Al Hosn gas  project in Abu Dhabi, joining with the Abu Dhabi National Oil Company in a 30-year joint venture agreement.  The project is operated by Abu Dhabi Gas Development Company Limited.  In May 2011, Occidental paid approximately $500 million for its share of pre-acquisition development expenditures.
	In early 2011, Occidental ceased exploration activity and its participation in production operations in Libya due to civil unrest in the country and United States sanctions.  As a result, Occidental wrote off the entire amount of the capitalized and suspended exploration costs incurred to date, including lease acquisition costs, of approximately $35 million in the first quarter of 2011.  The United States government lifted its sanctions in September 2011 and Occidental resumed its participation in the producing operations at that time.

ACCOUNTING_AND_DISCLOSURE_CHAN

ACCOUNTING AND DISCLOSURE CHANGES	12 Months Ended
	Dec. 31, 2013
ACCOUNTING AND DISCLOSURE CHANGES	'
ACCOUNTING AND DISCLOSURE CHANGES	'
	NOTE 3	ACCOUNTING AND DISCLOSURE CHANGES
	RECENTLY ADOPTED ACCOUNTING AND DISCLOSURE CHANGES
	Offsetting Assets and Liabilities
	Beginning in the quarter ended March 31, 2013, Occidental adopted new disclosure requirements relating to its derivatives in accordance with rules issued by the Financial Accounting Standards Board (FASB) in December 2011 and January 2013.  These new rules require tabular disclosures of the outstanding derivatives’ gross and net fair values, now including those derivatives that are subject to a master netting or similar arrangement and qualify for net presentation, whether or not offset in the consolidated balance sheet.
	Reclassification from Accumulated Other Comprehensive Income
	Beginning in the quarter ended March 31, 2013, Occidental adopted new disclosure requirements for reporting amounts reclassified out of each component of accumulated other comprehensive income into the income statement in accordance with rules issued by the FASB in February 2013.
	These new disclosures were not material to Occidental’s financial statements.

INVENTORIES

INVENTORIES	12 Months Ended
	Dec. 31, 2013
INVENTORIES	'
INVENTORIES	'
	NOTE 4	INVENTORIES
	Net carrying values of inventories valued under the LIFO method were approximately $205 million and $185 million at December 31, 2013 and 2012, respectively.  Inventories consisted of the following:
	Balance at December 31, (in millions)		2013			2012
	Raw materials		$	74		$	70
	Materials and supplies		628			612
	Finished goods		589			763
			1,291			1,445
	LIFO reserve		(91		)	(101		)
	Total		$	1,200		$	1,344

LONGTERM_DEBT

LONG-TERM DEBT	12 Months Ended
	Dec. 31, 2013
LONG-TERM DEBT	'
LONG-TERM DEBT	'
	NOTE 5	LONG-TERM DEBT
	Long-term debt consisted of the following:
	Balance at December 31, (in millions)		2013			2012
	4.10% senior notes due 2021		$	1,249		$	1,300
	1.75% senior notes due 2017		1,250			1,250
	2.70% senior notes due 2023		1,224			1,250
	3.125% senior notes due 2022		887			900
	4.125% senior notes due 2016		750			750
	2.5% senior notes due 2016		700			700
	1.45% senior notes due 2013		—			600
	1.50% senior notes due 2018		500			500
	8.45% senior notes due 2029		116			116
	9.25% senior debentures due 2019		116			116
	7.2% senior debentures due 2028		82			82
	Variable rate bonds due 2030 (0.04% and 0.13% as of December 31, 2013 and 2012, respectively)		68			68
	8.75% medium-term notes due 2023		22			22
			6,964			7,654
	Less:
	Unamortized discount, net		(25		)	(31		)
	Current maturities		—			(600		)
	Total		$	6,939		$	7,023
	Occidental has a bank credit facility (Credit Facility) with a $2.0 billion commitment expiring in 2016.  No amounts have been drawn under this Credit Facility.  Up to $1.0 billion of the Credit Facility is available in the form of letters of credit.  Borrowings under the Credit Facility bear interest at various benchmark rates, including LIBOR, plus a margin based on Occidental’s senior debt ratings.  Additionally, Occidental paid average annual facility fees of 0.08 percent in 2013 on the total commitment amounts of the Credit Facility.
	The Credit Facility provides for the termination of loan commitments and requires immediate repayment of any outstanding amounts if certain events of default occur.  The Credit Facility and other debt agreements do 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.
	As of December 31, 2013, under the most restrictive covenants of its financing agreements, Occidental had substantial capacity for additional unsecured borrowings, the payment of cash dividends and other distributions on, or acquisitions of, Occidental stock.
	In December 2013, all $600 million of the outstanding 1.45-percent senior notes due 2013 matured.  In addition, Occidental repurchased approximately $90 million of various senior notes due in 2021 and later.
	In June 2012, Occidental issued $1.75 billion of debt which comprised $1.25 billion of 2.70-percent senior unsecured notes due 2023 and $500 million of 1.50-percent senior unsecured notes due 2018.  Occidental received net proceeds of approximately $1.74 billion.  Interest on the notes will be payable semi-annually in arrears in February and August for each series of notes.
	In August 2011, Occidental issued $2.15 billion of debt, which comprised $1.25 billion of 1.75-percent senior unsecured notes due 2017 and $900 million of 3.125-percent senior unsecured notes due 2022.  Occidental received net proceeds of approximately $2.1 billion.  Interest on the notes is payable semi-annually in arrears in February and August for each series of notes.
	In March 2011, Occidental redeemed all $1.0 billion of its outstanding 7-percent senior notes due 2013 and all $368 million of its outstanding 6.75-percent senior notes due 2012.  Occidental recorded a $163-million pre-tax charge related to this redemption in the first quarter of 2011.
	Occidental has provided guarantees on Dolphin Energy’s debt, which are limited to certain political and other events.  At December 31, 2013 and 2012, Occidental’s total guarantees were not material and a substantial majority of the amounts consisted of limited recourse guarantees on approximately $354 million and $370 million, respectively, of Dolphin’s debt.  The fair value of the guarantees was immaterial.
	At December 31, 2013, principal payments on long-term debt aggregated approximately $7.0 billion, of which none is due in 2014 and 2015, $1.5 billion is due in 2016, $1.2 billion is due in 2017, $0.5 billion is due in 2018 and $3.8 billion is due in 2019 and thereafter.
	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 values of Occidental’s debt at December 31, 2013 and 2012, substantially all of which were classified as Level 1, were approximately $7.1 billion and $8.2 billion, respectively, compared to carrying values of approximately $7.0 billion and $7.6 billion, respectively.  Occidental’s exposure to changes in interest rates relates primarily to its variable-rate, long-term debt obligations, and is not material.  As of December 31, 2013 and 2012, variable-rate debt constituted approximately one percent of Occidental’s total debt.

LEASE_COMMITMENTS

LEASE COMMITMENTS	12 Months Ended
	Dec. 31, 2013
LEASE COMMITMENTS	'
LEASE COMMITMENTS	'
	NOTE 6	LEASE COMMITMENTS
	Operating lease agreements include leases for transportation equipment, power plants, machinery, terminals, storage facilities, land and office space.  Occidental’s operating lease agreements frequently include renewal or purchase options and require the Company to pay for utilities, taxes, insurance and maintenance expenses.  At December 31, 2013, future net minimum lease payments for noncancelable operating leases (excluding oil and gas and other mineral leases, utilities, taxes, insurance and maintenance expense) were the following:
	In millions		Amount (a)
	2014		$	141
	2015		122
	2016		97
	2017		89
	2018		128
	Thereafter		589
	Total minimum lease payments		$	1,166
	(a)   These amounts are net of sublease rentals of $3 million, which are to be received in 2014.
	Rental expense for operating leases, net of sublease rental income for continuing operations, was $204 million in 2013, $176 million in 2012 and $179 million in 2011.  Rental expense was net of sublease income of $3 million in 2013 and $4 million each in 2012 and 2011.

DERIVATIVES

DERIVATIVES	12 Months Ended
	Dec. 31, 2013
DERIVATIVES	'
DERIVATIVES	'
	NOTE 7	DERIVATIVES
	Objective & Strategy
	Occidental uses a variety of derivative instruments, including cash-flow hedges and derivative instruments not designated as hedging instruments, to obtain the average prices for the relevant production month and to improve realized prices for oil and gas.  Occidental only occasionally hedges its oil and gas production, and, when it does so, the volumes are usually insignificant.  Additionally, Occidental’s Phibro trading unit engages in trading activities using derivatives for the purpose of generating profits mainly from market price changes of commodities.
	Refer to Note 1 for Occidental’s accounting policy on derivatives.
	Cash-Flow Hedges
	Occidental entered into financial swap agreements in November 2012 for the sale of a portion of its natural gas production in California.  These swap agreements hedge 50 million cubic feet of natural gas per day beginning in January 2013 through March 2014 and qualify as cash-flow hedges.  The weighted-average strike price of these swaps is $4.30.
	Through March 31, 2012, Occidental held financial swap agreements related to the sale of 50 million cubic feet per day of its existing natural gas production from the Rocky Mountain region of the United States that qualified as cash-flow hedges  at a weighted-average strike price of $6.07.
	Through December 31, 2011, Occidental held a series of collar agreements for 12,000 barrels of oil per day of its domestic production that qualified as cash-flow hedges at a weighted-average strike price that ranged from $32.92 to $46.35.
	Occidental’s marketing and trading operations store natural gas purchased from third parties at Occidental’s North American leased storage facilities.  Derivative instruments are used to fix margins on the future sales of the stored volumes through March 31, 2014.  As of December 31, 2013 and 2012, Occidental had approximately 11 billion cubic feet and 20 billion cubic feet of natural gas held in storage, respectively.  As of December 31, 2013 and 2012, Occidental had cash-flow hedges for the forecast sale, to be settled by physical delivery, of approximately 13 billion cubic feet and 20 billion cubic feet of this stored natural gas, respectively.
	The following table presents the after-tax gains and losses recognized in, and reclassified to income from, AOCI, for derivative instruments classified as cash-flow hedges for the years ended December 31, 2013 and 2012 (in millions):
			After-tax
			2013				2012
	Beginning Balance — AOCI		$	(7	)		$	1
	Unrealized (losses) gains recognized in AOCI		(3		)		16
	Gains reclassified to income		(4		)		(24		)
	Ending Balance — AOCI		$	(14	)		$	(7	)
	Occidental expects to reclassify an insignificant amount, based on the valuation as of December 31, 2013, of net after-tax derivative losses from AOCI into income during the next 12 months.  The gains and losses reclassified to income were recognized in net sales, and the amount of the ineffective portion of cash-flow hedges was immaterial for the years ended December 31, 2013 and 2012.
	Derivatives Not Designated as Hedging Instruments
	The following table summarizes Occidental’s net volumes of outstanding commodity derivatives contracts not designated as hedging instruments, including both financial and physical derivative contracts as of December 31, 2013 and 2012:
			Net Outstanding Position
			Long / (Short)
	Commodity		2013			2012
	Oil (million barrels)		(22	)		(4	)
	Natural gas (billion cubic feet)		(10	)		(170	)
	Precious metals (million troy ounces)		1			1
	The volumes in the table above exclude contracts tied to index prices, for which the fair value, if any, is minimal at any point in time.  These contracts do not expose Occidental to price risk because the contract prices fluctuate with index prices.
	In addition, Occidental typically has certain other commodity trading contracts, such as agricultural products, power and other metals, as well as foreign exchange contracts.  These contracts were not material to Occidental as of December 31, 2013 and 2012.
	Occidental fulfills its short positions through its own production or by third-party purchase contracts.  Subsequent to December 31, 2013, Occidental entered into purchase contracts for a substantial portion of the outstanding positions at year-end and has sufficient production capacity and the ability to enter into additional purchase contracts to satisfy the remaining positions.
	Approximately $11 million and $49 million of net gains from derivatives not designated as hedging instruments were recognized in net sales for the years ended December 31, 2013 and 2012, respectively.
	Fair Value of Derivatives
	The following table presents the gross and net fair values of Occidental’s outstanding derivatives as of December 31, 2013 and 2012 (in millions):
	December 31, 2013		Asset Derivatives Balance Sheet Location		Fair				Liability Derivatives	Fair
					Value				Balance Sheet Location	Value
	Cash-flow hedges (a)
	Commodity contracts		Other current assets		$	—			Accrued liabilities	$	4
			Long-term receivables and other assets, net		—				Deferred credits and other liabilities	—
					$	—				$	4
	Derivatives not designated as hedging instruments (a)
	Commodity contracts		Other current assets		$	367			Accrued liabilities	$	407
			Long-term receivables and other assets, net		13				Deferred credits and other liabilities	11
					380					418
	Total gross fair value				380					422
	Less: counterparty netting and cash collateral (b) (d)				(329		)			(364		)
	Total net fair value of derivatives				$	51				$	58
	December 31, 2012		Asset Derivatives		Fair				Liability Derivatives	Fair
			Balance Sheet Location		Value				Balance Sheet Location	Value
	Cash-flow hedges (a)
	Commodity contracts		Other current assets		$	11			Accrued liabilities	$	1
			Long-term receivables and other assets, net		—				Deferred credits and other liabilities	1
					$	11				$	2
	Derivatives not designated as hedging instruments (a)
	Commodity contracts		Other current assets		$	386			Accrued liabilities	$	479
			Long-term receivables and other assets, net		22				Deferred credits and other liabilities	16
					408					495
	Total gross fair value				419					497
	Less: counterparty netting and cash collateral (c) (d)				(301		)			(371		)
	Total net fair value of derivatives				$	118				$	126
	(a)   Fair values are presented at gross amounts, including when the derivatives are subject to master netting arrangements and presented on a net basis in the consolidated balance sheets.
	(b)   As of December 31, 2013, collateral received of $11 million has been netted against derivative assets and collateral paid of $46 million has been netted against derivative liabilities.
	(c)   As of December 31, 2012, collateral received of $25 million has been netted against derivative assets and collateral paid of $95 million has been netted against derivative liabilities.
	(d)   Select clearinghouses and brokers require Occidental to post an initial margin deposit.  Collateral, mainly for initial margin, of $103 million and $116 million deposited by Occidental has not been reflected in these derivative fair value tables.  This collateral is included in other current assets in the consolidated balance sheets as of December 31, 2013 and 2012, respectively.
	See Note 15 for fair value measurement disclosures on derivatives.
	Credit Risk
A substantial portion of Occidental’s derivative transaction volume is executed through exchange-traded contracts, which are subject to minimal credit risk as a significant portion of these transactions is settled on a daily margin basis with select clearinghouses and brokers.  Occidental executes the rest of its derivative transactions in the OTC market.  Occidental is subject to counterparty credit risk to the extent the counterparty to the derivatives is unable to meet its settlement commitments.  Occidental manages this credit risk by selecting counterparties that it believes to be financially strong, by spreading the credit risk among many such counterparties, by entering into master netting arrangements with the counterparties and by requiring collateral, as appropriate.  Occidental actively monitors the creditworthiness of each counterparty and records valuation adjustments to reflect counterparty risk, if necessary.
Certain of Occidental’s OTC 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 would need to post.  As of December 31, 2013 and 2012, Occidental had a net liability of $8 million and $34 million, respectively, which are net of collateral posted of $23 million and $64 million, respectively.  Occidental believes that if it had received a one-notch reduction in its credit ratings, it would not have resulted in a material change in its collateral-posting requirements as of December 31, 2013 and 2012.
Foreign Currency Risk
Occidental’s foreign operations have limited currency risk.  Occidental manages its exposure primarily by balancing monetary assets and liabilities and limiting cash positions in foreign currencies to levels necessary for operating purposes.  A vast majority of international oil sales are denominated in United States dollars.  Additionally, all of Occidental’s consolidated foreign oil and gas subsidiaries have the United States dollar as the functional currency.  As of December 31, 2013, the fair value of foreign currency derivatives used in the trading operations was immaterial.  The effect of exchange rates on transactions in foreign currencies is included in periodic income.

ENVIRONMENTAL_LIABILITIES_AND_

ENVIRONMENTAL LIABILITIES AND EXPENDITURES	12 Months Ended
	Dec. 31, 2013
ENVIRONMENTAL LIABILITIES AND EXPENDITURES	'
ENVIRONMENTAL LIABILITIES AND EXPENDITURES	'
	NOTE 8	ENVIRONMENTAL LIABILITIES AND EXPENDITURES
	Occidental’s operations are subject to stringent federal, state, local and foreign laws and regulations related to improving or maintaining environmental quality.
	ENVIRONMENTAL REMEDIATION
	The laws that require or address environmental remediation, including CERCLA and similar federal, state, local and foreign laws, may apply retroactively and regardless of fault, the legality of the original activities or the current ownership or control of sites.  OPC 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 December 31, 2013, Occidental participated in or monitored remedial activities or proceedings at 157 sites.  The following table presents Occidental’s environmental remediation reserves as of December 31, 2013, 2012 and 2011, the current portion of which is included in accrued liabilities ($78 million in 2013, $80 million in 2012 and $79 million in 2011) and the remainder in deferred credits and other liabilities — other ($252 million in 2013, $264 million in 2012 and $281 million in 2011).  The reserves are grouped as environmental remediation sites listed or proposed for listing by the U.S. Environmental Protection Agency 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.
	$ amounts in millions		2013					2012				2011
			Number of Sites		Reserve Balance			Number of Sites		Reserve Balance		Number of Sites	Reserve Balance
	NPL sites		31		$	25		35		$	54	36	$	63
	Third-party sites		74		83			75		84		73	88
	Occidental-operated sites		20		118			22		123		22	120
	Closed or non-operated Occidental sites		32		104			29		83		29	89
	Total		157		$	330		161		$	344	160	$	360
	As of December 31, 2013, Occidental’s environmental reserves exceeded $10 million each at 10 of the 157 sites described above, and 108 of the sites had reserves from $0 to $1 million each.
	As of December 31, 2013, two sites — a landfill in western New York owned by Occidental and a former facility in New York — accounted for 60 percent of its reserves associated with NPL sites.  In connection with a 1986 acquisition, Maxus Energy Corporation has retained the liability and is indemnifying Occidental for 14 of the remaining NPL sites.
	As of December 31, 2013, Maxus has also retained the liability and is indemnifying Occidental for 8 of the 74 third-party sites.  Three of the remaining 66 third-party sites — a former copper mining and smelting operation in Tennessee, a containment and removal project in Tennessee and an active refinery in Louisiana where Occidental reimburses the current owner for certain remediation activities — accounted for 52 percent of Occidental’s reserves associated with these sites.
	Four sites — chemical plants in Kansas, Louisiana and New York and a group of oil and gas properties in the southwestern United States — accounted for 61 percent of the reserves associated with the Occidental-operated sites.
	Four other sites — a landfill in western New York, former chemical plants in Tennessee and Delaware and a closed coal mine in Pennsylvania — accounted for 64 percent of the reserves associated with closed or non-operated Occidental sites.
	Environmental reserves vary over time depending on factors such as acquisitions or dispositions, identification of additional sites and remedy selection and implementation.  The following table presents environmental reserve activity for the past three years:
	In millions		2013			2012			2011
	Balance — Beginning of Year		$	344		$	360		$	366
	Remediation expenses and interest accretion		60			56			53
	Changes from acquisitions/dispositions		—			—			14
	Payments		(74		)	(72		)	(73		)
	Balance — End of Year		$	330		$	344		$	360
	Based on current estimates, Occidental expects to expend funds corresponding to approximately half of the current environmental reserves at the sites described above over the next three to four years and the 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 $380 million.
	ENVIRONMENTAL COSTS
	Occidental’s environmental costs, some of which include estimates, are presented below for each segment for each of the years ended December 31:
	In millions		2013			2012			2011
	Operating Expenses
	Oil and Gas		$	137		$	160		$	158
	Chemical		75			70			68
	Midstream and Marketing		17			20			21
			$	229		$	250		$	247
	Capital Expenditures
	Oil and Gas		$	97		$	122		$	110
	Chemical		14			18			15
	Midstream and Marketing		7			12			15
			$	118		$	152		$	140
	Remediation Expenses
	Corporate		$	60		$	56		$	52
	Operating expenses are incurred on a continual basis.  Capital expenditures relate to longer-lived improvements in  properties currently operated by Occidental.  Remediation expenses relate to existing conditions from past operations.

LAWSUITS_CLAIMS_COMMITMENTS_AN

LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2013
LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES	'
LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES	'
	NOTE 9	LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES
	OPC 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.  OPC or certain of its subsidiaries also are involved in proceedings under 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 OPC 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.
	Occidental accrues reserves for currently outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the liability can be reasonably estimated.  Occidental has disclosed its reserve balances for environmental matters.  Reserve balances for other matters as of December 31, 2013 and 2012, were not material to Occidental’s consolidated balance sheets.  Occidental also evaluates the amount of reasonably possible losses that it could incur as a result of the matters mentioned above.  Occidental has disclosed its range of reasonably possible additional losses for sites where it is a participant in environmental remediation.  Occidental believes that other reasonably possible losses that it could incur in excess of reserves accrued on the balance sheet would not be material to its consolidated financial position or results of operations.
	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.  Although taxable years through 2009 for United States federal income tax purposes have been audited by the United States Internal Revenue Service (IRS) pursuant to its Compliance Assurance Program, subsequent taxable years are currently under review.  Additionally, in December 2012, Occidental filed United States federal refund claims for tax years 2008 and 2009 which are subject to IRS review.  Taxable years from 2000 through the current year remain subject to examination by foreign and state government tax authorities in certain jurisdictions.  In certain of these jurisdictions, tax authorities are in various stages of auditing Occidental’s income taxes.  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.
	OPC, 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.  At December 31, 2013, total purchase obligations were $10.0 billion, which included approximately $3.0 billion, $1.7 billion, $1.0 billion, $0.6 billion and $0.8 billion that will be paid in 2014, 2015, 2016, 2017 and 2018, respectively.  Included in the purchase obligations are commitments for major fixed and determinable capital expenditures during 2014 and thereafter, which were approximately $2.1 billion.
	OPC, 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 December 31, 2013, 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.

DOMESTIC_AND_FOREIGN_INCOME_TA

DOMESTIC AND FOREIGN INCOME TAXES	12 Months Ended
	Dec. 31, 2013
DOMESTIC AND FOREIGN INCOME TAXES	'
DOMESTIC AND FOREIGN INCOME TAXES	'
	NOTE 10	DOMESTIC AND FOREIGN INCOME TAXES
	The domestic and foreign components of income from continuing operations before domestic and foreign income taxes were as follows:
	For the years ended December 31, (in millions)		Domestic			Foreign			Total
	2013		$	4,930		$	4,747		$	9,677
	2012		$	2,117		$	5,636		$	7,753
	2011		$	4,806		$	6,035		$	10,841
	The provisions (credits) for domestic and foreign income taxes on continuing operations consisted of the following:
	For the years ended December 31, (in millions)		United States			State			Foreign			Total
			Federal			and Local
	2013
	Current		$	361		$	37		$	2,170		$	2,568
	Deferred		1,145			59			(17		)	1,187
			$	1,506		$	96		$	2,153		$	3,755
	2012
	Current		$	(401	)	$	8		$	2,383		$	1,990
	Deferred		1,046			41			41			1,128
			$	645		$	49		$	2,424		$	3,118
	2011
	Current		$	320		$	88		$	2,357		$	2,765
	Deferred		1,340			47			49			1,436
			$	1,660		$	135		$	2,406		$	4,201
	The following reconciliation of the United States federal statutory income tax rate to Occidental’s worldwide effective tax rate on income from continuing operations is stated as a percentage of pre-tax income:
	For the years ended December 31,		2013		2012		2011
	United States federal statutory tax rate		35	%	35	%	35	%
	Operations outside the United States		4		5		4
	State income taxes, net of federal benefit		1		1		1
	Other		(1	)	(1	)	(1	)
	Worldwide effective tax rate		39	%	40	%	39	%
	The tax effects of temporary differences resulting in deferred income taxes at December 31, 2013 and 2012 were as follows:
			2013						2012
	Tax effects of temporary differences (in millions)		Deferred Tax			Deferred Tax			Deferred Tax			Deferred Tax
			Assets			Liabilities			Assets			Liabilities
	Property, plant and equipment differences		$	—		$	8,363		$	—		$	7,316
	Equity investments, partnerships and foreign subsidiaries		—			225			—			351
	Environmental reserves		121			—			126			—
	Postretirement benefit accruals		376			—			413			—
	Deferred compensation and benefits		222			—			278			—
	Asset retirement obligations		407			—			367			—
	Foreign tax credit carryforwards		1,091			—			1,277			—
	Other tax credit carryforwards		—			—			195			—
	Federal benefit of state income taxes		136			—			89			—
	All other		344			82			334			161
	Subtotal		2,697			8,670			3,079			7,828
	Valuation allowance		(1,074		)	—			(1,040		)	—
	Total deferred taxes		$	1,623		$	8,670		$	2,039		$	7,828
	The current portion of total deferred tax assets was $150 million and $250 million as of December 31, 2013 and 2012, respectively, which was reported in other current assets.  Total deferred tax assets were $1.6 billion and $2.0 billion as of December 31, 2013 and 2012, respectively, the noncurrent portion of which is netted against deferred tax liabilities.  Occidental expects to realize the recorded deferred tax assets, net of any allowances, through future operating income and reversal of temporary differences.
	Occidental had, as of December 31, 2013, foreign tax credit carryforwards of $1.1 billion, which expire in varying amounts through 2022, and various state operating loss carryforwards, which have varying carryforward periods through 2025.  Occidental’s valuation allowance provides for substantially all of the foreign tax credit and state operating loss carryforwards.
	A deferred tax liability has not been recognized for temporary differences related to unremitted earnings of certain consolidated foreign subsidiaries aggregating approximately $10.6 billion, net of foreign taxes, at December 31, 2013, as it is Occidental’s intention, generally, to reinvest such earnings permanently.  If the earnings of these foreign subsidiaries were not indefinitely reinvested, an additional deferred tax liability of approximately $134 million would be required, assuming utilization of available foreign tax credits.
	Discontinued operations include income tax charges of $9 million, $7 million and $86 million in 2013, 2012 and 2011, respectively.
	Additional paid-in capital was credited $6 million in 2013, $8 million in 2012 and $14 million in 2011 for an excess tax benefit from the exercise of certain stock-based compensation awards.
	As of December 31, 2013, Occidental had liabilities for unrecognized tax benefits of approximately $61 million included in deferred credits and other liabilities — other, all of which, if subsequently recognized, would favorably affect Occidental’s effective tax rate.
	A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
	For the years ended December 31, (in millions)		2013			2012
	Balance at January 1,		$	76		$	67
	Additions based on tax positions related to the current year		—			16
	Reductions based on tax positions related to prior years and settlements		(15		)	(7		)
	Balance at December 31,		$	61		$	76
	Management believes it is unlikely that Occidental’s liabilities for unrecognized tax benefits related to existing matters would increase or decrease within the next 12 months by a material amount.  Occidental cannot reasonably estimate a range of potential changes in such benefits due to the unresolved nature of the various audits.
	Occidental is subject to audit by various tax authorities in varying periods.  See Note 9 for a discussion of these matters.
	Occidental records estimated potential interest and penalties related to liabilities for unrecognized tax benefits in the provisions for domestic and foreign income taxes and these amounts were not material for the years ended December 31, 2013, 2012 and 2011.

STOCKHOLDERS_EQUITY

STOCKHOLDERS' EQUITY	12 Months Ended
	Dec. 31, 2013
STOCKHOLDERS' EQUITY	'
STOCKHOLDERS' EQUITY	'
	NOTE 11	STOCKHOLDERS’ EQUITY
	The following is a summary of common stock issuances:
	Shares in thousands		Common Stock
	Balance, December 31, 2010		885,275
	Issued		1,302
	Options exercised and other, net		232
	Balance, December 31, 2011		886,809
	Issued		1,746
	Options exercised and other, net		246
	Balance, December 31, 2012		888,801
	Issued		826
	Options exercised and other, net		292
	Balance, December 31, 2013		889,919
	TREASURY STOCK
	In February 2014, Occidental increased the number of shares authorized for its share repurchase program by 30 million  from 95 million shares; however, the program does not obligate Occidental to acquire any specific number of shares and may be discontinued at any time.  In 2013 and 2012, respectively, Occidental purchased 10.3 million and 7.2 million shares under the program at an average cost of $94.42 and $77.98 per share.
	Additionally, Occidental purchased shares from the trustee of its defined contribution savings plan during each year.
	As of December 31, 2013, 2012 and 2011, treasury stock shares numbered 93.9 million, 83.3 million and 75.8 million, respectively.
	NONREDEEMABLE PREFERRED STOCK
	Occidental has authorized 50,000,000 shares of preferred stock with a par value of $1.00 per share.  At December 31, 2013, 2012 and 2011, Occidental had no outstanding shares of preferred stock.
	EARNINGS PER SHARE
	The following table presents the calculation of basic and diluted EPS for the years ended December 31:
	In millions, except per-share amounts		2013			2012			2011
	Basic EPS
	Income from continuing operations		$	5,922		$	4,635		$	6,640
	Discontinued operations, net		(19		)	(37		)	131
	Net income		5,903			4,598			6,771
	Less: Net income allocated to participating securities		(13		)	(8		)	(11		)
	Net income, net of participating securities		$	5,890		$	4,590		$	6,760
	Weighted average number of basic shares		804.1			809.3			812.1
	Basic EPS		$	7.33		$	5.67		$	8.32
	Diluted EPS
	Net income, net of participating securities		$	5,890		$	4,590		$	6,760
	Weighted average number of basic shares		804.1			809.3			812.1
	Dilutive securities		0.5			0.7			0.8
	Total diluted weighted average common shares		804.6			810			812.9
	Diluted EPS		$	7.32		$	5.67		$	8.32
	ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
	Accumulated other comprehensive loss consisted of the following after-tax amounts:
	Balance at December 31, (in millions)		2013			2012
	Foreign currency translation adjustments		$	(5	)	$	(34	)
	Unrealized losses on derivatives		(14		)	(7		)
	Pension and post-retirement adjustments (a)		(284		)	(461		)
	Total		$	(303	)	$	(502	)
	(a)   See Note 13 for further information.

STOCKBASED_INCENTIVE_PLANS

STOCK-BASED INCENTIVE PLANS	12 Months Ended
	Dec. 31, 2013
STOCK-BASED INCENTIVE PLANS	'
STOCK-BASED INCENTIVE PLANS	'
	NOTE 12	STOCK-BASED INCENTIVE PLANS
	Occidental has established several Plans that allow it to issue stock-based awards including in the form of RSUs, stock options (Options), stock appreciation rights (SARs) and TSRIs.  An aggregate of 66 million shares of Occidental common stock were authorized for issuance and approximately 16 million shares had been issued through December 31, 2013.  Of the remaining shares, only approximately 20 million shares are available for grants of future awards because a plan provision requires each share covered by an award (other than Options and SARs) to be counted as if three shares were issued in determining the number of shares that are available for future awards.  Accordingly, the number of shares available for future awards may be less than 20 million depending on the type of award granted.  Additionally, under the plan, the shares available for future awards may increase, depending on the award type, by the number of shares currently unvested or forfeitable, or three times that number as applicable, that (i) fail to vest, (ii) are forfeited or canceled, or (iii) correspond to the portion of any stock-based awards settled in cash.
	During 2013, non-employee directors were granted awards for 37,100 shares of restricted stock, a substantial majority of which fully vested on the grant date.  Compensation expense for these awards was measured using the quoted market price of Occidental’s common stock on the grant date and was fully recognized at that time.
	The following table summarizes certain stock-based incentive amounts for the past three years:
	For the years ended December 31, (in millions)		2013			2012			2011
	Compensation expense		$	152		$	78		$	110
	Income tax benefit recognized in the income statement		$	55		$	29		$	40
	Intrinsic value of options and stock-settled SARs exercised		$	24		$	18		$	21
	Cash paid (a)		$	96		$	83		$	124
	Fair value of RSUs and TSRIs vested during the year (b)		$	83		$	28		$	53
	(a)   Includes cash paid under the cash-settled portion of the SARs, RSUs and TSRIs.
	(b)   As measured on the vesting date for the stock-settled portion of the RSUs and TSRIs.
	As of December 31, 2013, unrecognized compensation expense for all unvested stock-based incentive awards, based on year-end valuation, was $205 million.  This expense is expected to be recognized over a weighted-average period of 2.0 years.
	RSUs
	Certain employees are awarded the right to receive RSUs, some of which have performance criteria, and are in the form of, or equivalent in value to, actual shares of Occidental common stock.  Depending on their terms, RSUs are settled in cash or stock at the time of vesting.  These awards vest ratably over three years, or at the end of two or three years, following the grant date, however, certain of the RSUs are forfeitable if performance objectives are not satisfied by the seventh anniversary of the grant date.  For certain three-year RSUs, dividend equivalents are paid during the vesting period.  For those awards that cliff vest in two or three years, dividend equivalents are accumulated during the vesting period and are paid when they vest.
	The weighted-average, grant-date fair values of cash-settled RSUs granted in 2013, 2012 and 2011 were $89.70, $84.38 and $104.74 per share, respectively.  The weighted-average, grant-date fair values of the stock-settled RSUs granted in 2013, 2012, and 2011 were $90.35, $84.81 and $102.97, respectively.
	A summary of changes in Occidental’s unvested cash- and stock-settled RSUs during the year ended December 31, 2013 is presented below:
			Cash-Settled					Stock-Settled
			RSUs (000’s)		Weighted-Average			RSUs (000’s)		Weighted-Average
					Grant-Date					Grant-Date
					Fair Value					Fair Value
	Unvested at January 1		1,332		$	90.27		1,375		$	88.23
	Granted		785		89.7			793		90.35
	Vested		(613	)	89.89			(438	)	84.51
	Forfeitures		(73	)	90.26			(123	)	88.59
	Unvested at December 31		1,431		90.12			1,607		90.26
	TSRIs
	Certain executives are awarded TSRIs that vest at the end of a three-year period following the grant date if performance targets are certified as being met.  TSRIs granted in July 2013 and 2012 have payouts that range from 0 to 150 percent of the target award and 0 to 100 percent of the maximum award, respectively, that would settle, once certified, fully in stock.  TSRIs granted in July 2011 have payouts that range from 0 to 100 percent of the maximum award that would settle, once certified, 50 percent in stock and 50 percent in cash.  Dividend equivalents for TSRIs are accumulated and paid upon vesting for the number of vested shares.
	The fair values of TSRIs are initially determined on the grant date using a Monte Carlo simulation model based on Occidental’s assumptions, noted in the following table, and the volatility from corresponding peer group companies.  The expected life is based on the vesting period (Term).  The risk-free interest rate is the implied yield available on zero coupon T-notes (US Treasury Strip) at the time of grant with a remaining term equal to the Term.  The dividend yield is the expected annual dividend yield over the Term, expressed as a percentage of the stock price on the grant date.  Estimates of fair value may not accurately predict the value ultimately realized by the employees who receive the awards, and the ultimate value may not be indicative of the reasonableness of the original estimates of fair value made by Occidental.
	The grant-date assumptions used in the Monte Carlo simulation models for the estimated payout level of TSRIs were as follows:
			TSRIs
	Year Granted		2013			2012			2011
	Assumptions used:
	Risk-free interest rate		0.6		%	0.4		%	0.6		%
	Dividend yield		2.8		%	2.6		%	1.8		%
	Volatility factor		30		%	34		%	33		%
	Expected life (years)		3			3			3
	Grant-date fair value of underlying Occidental common stock		$	91.97		$	84.57		$	102.97
	A summary of Occidental’s unvested TSRIs as of December 31, 2013, and changes during the year ended December 31, 2013, is presented below:
			TSRIs
			Awards (000’s)		Weighted-Average
					Grant-Date Fair
					Value of Occidental Stock
	Unvested at January 1 (a)		1,930		$	80.39
	Granted (a)		135		91.97
	Vested (a)		(1,143	)	72.44
	Forfeitures		(90	)	87.05
	Unvested at December 31 (a)		832		92.49
	(a)   Presented at the target or mid-point payouts.
	STOCK OPTIONS AND SARs
	Certain employees have been granted Options that are settled in stock and SARs that are settled either only in stock or only in cash.  No Options or SARs have been granted since 2006 and all outstanding awards are vested.  Exercise prices of the Options and SARs were equal to the quoted market value of Occidental’s stock on the grant date.  Generally, the Options and SARs vest ratably over three years from the grant date with a maximum term of ten years.  These Options and SARs may be forfeited or accelerated under certain circumstances.
	The fair value of each Option, stock-settled SAR or cash-settled SAR is initially measured on the grant date using the Black Scholes option valuation model.  The expected life is estimated based on the actual weighted-average life of historical exercise activity of the grantee population at the grant date.  The volatility factors are based on the historical volatilities of Occidental common stock over the expected lives as estimated on the grant date.  The risk-free interest rate is the implied yield available on US Treasury Strips at the grant date with a remaining term equal to the expected life of the measured instrument.  The dividend yield is the expected annual dividend yield over the expected life, expressed as a percentage of the stock price on the grant date.  Estimates of fair value may not accurately predict the value ultimately realized by employees who receive stock-based incentive awards, and the ultimate value may not be indicative of the reasonableness of the original estimates of fair value made by Occidental.
	The following is a summary of Option and SAR transactions during the year ended December 31, 2013:
			Cash-Settled									Stock-Settled
			SARs		Weighted-			Weighted-		Aggregate		SARs &		Weighted-		Weighted-	Aggregate
			(000’s)		Average			Average		Intrinsic		Options		Average		Average	Intrinsic
					Exercise			Remaining		Value		(000’s)		Exercise		Remaining	Value
					Price			Contractual		(000’s)				Price		Contractual	(000’s)
								Term								Term
								(yrs)								(yrs)
	Beginning balance, January 1		494		$	24.66						537		$	31.88
	Exercised		(142	)	$	24.66						(391	)	$	28.12
	Forfeitures		—		$	—						(1	)	$	15.57
Ending balance, December 31		352		$	24.66		0.5		$	24,783	145		$	42.11	1.9	$	7,701
Exercisable at December 31		352		$	24.66		0.5		$	24,783	145		$	42.11	1.9	$	7,701
OTHER
During 2013, Occidental also granted approximately 160,000 share-equivalents to certain employees that vest at the end of a three-year period beginning January 1, 2014, if performance targets based on returns on assets of the applicable segment or capital employed are certified as being met.  These awards are settled in stock at the time of vesting, with payouts that range from 0 to 200 percent of the target award.  Dividend equivalents are accumulated and paid upon vesting for the number of vested shares.  The weighted-average, grant-date fair value of these awards was $80.98.

RETIREMENT_AND_POSTRETIREMENT_

RETIREMENT AND POSTRETIREMENT BENEFIT PLANS	12 Months Ended
	Dec. 31, 2013
RETIREMENT AND POSTRETIREMENT BENEFIT PLANS	'
RETIREMENT AND POSTRETIREMENT BENEFIT PLANS	'
	NOTE 13	RETIREMENT AND POSTRETIREMENT BENEFIT PLANS
	Occidental has various benefit plans for its salaried, domestic union and nonunion hourly, and certain foreign national employees.
	DEFINED CONTRIBUTION PLANS
	All domestic employees and certain foreign national employees are eligible to participate in one or more of the defined contribution retirement or savings plans that provide for periodic contributions by Occidental based on plan-specific criteria, such as base pay, age, level and employee contributions.  Certain salaried employees participate in a supplemental retirement plan that restores benefits lost due to governmental limitations on qualified retirement benefits.  The accrued liabilities for the supplemental retirement plan were $166 million and $145 million as of December 31, 2013 and 2012, respectively, and Occidental expensed $140 million in 2013, $137 million in 2012 and $110 million in 2011 under the provisions of these defined contribution and supplemental retirement plans.
	DEFINED BENEFIT PLANS
	Participation in defined benefit plans is limited and approximately 1,000 domestic and 1,500 foreign national employees, mainly union, nonunion hourly and certain employees that joined Occidental from acquired operations with grandfathered benefits, are currently accruing benefits under these plans.
	Pension costs for Occidental’s defined benefit pension plans, determined by independent actuarial valuations, are generally funded by payments to trust funds, which are administered by independent trustees.
	POSTRETIREMENT AND OTHER BENEFIT PLANS
	Occidental provides medical and dental benefits and life insurance coverage for certain active, retired and disabled employees and their eligible dependents.  Occidental generally funds the benefits as they are paid during the year.  These  benefit costs, including the postretirement costs, were approximately $229 million in 2013, $218 million in 2012 and $194 million in 2011.
	OBLIGATIONS AND FUNDED STATUS
	The following tables show the amounts recognized in the consolidated balance sheets of Occidental related to its pension and postretirement benefit plans and their funding status, obligations and plan asset fair values (in millions):
			Pension Benefits						Postretirement Benefits
	As of December 31,		2013			2012			2013			2012
	Amounts recognized in the consolidated balance sheet:
	Other assets		$	104		$	24		$	—		$	—
	Accrued liabilities		(6		)	(4		)	(58		)	(59		)
	Deferred credits and other liabilities — other		(83		)	(136		)	(958		)	(1,068		)
			$	15		$	(116	)	$	(1,016	)	$	(1,127	)
	AOCI included the following after-tax balances:
	Net loss		$	66		$	134		$	225		$	324
	Prior service cost		1			1			2			2
			$	67		$	135		$	227		$	326
	For the years ended December 31,
	Changes in the benefit obligation:
	Benefit obligation — beginning of year		$	615		$	592		$	1,127		$	1,092
	Service cost — benefits earned during the period		13			13			29			25
	Interest cost on projected benefit obligation		24			27			43			42
	Actuarial (gain) loss		(35		)	46			(126		)	26
	Foreign currency exchange rate (gain) loss		(5		)	2			—			—
	Benefits paid		(54		)	(57		)	(57		)	(58		)
	Settlements		(35		)	(8		)	—			—
	Benefit obligation — end of year		$	523		$	615		$	1,016		$	1,127
	Changes in plan assets:
	Fair value of plan assets — beginning of year		$	499		$	475		$	—		$	—
	Actual return on plan assets		88			61			—			—
	Foreign currency exchange rate loss		—			(3		)	—			—
	Employer contributions		29			31			—			—
	Benefits paid		(54		)	(57		)	—			—
	Settlements		(24		)	(8		)	—			—
	Fair value of plan assets — end of year		$	538		$	499		$	—		$	—
	Funded/(Unfunded) status:		$	15		$	(116	)	$	(1,016	)	$	(1,127	)
	The following table sets forth details of the obligations and assets of Occidental’s defined benefit pension plans (in millions):
			Accumulated Benefit						Plan Assets
			Obligation in Excess of						in Excess of Accumulated
			Plan Assets						Benefit Obligation
	As of December 31, (in millions)		2013			2012			2013			2012
	Projected Benefit Obligation		$	122		$	305		$	401		$	310
	Accumulated Benefit Obligation		$	112		$	278		$	386		$	305
	Fair Value of Plan Assets		$	39		$	171		$	499		$	328
	Occidental does not expect any plan assets to be returned during 2014.
	COMPONENTS OF NET PERIODIC BENEFIT COST
	The following table sets forth the components of net periodic benefit costs (in millions):
			Pension Benefits									Postretirement Benefits
	For the years ended December 31, (in millions)		2013			2012			2011			2013			2012		2011
	Net periodic benefit costs:
	Service cost — benefits earned during the period		$	13		$	13		$	12		$	29		$	25	$	22
	Interest cost on projected benefit obligation		24			27			29			43			42		45
	Expected return on plan assets		(31		)	(31		)	(33		)	—			—		—
	Recognized actuarial loss		19			19			13			38			37		31
	Other costs and adjustments		(13		)	17			—			1			1		1
	Net periodic benefit cost		$	12		$	45		$	21		$	111		$	105	$	99
	The estimated net loss and prior service cost for the defined benefit pension plans that will be amortized from AOCI into net periodic benefit cost over the next fiscal year are $6 million and zero, respectively.  The estimated net loss and prior service cost for the defined benefit postretirement plans that will be amortized from AOCI into net periodic benefit cost over the next fiscal year are $24 million and $1 million, respectively.
	ADDITIONAL INFORMATION
The following table sets forth the weighted-average assumptions used to determine Occidental’s benefit obligation and net periodic benefit cost for domestic plans:
		Pension Benefits				Postretirement Benefits
For the years ended December 31,		2013		2012		2013		2012
Benefit Obligation Assumptions:
Discount rate		4.45	%	3.59	%	4.75	%	3.89	%
Rate of compensation increase		4	%	4	%	—		—
Net Periodic Benefit Cost Assumptions:
Discount rate		3.59	%	4.12	%	3.89	%	4.12	%
Assumed long term rate of return on assets		6.5	%	6.5	%	—		—
Rate of compensation increase		4	%	4	%	—		—
For domestic pension plans and postretirement benefit plans, Occidental based the discount rate on the Aon/Hewitt AA-AAA Universe yield curve in 2013 and 2012.  The weighted-average rate of increase in future compensation levels is consistent with Occidental’s past and anticipated future compensation increases for employees participating in retirement plans that determine benefits using compensation.  The assumed long-term rate of return on assets is estimated with regard to current market factors but within the context of historical returns for the asset mix that exists at year end.
For pension plans outside the United States, Occidental based its discount rate on rates indicative of government or investment grade corporate debt in the applicable country, taking into account hyperinflationary environments when necessary.  The discount rates used for the foreign pension plans ranged from 1.5 percent to 10.0 percent at both December 31, 2013 and 2012.  The average rate of increase in future compensation levels ranged from 1.5 percent to 10.0 percent in 2013, depending on local economic conditions.  The expected long-term rate of return on plan assets was 6.5 percent in excess of local inflation in both 2013 and 2012.
The postretirement benefit obligation was determined by application of the terms of medical and dental benefits and life insurance coverage, including the effect of established maximums on covered costs, together with relevant actuarial assumptions and healthcare cost trend rates projected at an assumed U.S. Consumer Price Index (CPI) increase of 2.36 percent and 2.39 percent as of December 31, 2013 and 2012, respectively.  Since 1993, participants other than certain union employees have paid for all medical cost increases in excess of increases in the CPI.  For those union employees, Occidental projected that healthcare cost trend rates would decrease 0.25 percent per year from 8.0 percent in 2013 until they reach 5.0 percent in 2025, and remain at 5.0 percent thereafter.  A 1-percent increase or a 1-percent decrease in these assumed healthcare cost trend rates would result in an increase of $38 million or a reduction of $32 million, respectively, in the postretirement benefit obligation as of December 31, 2013.  The annual service and interest costs would not be materially affected by these changes.
The actuarial assumptions used could change in the near term as a result of changes in expected future trends and other factors that, depending on the nature of the changes, could cause increases or decreases in the plan assets and liabilities.
FAIR VALUE OF PENSION PLAN ASSETS
Occidental employs a total return investment approach that uses a diversified blend of equity and fixed-income investments to optimize the long-term return of plan assets at a prudent level of risk.  The investments are monitored by Occidental’s Investment Committee in its role as fiduciary.  The Investment Committee, consisting of senior Occidental executives, selects and employs various external professional investment management firms to manage specific investments across the spectrum of asset classes.  Equity investments are diversified across United States and non-United States stocks, as well as differing styles and market capitalizations.  Other asset classes such as private equity and real estate may be used with the goals of enhancing long-term returns and improving portfolio diversification.  The target allocation of plan assets is 65 percent equity securities and 35 percent debt securities.  Investment performance is measured and monitored on an ongoing basis through quarterly investment portfolio and manager guideline compliance reviews, annual liability measurements and periodic studies.
The fair values of Occidental’s pension plan assets by asset category are as follows (in millions):
		Fair Value Measurements at December 31, 2013 Using
Description		Level 1			Level 2			Level 3			Total
Asset Class:
U.S. government securities		$	16		$	—		$	—		$	16
Corporate bonds (a)		—			84			—			84
Common/collective trusts (b)		—			19			—			19
Mutual funds:
Bond funds		64			—			—			64
Blend funds		105			—			—			105
Value and growth funds		6			—			—			6
Common and preferred stocks (c)		201			—			—			201
Other		—			37			11			48
Total pension plan assets (d)		$	392		$	140		$	11		$	543
		Fair Value Measurements at December 31, 2012 Using
Description		Level 1			Level 2			Level 3			Total
Asset Class:
U.S. government securities		$	24		$	—		$	—		$	24
Corporate bonds (a)		—			83			—			83
Common/collective trusts (b)		—			11			—			11
Mutual funds:
Bond funds		84			—			—			84
Blend funds		106			—			—			106
Value and growth funds		5			—			—			5
Common and preferred stocks (c)		146			—			—			146
Other		—			35			11			46
Total pension plan assets (d)		$	365		$	129		$	11		$	505
(a)   This category represents investment grade bonds of U.S. and non-U.S. issuers from diverse industries.
(b)   This category includes investment funds that primarily invest in U.S. and non-U.S. common stocks and fixed-income securities.
(c)   This category represents direct investments in common and preferred stocks from diverse U.S. and non-U.S. industries.
(d)   Amounts exclude net payables of approximately $5 million and $6 million as of December 31, 2013 and 2012, respectively.
The activity during the years ended December 31, 2013 and 2012, for the assets using Level 3 fair value measurements was insignificant.
Occidental expects to contribute $6 million in cash to its defined benefit pension plans during 2014.
Estimated future benefit payments, which reflect expected future service, as appropriate, are as follows:
For the years ended December 31, (in millions)		Pension Benefits			Postretirement Benefits
2014		$	46		$	59
2015		$	44		$	60
2016		$	49		$	61
2017		$	41		$	62
2018		$	40		$	63
2019 — 2023		$	233		$	335

INVESTMENTS_AND_RELATEDPARTY_T

INVESTMENTS AND RELATED-PARTY TRANSACTIONS	12 Months Ended
	Dec. 31, 2013
INVESTMENTS AND RELATED-PARTY TRANSACTIONS	'
INVESTMENTS AND RELATED-PARTY TRANSACTIONS	'
	NOTE 14	INVESTMENTS AND RELATED-PARTY TRANSACTIONS
	As of December 31, 2013 and 2012, investments in unconsolidated entities comprised $1.5 billion and $1.9 billion of equity-method investments, respectively.
	EQUITY INVESTMENTS
	As of December 31, 2013, Occidental’s equity investments consisted mainly of an approximate 25-percent interest in Plains Pipeline, a 24.5-percent interest in the stock of Dolphin Energy, and various other partnerships and joint ventures.  Equity investments paid dividends of $447 million, $526 million and $349 million to Occidental in 2013, 2012 and 2011, respectively.  As of December 31, 2013, cumulative undistributed earnings of equity-method investees since their respective acquisitions totaled approximately $65 million.  As of December 31, 2013, Occidental’s investments in equity investees exceeded the underlying equity in net assets by approximately $900 million, of which almost $750 million represented goodwill and the remainder comprised intangibles amortized over their estimated useful lives.
	The following table presents Occidental’s interest in the summarized financial information of its equity-method investments:
	For the years ended December 31, (in millions)		2013		2012		2011
	Revenues		$	3,373	$	2,667	$	2,439
	Costs and expenses		2,987		2,310		2,046
	Net income		$	386	$	357	$	393
	As of December 31, (in millions)		2013		2012
	Current assets		$	1,813	$	2,242
	Non-current assets		$	4,412	$	5,449
	Current liabilities		$	1,308	$	1,799
	Long-term debt		$	2,506	$	2,833
	Other non-current liabilities		$	163	$	248
	Stockholders’ equity		$	2,248	$	2,811
	Occidental’s investment in Dolphin, which was acquired in 2002, consists of two separate economic interests through which Occidental owns (i) a 24.5-percent undivided interest in the upstream operations under an agreement which is proportionately consolidated in the financial statements; and (ii) a 24.5-percent interest in the stock of Dolphin Energy, which operates a pipeline and is accounted for as an equity investment.
	In October 2013, Occidental sold a portion of its equity interest in Plains Pipeline for approximately $1.4 billion, resulting in a pre-tax gain of approximately $1.0 billion.
	RELATED-PARTY TRANSACTIONS
	From time to time, Occidental purchases oil, NGLs, power, steam and chemicals from and sells oil, NGLs, gas, chemicals and power to certain of its equity investees and other related parties at market-related prices.  During 2013, 2012 and 2011, Occidental entered into the following related-party transactions and had the following amounts due from or to its related parties:
	December 31, (in millions)		2013		2012		2011
	Sales (a)		$	663	$	419	$	392
	Purchases		$	—	$	8	$	10
	Services		$	30	$	17	$	10
	Advances and amounts due from		$	67	$	25	$	32
	Amounts due to		$	3	$	129	$	21
	(a)   In 2013, 2012 and 2011, sales of Occidental-produced oil and NGLs to Plains Pipeline accounted for 72 percent, 80 percent and 76 percent of these totals, respectively.  Additionally, Occidental conducts marketing and trading activities with Plains Pipeline for oil and NGLs.  These transactions are reported in Occidental’s income statement on a net margin basis.  The sales amounts above include the net margins on such transactions, which were negligible.

FAIR_VALUE_MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Dec. 31, 2013
FAIR VALUE MEASUREMENTS	'
FAIR VALUE MEASUREMENTS	'
	NOTE 15	FAIR VALUE MEASUREMENTS
	FAIR VALUES – RECURRING
	The following tables provide fair value measurement information for assets and liabilities that are measured on a recurring basis as of December 31, 2013 and 2012 (in millions):
			Fair Value Measurements at December 31, 2013 Using
	Description		Level 1		Level 2		Level 3		Netting and			Total
									Collateral			Fair Value
	Assets:
	Commodity derivatives		$	185	$	195	$	—	$	(329	)	$	51
	Liabilities:
	Commodity derivatives		$	199	$	223	$	—	$	(364	)	$	58
			Fair Value Measurements at December 31, 2012 Using
	Description		Level 1		Level 2		Level 3		Netting and			Total
									Collateral			Fair Value
	Assets:
	Commodity derivatives		$	107	$	312	$	—	$	(301	)	$	118
	Liabilities:
	Commodity derivatives		$	99	$	398	$	—	$	(371	)	$	126
	FAIR VALUES – NONRECURRING
	During its annual capital planning process in the fourth quarter of 2013, management determined that it would not pursue development of certain of its non-producing domestic oil and gas acreage based on product prices, availability of transportation capacity to market the products and regulatory and environmental considerations.  As a result, Occidental recorded pre-tax impairment charges of $0.6 billion for the acreage.
	At year end 2012, Occidental performed impairment tests with respect to its proved and unproved properties due to the negative revisions to certain of its natural gas reserves and the continued deterioration of natural gas prices.  In the fourth quarter of 2012, Occidental recorded pre-tax impairment charges of $1.7 billion, almost all of which were for certain assets in Midcontinent, over 90 percent of which were related to natural gas properties, which were acquired more than five years ago on average.
	The impairment tests, including the fair value estimation, 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 and, where applicable, contractual prices, estimates of oil and gas reserves, estimates of future expected operating and development costs and appropriate discount rates.  These properties were impacted by persistently low natural gas prices in the United States changing management’s development plans.  Occidental used the income approach to measure the fair value of these properties, using inputs categorized as Level 3 in the fair value hierarchy.
	FINANCIAL INSTRUMENTS FAIR VALUE
	The carrying amounts of cash and cash equivalents and other on-balance-sheet financial instruments, other than fixed-rate debt, approximate fair value.  The cost, if any, to terminate off-balance-sheet financial instruments is not significant.

INDUSTRY_SEGMENTS_AND_GEOGRAPH

INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS	12 Months Ended
	Dec. 31, 2013
INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS	'
INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS	'
	NOTE 16	INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS
	Occidental conducts its continuing operations through three segments: (1) oil and gas; (2) chemical; and (3) midstream and marketing.  The oil and gas segment explores for, develops and produces oil and condensate, NGLs, and natural gas.  The chemical segment mainly manufactures and markets basic chemicals and vinyls.  The midstream and marketing segment gathers, processes, transports, stores, purchases and markets oil, condensate, NGLs, natural gas, CO2 and power.  It also trades around its assets, including transportation and storage capacity, and trades oil, NGLs, gas and other commodities.  Additionally, the midstream and marketing segment invests in entities that conduct similar activities.
	Earnings of industry segments and geographic areas exclude income taxes, interest income, interest expense, environmental remediation expenses, unallocated corporate expenses and discontinued operations, but include gains and losses from dispositions of segment and geographic area assets and income from the segments’ equity investments.  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.
	Identifiable assets are those assets used in the operations of the segments.  Corporate assets consist of cash, certain corporate receivables and PP&E, and an investment in the Joslyn, Canada oil sands project.
	Industry Segments		Oil and Gas			Chemical			Midstream			Corporate			Total
	In millions								and			and
									Marketing			Eliminations
	YEAR ENDED DECEMBER 31, 2013
	Net sales		$	19,132	(a)	$	4,673	(b)	$	1,538	(c)	$	(888	)	$	24,455
	Pretax operating profit (loss)		$	7,894	(d)	$	743	(e)	$	1,573	(f)	$	-533	(g),(i)	$	9,677	(d),(e),(f)
	Income taxes		—			—			—			-3,755		(h),(i)	(3,755		)
	Discontinued operations, net		—			—			—			(19		)	(19		)
	Net income (loss)		$	7,894		$	743		$	1,573		$	(4,307	)	$	5,903
	Investments in unconsolidated entities		$	108		$	34		$	1,307		$	10		$	1,459
	Property, plant and equipment additions, net (j)		$	7,106		$	435		$	1,482		$	165		$	9,188
	Depreciation, depletion and amortization		$	4,753		$	346		$	212		$	36		$	5,347
	Total assets		$	46,213		$	3,947		$	14,374		$	4,909		$	69,443
	YEAR ENDED DECEMBER 31, 2012
	Net sales		$	18,906	(a)	$	4,580	(b)	$	1,399	(c)	$	(713	)	$	24,172
	Pretax operating profit (loss)		$	7,095	(d)	$	720		$	439		$	-501	(g),(i)	$	7,753	(d)
	Income taxes		—			—			—			-3,118		(h),(i)	(3,118		)
	Discontinued operations, net		—			—			—			(37		)	(37		)
	Net income (loss)		$	7,095		$	720		$	439		$	(3,656	)	$	4,598
	Investments in unconsolidated entities		$	113		$	108		$	1,662		$	11		$	1,894
	Property, plant and equipment additions, net (j)		$	8,282		$	365		$	1,612		$	91		$	10,350
	Depreciation, depletion and amortization		$	3,933		$	345		$	206		$	27		$	4,511
	Total assets		$	44,004		$	3,854		$	12,762		$	3,590		$	64,210
	YEAR ENDED DECEMBER 31, 2011
	Net sales		$	18,419	(a)	$	4,815	(b)	$	1,447	(c)	$	(742	)	$	23,939
	Pretax operating profit (loss)		$	10,241	(d)	$	861		$	448		$	-709	(g),(i)	$	10,841	(d)
	Income taxes		—			—			—			-4,201		(h),(i)	(4,201		)
	Discontinued operations, net		—			—			—			131			131
	Net income (loss)		$	10,241	(d)	$	861		$	448		$	(4,779	)	$	6,771
	Investments in unconsolidated entities		$	128		$	121		$	1,812		$	11		$	2,072
	Property, plant and equipment additions, net (j)		$	6,192		$	241		$	1,120		$	51		$	7,604
	Depreciation, depletion and amortization		$	3,064		$	330		$	173		$	24		$	3,591
	Total assets		$	38,967		$	3,754		$	11,962		$	5,361		$	60,044
	(See footnotes on next page)
	Footnotes:
	(a)   Oil sales represented approximately 89 percent, 90 percent and 87 percent of the oil and gas segment net sales for the years ended December 31, 2013, 2012 and 2011, respectively.
	(b)   Net sales for the chemical segment comprised the following products:
			Basic Chemicals		Vinyls		Other Chemicals
	Year ended December 31, 2013		55%		42%		3%
	Year ended December 31, 2012		57%		40%		3%
	Year ended December 31, 2011		58%		39%		3%
	(c)   Net sales for the midstream and marketing segment comprised the following:
			Gas Processing		Power		Marketing, Trading,
							Transportation and other
	Year ended December 31, 2013		51%		36%		13%
	Year ended December 31, 2012		59%		27%		14%
	Year ended December 31, 2011		64%		35%		1%
	(d)   The 2013 amount includes pre-tax charges of $607 million for the impairment of domestic non-producing acreage.  The 2012 amount includes pre-tax charges of $1.7 billion for the impairment of domestic gas assets and related items.   The 2011 amount includes pre-tax charges of $35 million related to exploration write-offs in Libya and $29 million related to a Colombian net worth tax, and a pre-tax gain for the sale of an interest in a Colombian pipeline of $22 million.
	(e)   Includes a pre-tax gain of $131 million for the sale of an investment in Carbocloro.
	(f)    Includes a pre-tax gain of $1,030 million for the sale of a portion of  an investment in Plains Pipeline and other items.
	(g)   Includes unallocated net interest expense, administration expense, environmental remediation and other pre-tax items noted in footnote (i) below.
	(h)   Includes all foreign and domestic income taxes from continuing operations.
	(i)    Includes the following significant items affecting earnings for the years ended December 31:
	Benefit (Charge)  (In millions)		2013			2012			2011
	CORPORATE
	Pre-tax operating profit (loss)
	Premium on debt extinguishments		$	—		$	—		$	(163	)
	Litigation reserves		—			(20		)	—
	Charge for former executives and consultants		(55		)	—			—
		$	(55	)	$	(20	)	$	(163	)
Income taxes
State income tax charge		$	—		$	—		$	(33	)
Tax effect of pre-tax adjustments *		(179		)	636			50
		$	(179	)	$	636		$	17
*   Amounts represent the tax effect of the pre-tax adjustments listed in this note, as well as those in footnotes (d), (e) and (f).
(j)    Includes capital expenditures and capitalized interest, but excludes acquisition and disposition of assets.
GEOGRAPHIC AREAS
In millions
		Net sales (a)									Property, plant and equipment, net
For the years ended December 31,		2013			2012			2011			2013			2012			2011
United States		$	16,009		$	15,359		$	15,040		$	42,956		$	40,786		$	36,283
Foreign
Qatar		2,995			3,356			3,432			2,605			2,676			2,735
Oman		2,567			2,578			2,500			2,509			2,353			2,143
Colombia		1,022			1,027			1,054			1,259			1,041			854
United Arab Emirates		—			—			—			3,131			2,104			971
Other Foreign		1,862			1,852			1,913			3,361			3,104			2,698
Total Foreign		8,446			8,813			8,899			12,865			11,278			9,401
Total		$	24,455		$	24,172		$	23,939		$	55,821		$	52,064		$	45,684
(a)   Sales are shown by individual country based on the location of the entity making the sale.

Schedule_II_Valuation_and_Qual

Schedule II - Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2013
Schedule II - Valuation and Qualifying Accounts	'
Schedule II - Valuation and Qualifying Accounts	'
	Schedule II — Valuation and Qualifying Accounts	Occidental Petroleum Corporation
		and Subsidiaries
	In millions
				Additions
		Balance at		Charged to		Charged to		Deductions (a)			Balance at
		Beginning		Costs and		Other					End of
		of Period		Expenses		Accounts					Period
	2013
	Allowance for doubtful accounts	$	16	$	1	$	—	$	—		$	17
	Environmental	$	344	$	60	$	—	$	(74	)	$	330
	Litigation, tax and other reserves	229		3		4		(70		)	166
		$	573	$	63	$	4	$	(144	)	$	496	(b)
	2012
	Allowance for doubtful accounts	$	16	$	—	$	—	$	—		$	16
	Environmental	$	360	$	56	$	—	$	(72	)	$	344
	Litigation, tax and other reserves	198		57		—		(26		)	229
		$	558	$	113	$	—	$	(98	)	$	573	(b)
	2011
	Allowance for doubtful accounts	$	19	$	—	$	—	$	(3	)	$	16
	Environmental	$	366	$	53	$	14	$	(73	)	$	360
	Litigation, tax and other reserves	193		37		—		(32		)	198
		$	559	$	90	$	14	$	(105	)	$	558	(b)
	Note:  The amounts presented represent continuing operations.
	(a)   Primarily represents payments.
	(b)   Of these amounts, $101 million, $98 million and $100 million in 2013, 2012 and 2011, respectively, are classified as current.

SUMMARY_OF_SIGNIFICANT_ACCOUNT1

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)	12 Months Ended
	Dec. 31, 2013
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
Consolidation policy	'
	PRINCIPLES OF CONSOLIDATION
	The consolidated financial statements have been prepared in conformity with United States generally accepted accounting principles (GAAP) and include the accounts of OPC, its subsidiaries and its undivided interests in oil and gas exploration and production ventures.  Occidental accounts for its share of oil and gas exploration and production ventures, in which it has a direct working interest, by reporting its proportionate share of assets, liabilities, revenues, costs and cash flows within the relevant lines on the balance sheets, income statements and cash flow statements.
	Certain financial statements, notes and supplementary data for prior years have been reclassified to conform to the 2013 presentation.
Investments in unconsolidated entities policy	'
	INVESTMENTS IN UNCONSOLIDATED ENTITIES
	Occidental’s percentage interest in the underlying net assets of affiliates as to which it exercises significant influence without having a controlling interest (excluding oil and gas ventures in which Occidental holds an undivided interest) are accounted for under the equity method.  Occidental reviews equity-method investments for impairment whenever events or changes in circumstances indicate that an other-than-temporary decline in value may have occurred.  The amount of impairment, if any, is based on quoted market prices, when available, or other valuation techniques, including discounted cash flows.
Revenue recognition policy	'
	REVENUE RECOGNITION
	Revenue is recognized from oil and gas production when title has passed to the customer, which occurs when the product is shipped.  In international locations where oil is shipped by tanker, title passes when the tanker is loaded or product is received by the customer, depending on the shipping terms.  This process occasionally causes a difference between actual production in a reporting period and sales volumes that have been recognized as revenue.
	Revenue from chemical product sales is recognized when the product is shipped and title has passed to the customer.  Certain incentive programs may provide for payments or credits to be made to customers based on the volume of product purchased over a defined period.  Total customer incentive payments over a given period are estimated and recorded as a reduction to revenue ratably over the contract period.  Such estimates are evaluated and revised as warranted.
	Revenue from marketing and trading activities is recognized on net settled transactions upon completion of contract terms and, for physical deliveries, upon title transfer.  For unsettled transactions, contracts are recorded at fair value and changes in fair value are reflected in net sales.  Revenue from all marketing and trading activities is reported on a net basis.
	Occidental records revenue net of any taxes, such as sales taxes, that are assessed by governmental authorities on Occidental’s customers.
Deferred tax asset valuation allowance policy	'
	Occidental establishes a valuation allowance against net operating losses and other deferred tax assets to the extent it believes the future benefit from these assets will not be realized in the statutory carryforward periods.  Realization of deferred tax assets, including any net operating loss carryforwards, is dependent upon Occidental generating sufficient future taxable income and reversal of temporary differences in jurisdictions where such assets originate.
Cash and cash equivalents policy	'
	CASH AND CASH EQUIVALENTS
	Cash equivalents are short-term, highly liquid investments that are readily convertible to cash.  Cash equivalents were approximately $2.9 billion and $1.0 billion at December 31, 2013 and 2012, respectively.
Available-for-sale securities and trading securities policy	'
	INVESTMENTS
	Available-for-sale securities are recorded at fair value with any unrealized gains or losses included in accumulated other comprehensive income/loss (AOCI).  Trading securities are recorded at fair value with unrealized and realized gains or losses included in net sales.
Inventory policy	'
	INVENTORIES
	Materials and supplies are valued at weighted-average cost and are reviewed periodically for obsolescence.  Oil, NGL and natural gas inventories are valued at the lower of cost or market.
	For the chemical segment, Occidental’s finished goods inventories are valued at the lower of cost or market.  For most of its domestic inventories, other than materials and supplies, the chemical segment uses the last-in, first-out (LIFO) method as it better matches current costs and current revenue.  For other countries, Occidental uses the first-in, first-out method (if the costs of goods are specifically identifiable) or the average-cost method (if the costs of goods are not specifically identifiable).
Property, plant and equipment policy	'
	PROPERTY, PLANT AND EQUIPMENT
	Oil and Gas
	The carrying value of Occidental’s property, plant and equipment (PP&E) represents the cost incurred to acquire or develop the asset, including any asset retirement obligations and capitalized interest, net of accumulated depreciation, depletion and amortization (DD&A) and any impairment charges.  For assets acquired, PP&E cost is based on fair values at the acquisition date.  Asset retirement obligations and interest costs incurred in connection with qualifying capital expenditures are capitalized and amortized over the lives of the related assets.
	Occidental uses the successful efforts method to account for its oil and gas properties.  Under this method, Occidental capitalizes costs of acquiring properties, costs of drilling successful exploration wells and development costs.  The costs of exploratory wells are initially capitalized pending a determination of whether proved reserves have been found.  If proved reserves have been found, the costs of exploratory wells remain capitalized.  Otherwise, Occidental charges the costs of the related wells to expense.  In some cases, a determination of proved reserves cannot be made at the completion of drilling, requiring additional testing and evaluation of the wells.  Occidental generally expenses the costs of such exploratory wells if a determination of proved reserves has not been made within a 12-month period after drilling is complete.
	The following table summarizes the activity of capitalized exploratory well costs for continuing operations for the years ended December 31:
	In millions	2013			2012			2011
	Balance — Beginning of Year	$	124		$	189		$	77
	Additions to capitalized exploratory well costs pending the determination of proved reserves	337			400			333
	Reclassifications to property, plant and equipment based on the determination of proved reserves	(271		)	(389		)	(201		)
	Capitalized exploratory well costs charged to expense	(50		)	(76		)	(20		)
	Balance — End of Year	$	140		$	124		$	189
	Occidental expenses annual lease rentals, the costs of injectants used in production and geological, geophysical and seismic costs as incurred.
	Occidental determines depreciation and depletion of oil and gas producing properties by the unit-of-production method.  It amortizes acquisition costs over total proved reserves, and capitalized development and successful exploration costs over proved developed reserves.
	Proved oil and gas reserves are those quantities of oil and gas which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation.  Occidental has no proved oil and gas reserves for which the determination of economic producibility is subject to the completion of major additional capital expenditures.
	Additionally, Occidental performs impairment tests with respect to its proved properties when product prices decline other than temporarily, reserve estimates change significantly, other significant events occur or management’s plans change with respect to these properties in a manner that may impact Occidental’s ability to realize the recorded asset amounts.  Impairment tests incorporate a number of assumptions involving expectations of undiscounted future cash flows, which can change significantly over time.  These assumptions include estimates of future product prices, which Occidental bases on forward price curves and, when applicable, contractual prices, estimates of oil and gas reserves and estimates of future expected operating and development costs.  Any impairment loss would be calculated as the excess of the asset’s net book value over its estimated fair value.
	A portion of the carrying value of Occidental’s oil and gas properties is attributable to unproved properties.  At December 31, 2013, the net capitalized costs attributable to unproved properties were $3.6 billion.  The unproved amounts are not subject to DD&A until they are classified as proved properties.  As exploration and development work progresses, if reserves on these properties are proved, capitalized costs attributable to the properties become subject to DD&A.  If the exploration and development work were to be unsuccessful, or management decided not to pursue development of these properties as a result of lower commodity prices, higher development and operating costs, contractual conditions or other factors, the capitalized costs of the related properties would be expensed.  The timing of any writedowns of these unproved properties, if warranted, depends upon management’s plans, the nature, timing and extent of future exploration and development activities and their results.  Occidental believes its current plans and exploration and development efforts will allow it to realize its unproved property balance.
	Chemical
	Occidental’s chemical assets are depreciated using either the unit-of-production or the straight-line method, based upon the estimated useful lives of the facilities.  The estimated useful lives of Occidental’s chemical assets, which range from three years to 50 years, are also used for impairment tests.  The estimated useful lives for the chemical facilities are based on the assumption that Occidental will provide an appropriate level of annual expenditures to ensure productive capacity is sustained.  Such expenditures consist of ongoing routine repairs and maintenance, as well as planned major maintenance activities (PMMA).  Ongoing routine repairs and maintenance expenditures are expensed as incurred. PMMA costs are capitalized and amortized over the period until the next planned overhaul.  Additionally, Occidental incurs capital expenditures that extend the remaining useful lives of existing assets, increase their capacity or operating efficiency beyond the original specification or add value through modification for a different use.  These capital expenditures are not considered in the initial determination of the useful lives of these assets at the time they are placed into service.  The resulting revision, if any, of the asset’s estimated useful life is measured and accounted for prospectively.
	Without these continued expenditures, the useful lives of these assets could decrease significantly.  Other factors that could change the estimated useful lives of Occidental’s chemical assets include sustained higher or lower product prices, which are particularly affected by both domestic and foreign competition, demand, feedstock costs, energy prices, environmental regulations and technological changes.
	Occidental performs impairment tests on its chemical assets whenever events or changes in circumstances lead to a reduction in the estimated useful lives or estimated future cash flows that would indicate that the carrying amount may not be recoverable, or when management’s plans change with respect to those assets.  Any impairment loss would be calculated as the excess of the asset’s net book value over its estimated fair value.
	Midstream and Marketing
	Occidental’s midstream and marketing PP&E is depreciated over the estimated useful lives of the assets, using either the unit-of-production or straight-line method.
	Occidental performs impairment tests on its midstream and marketing assets whenever events or changes in circumstances lead to a reduction in the estimated useful lives or estimated future cash flows that would indicate that the carrying amount may not be recoverable, or when management’s plans change with respect to those assets.  Any impairment loss would be calculated as the excess of the asset’s net book value over its estimated fair value.
Fair value policy	'
	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 reported at the end of each reporting period.
	Fair Values - Recurring
	Occidental primarily applies the market approach for recurring fair value measurements, maximizes its use of observable inputs and minimizes its use of unobservable inputs.  Occidental utilizes the mid-point between bid and ask prices for valuing the majority of its assets and liabilities measured and reported at fair value.  In addition to using market data, Occidental makes assumptions in valuing its assets and liabilities, including assumptions about the risks inherent in the inputs to the valuation technique.  For assets and liabilities carried at fair value, Occidental measures fair value using the following methods:
	Ø              Commodity derivatives – Occidental values exchange-cleared commodity derivatives using closing prices provided by the exchange as of the balance sheet date.  These derivatives are classified as Level 1.  Over-the-Counter (OTC) bilateral financial commodity contracts, foreign exchange contracts, options and physical commodity forward purchase and sale contracts are generally valued using quotations provided by brokers or industry-standard models that consider various inputs, including quoted forward prices for commodities, time value, volatility factors, credit risk and current market and contractual prices for the underlying instruments, as well as other relevant economic measures.  Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable prices at which transactions are executed in the marketplace.  Occidental classifies these measurements as Level 2.
	Ø              Embedded commodity derivatives – Occidental values embedded commodity derivatives based on a market approach that considers various assumptions, including quoted forward commodity prices and market yield curves.  The assumptions used include inputs that are observable and unobservable in the marketplace, and the fair value is designated as Level 3 within the valuation hierarchy.
	Occidental generally uses an income approach to measure fair value when there is not a market-observable price for an identical or similar asset or liability.  This approach utilizes management’s judgments regarding expectations of projected cash flows, and discounts those cash flows using a risk-adjusted discount rate.
Environmental liabilities and expenditures policy	'
	ENVIRONMENTAL LIABILITIES AND EXPENDITURES
	Environmental expenditures that relate to current operations are expensed or capitalized as appropriate.  Occidental records environmental reserves and related charges and expenses for estimated remediation costs that relate to existing conditions from past operations when environmental remediation efforts are probable and the costs can be reasonably estimated.  In determining the reserves and the range of reasonably possible additional losses, Occidental refers to currently available information, including relevant past experience, remedial objectives, available technologies, applicable laws and regulations and cost-sharing arrangements.  Occidental bases environmental reserves on management’s estimate of the most likely cost to be incurred, using the most cost-effective technology reasonably expected to achieve the remedial objective.  Occidental periodically reviews reserves and adjusts them as new information becomes available.  Occidental records environmental reserves on a discounted basis when it deems the aggregate amount and timing of cash payments to be reliably determinable at the time the reserves are established.  The reserve methodology with respect to discounting for a specific site is not modified once it is established.  The amount of discounted environmental reserves is insignificant.  Occidental generally records reimbursements or recoveries of environmental remediation costs in income when received, or when receipt of recovery is highly probable.  As of December 31, 2013, 2012 and 2011, Occidental did not have any accruals for reimbursements or recoveries.
	Many factors could affect Occidental’s future remediation costs and result in adjustments to its environmental reserves and range of reasonably possible additional losses.  The most significant are: (1) cost estimates for remedial activities may be inaccurate; (2) the length of time, type or amount of remediation necessary to achieve the remedial objective may change due to factors such as site conditions, the ability to identify and control contaminant sources or the discovery of additional contamination; (3) a regulatory agency may ultimately reject or modify Occidental’s proposed remedial plan; (4) improved or alternative remediation technologies may change remediation costs; (5) laws and regulations may change remediation requirements or affect cost sharing or allocation of liability; and (6) changes in allocation or cost-sharing arrangements may occur.
	Certain sites involve multiple parties with various cost-sharing arrangements, which fall into the following three categories:  (1) environmental proceedings that result in a negotiated or prescribed allocation of remediation costs among Occidental and other alleged potentially responsible parties; (2) oil and gas ventures in which each participant pays its proportionate share of remediation costs reflecting its working interest; or (3) contractual arrangements, typically relating to purchases and sales of properties, in which the parties to the transaction agree to methods of allocating remediation costs.  In these circumstances, Occidental evaluates the financial viability of the other parties with whom it is alleged to be jointly liable, the degree of their commitment to participate and the consequences to Occidental of their failure to participate when estimating Occidental’s ultimate share of liability.  Occidental records reserves at its expected net cost of remedial activities and, based on these factors, believes that it will not be required to assume a share of liability of such other potentially responsible parties in an amount materially above amounts reserved.
	In addition to the costs of investigations and cleanup measures, which often take in excess of 10 years at Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA) National Priorities List (NPL) sites, Occidental’s reserves include management’s estimates of the costs to operate and maintain remedial systems.  If remedial systems are modified over time in response to significant changes in site-specific data, laws, regulations, technologies or engineering estimates, Occidental reviews and adjusts its reserves accordingly.
Asset retirement obligations policy	'
	ASSET RETIREMENT OBLIGATIONS
	Occidental recognizes the fair value of asset retirement obligations in the period in which a determination is made that a legal obligation exists to dismantle an asset and reclaim or remediate the property at the end of its useful life and the cost of the obligation can be reasonably estimated.  The liability amounts are based on future retirement cost estimates and incorporate many assumptions such as time to abandonment, technological changes, future inflation rates and the risk-adjusted discount rate.  When the liability is initially recorded, Occidental capitalizes the cost by increasing the related PP&E balances.  If the estimated future cost of the asset retirement obligation changes, Occidental records an adjustment to both the asset retirement obligation and PP&E.  Over time, the liability is increased and expense is recognized for accretion, and the capitalized cost is depreciated over the useful life of the asset.
	At a certain number of its facilities, Occidental has identified conditional asset retirement obligations that are related mainly to plant decommissioning.  Occidental does not know or cannot estimate when it may settle these obligations.  Therefore, Occidental cannot reasonably estimate the fair value of these liabilities.  Occidental will recognize these conditional asset retirement obligations in the periods in which sufficient information becomes available to reasonably estimate their fair values.
	The following table summarizes the activity of the asset retirement obligation, of which $1,283 million and $1,212 million is included in deferred credits and other liabilities - other, with the remaining current portion in accrued liabilities at December 31, 2013 and 2012, respectively.
	For the years ended December 31, (in millions)	2013			2012
	Beginning balance	$	1,266		$	1,089
	Liabilities incurred – capitalized to PP&E	101			86
	Liabilities settled and paid	(72		)	(58		)
	Accretion expense	68			61
	Acquisitions, dispositions and other – changes in PP&E	(10		)	50
	Revisions to estimated cash flows – changes in PP&E	(21		)	38
	Ending balance	$	1,332		$	1,266
Derivatives Policy	'
	DERIVATIVE INSTRUMENTS
	Derivatives are carried at fair value and on a net basis when a legal right of offset exists with the same counterparty.  Occidental applies hedge accounting when transactions meet specified criteria for cash-flow hedge treatment and management elects and documents such treatment.  Otherwise, any fair value gains or losses are recognized in earnings in the current period.  For cash-flow hedges, the gain or loss on the effective portion of the derivative is reported as a component of other comprehensive income (OCI) with an offsetting adjustment to the basis of the item being hedged.  Realized gains or losses from cash-flow hedges, and any ineffective portion, are recorded as a component of net sales in the consolidated statements of income.  Ineffectiveness is primarily created by a lack of correlation between the hedged item and the hedging instrument due to location, quality, grade or changes in the expected quantity of the hedged item.  Gains and losses from derivative instruments are reported net in the consolidated statements of income. There were no fair value hedges as of and during the years ended December 31, 2013, 2012 and 2011.
	A hedge is regarded as highly effective such that it qualifies for hedge accounting if, at inception and throughout its life, it is expected that changes in the fair value or cash flows of the hedged item will be offset by 80 to 125 percent of the changes in the fair value or cash flows, respectively, of the hedging instrument.  In the case of hedging a forecast transaction, the transaction must be probable and must present an exposure to variations in cash flows that could ultimately affect reported net income or loss.  Occidental discontinues hedge accounting when it determines that a derivative has ceased to be highly effective as a hedge; when the hedged item matures or is sold or repaid; or when a forecast transaction is no longer deemed probable.
Stock-based compensation and pension and postretirement benefits policy	'
	STOCK-BASED INCENTIVE PLANS
	Occidental has established several stockholder-approved stock-based incentive plans for certain employees and directors (Plans) that are more fully described in Note 12.  A summary of Occidental’s accounting policy for awards issued under the Plans is as follows.
	For cash- and stock-settled restricted stock units or incentive award shares (RSUs), compensation value is initially measured on the grant date using the quoted market price of Occidental’s common stock.  For cash- and stock-settled total shareholder return incentives (TSRIs), compensation value is initially measured on the grant date using estimated payout levels derived from the Monte Carlo valuation model.  Compensation expense for RSUs and TSRIs is recognized on a straight-line basis over the requisite service periods, which is generally over the awards’ respective vesting or performance periods.  Compensation expense for the cash-settled portion of the TSRI awards and related dividends is adjusted quarterly for any changes in stock price and the number of share equivalents expected to be paid based on the relevant performance criteria.  For RSUs, compensation expense for the cash-settled portion of the awards is adjusted for changes in the value of the underlying stock on a quarterly basis.  All such performance or stock-price-related changes are recognized in periodic compensation expense.  The stock-settled portion of these awards is expensed using the initially measured compensation value.
	RETIREMENT AND POSTRETIREMENT BENEFIT PLANS
	Occidental recognizes the overfunded or underfunded amounts of its defined benefit pension and postretirement plans in its financial statements using a December 31 measurement date.
	Occidental determines its defined benefit pension and postretirement benefit plan obligations based on various assumptions and discount rates.  The discount rate assumptions used are meant to reflect the interest rate at which the obligations could effectively be settled on the measurement date.  Occidental estimates the rate of return on assets with regard to current market factors but within the context of historical returns.  Occidental funds and expenses negotiated pension increases for domestic union employees over the terms of the applicable collective bargaining agreements.
	Pension and any postretirement plan assets are measured at fair value.  Common stock, preferred stock, publicly registered mutual funds, U.S. government securities and corporate bonds are valued using quoted market prices in active markets when available.  When quoted market prices are not available, these investments are valued using pricing models with observable inputs from both active and non-active markets.  Common and collective trusts are valued at the fund units’ net asset value (NAV) provided by the issuer, which represents the quoted price in a non-active market.  Short-term investment funds are valued at the fund units’ NAV provided by the issuer.
Earnings per share policy	'
	EARNINGS PER SHARE
	Occidental’s instruments containing rights to nonforfeitable dividends granted in stock-based awards are considered participating securities prior to vesting and, therefore, have been deducted from earnings in computing basic and diluted EPS under the two-class method.
	Basic EPS was computed by dividing net income attributable to common stock, net of income allocated to participating securities, by the weighted-average number of common shares outstanding during each period, net of treasury shares and including vested but unissued shares and share units. The computation of diluted EPS reflects the additional dilutive effect of stock options and unvested stock awards.
Foreign currency transactions policy	'
	FOREIGN CURRENCY TRANSACTIONS
	The functional currency applicable to all of Occidental’s foreign oil and gas operations is the United States dollar since cash flows are denominated principally in United States dollars.  In Occidental’s other operations, Occidental’s use of non-United States dollar functional currencies was not material for all years presented.  The effect of exchange rates on transactions in foreign currencies is included in periodic income.  Occidental reports the exchange rate differences arising from translating foreign-currency-denominated balance sheet accounts to the United States dollar as of the reporting date in other comprehensive income.  Exchange-rate gains and losses for continuing operations were not material for all years presented.

SUMMARY_OF_SIGNIFICANT_ACCOUNT2

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)	12 Months Ended
	Dec. 31, 2013
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	'
Summary of the activity of capitalized exploratory well costs for continuing operations	'
	In millions	2013			2012			2011
	Balance — Beginning of Year	$	124		$	189		$	77
	Additions to capitalized exploratory well costs pending the determination of proved reserves	337			400			333
	Reclassifications to property, plant and equipment based on the determination of proved reserves	(271		)	(389		)	(201		)
	Capitalized exploratory well costs charged to expense	(50		)	(76		)	(20		)
	Balance — End of Year	$	140		$	124		$	189
Summary of the activity of the asset retirement obligation	'
	For the years ended December 31, (in millions)	2013			2012
	Beginning balance	$	1,266		$	1,089
	Liabilities incurred – capitalized to PP&E	101			86
	Liabilities settled and paid	(72		)	(58		)
	Accretion expense	68			61
	Acquisitions, dispositions and other – changes in PP&E	(10		)	50
	Revisions to estimated cash flows – changes in PP&E	(21		)	38
	Ending balance	$	1,332		$	1,266

INVENTORIES_Tables

INVENTORIES (Tables)	12 Months Ended
	Dec. 31, 2013
INVENTORIES	'
Inventories (in millions)	'
	Balance at December 31, (in millions)	2013			2012
	Raw materials	$	74		$	70
	Materials and supplies	628			612
	Finished goods	589			763
		1,291			1,445
	LIFO reserve	(91		)	(101		)
	Total	$	1,200		$	1,344

LONGTERM_DEBT_Tables

LONG-TERM DEBT (Tables)	12 Months Ended
	Dec. 31, 2013
LONG-TERM DEBT	'
Long-term debt	'
	Balance at December 31, (in millions)	2013			2012
	4.10% senior notes due 2021	$	1,249		$	1,300
	1.75% senior notes due 2017	1,250			1,250
	2.70% senior notes due 2023	1,224			1,250
	3.125% senior notes due 2022	887			900
	4.125% senior notes due 2016	750			750
	2.5% senior notes due 2016	700			700
	1.45% senior notes due 2013	—			600
	1.50% senior notes due 2018	500			500
	8.45% senior notes due 2029	116			116
	9.25% senior debentures due 2019	116			116
	7.2% senior debentures due 2028	82			82
	Variable rate bonds due 2030 (0.04% and 0.13% as of December 31, 2013 and 2012, respectively)	68			68
	8.75% medium-term notes due 2023	22			22
		6,964			7,654
	Less:
	Unamortized discount, net	(25		)	(31		)
	Current maturities	—			(600		)
	Total	$	6,939		$	7,023
	Occidental has a bank credit facility (Credit

LEASE_COMMITMENTS_Tables

LEASE COMMITMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
LEASE COMMITMENTS	'
Future net minimum lease payments for noncancelable operating leases	'
	In millions	Amount (a)
	2014	$	141
	2015	122
	2016	97
	2017	89
	2018	128
	Thereafter	589
	Total minimum lease payments	$	1,166
	(a)   These amounts are net of sublease rentals of $3 million, which are to be received in 2014.

DERIVATIVES_Tables

DERIVATIVES (Tables)	12 Months Ended
	Dec. 31, 2013
Derivatives	'
Cash-flow hedges - after-tax gains and losses recognized in, and reclassified to income from, Accumulated Other Comprehensive Income (in millions)	'
		After-tax
		2013				2012
	Beginning Balance — AOCI	$	(7	)		$	1
	Unrealized (losses) gains recognized in AOCI	(3		)		16
	Gains reclassified to income	(4		)		(24		)
	Ending Balance — AOCI	$	(14	)		$	(7	)
Gross and net fair values of outstanding derivatives (in millions)	'
	December 31, 2013	Asset Derivatives Balance Sheet Location		Fair				Liability Derivatives	Fair
				Value				Balance Sheet Location	Value
	Cash-flow hedges (a)
	Commodity contracts	Other current assets		$	—			Accrued liabilities	$	4
		Long-term receivables and other assets, net		—				Deferred credits and other liabilities	—
				$	—				$	4
	Derivatives not designated as hedging instruments (a)
	Commodity contracts	Other current assets		$	367			Accrued liabilities	$	407
		Long-term receivables and other assets, net		13				Deferred credits and other liabilities	11
				380					418
	Total gross fair value			380					422
	Less: counterparty netting and cash collateral (b) (d)			(329		)			(364		)
	Total net fair value of derivatives			$	51				$	58
	December 31, 2012	Asset Derivatives		Fair				Liability Derivatives	Fair
		Balance Sheet Location		Value				Balance Sheet Location	Value
	Cash-flow hedges (a)
	Commodity contracts	Other current assets		$	11			Accrued liabilities	$	1
		Long-term receivables and other assets, net		—				Deferred credits and other liabilities	1
				$	11				$	2
	Derivatives not designated as hedging instruments (a)
	Commodity contracts	Other current assets		$	386			Accrued liabilities	$	479
		Long-term receivables and other assets, net		22				Deferred credits and other liabilities	16
				408					495
	Total gross fair value			419					497
	Less: counterparty netting and cash collateral (c) (d)			(301		)			(371		)
	Total net fair value of derivatives			$	118				$	126
	(a)   Fair values are presented at gross amounts, including when the derivatives are subject to master netting arrangements and presented on a net basis in the consolidated balance sheets.
	(b)   As of December 31, 2013, collateral received of $11 million has been netted against derivative assets and collateral paid of $46 million has been netted against derivative liabilities.
	(c)   As of December 31, 2012, collateral received of $25 million has been netted against derivative assets and collateral paid of $95 million has been netted against derivative liabilities.
	(d)   Select clearinghouses and brokers require Occidental to post an initial margin deposit.  Collateral, mainly for initial margin, of $103 million and $116 million deposited by Occidental has not been reflected in these derivative fair value tables.  This collateral is included in other current assets in the consolidated balance sheets as of December 31, 2013 and 2012, respectively.
Derivatives Not Designated as Hedging Instruments | Commodity Contracts	'
Derivatives	'
Net volumes of outstanding commodity derivatives contracts	'
		Net Outstanding Position
		Long / (Short)
	Commodity	2013			2012
	Oil (million barrels)	(22	)		(4	)
	Natural gas (billion cubic feet)	(10	)		(170	)
	Precious metals (million troy ounces)	1			1

ENVIRONMENTAL_LIABILITIES_AND_1

ENVIRONMENTAL LIABILITIES AND EXPENDITURES (Tables)	12 Months Ended
	Dec. 31, 2013
ENVIRONMENTAL LIABILITIES AND EXPENDITURES	'
Environmental loss contingencies by categories of sites	'
	$ amounts in millions	2013					2012				2011
		Number of Sites		Reserve Balance			Number of Sites		Reserve Balance		Number of Sites	Reserve Balance
	NPL sites	31		$	25		35		$	54	36	$	63
	Third-party sites	74		83			75		84		73	88
	Occidental-operated sites	20		118			22		123		22	120
	Closed or non-operated Occidental sites	32		104			29		83		29	89
	Total	157		$	330		161		$	344	160	$	360
Environmental reserve activity	'
	In millions	2013			2012			2011
	Balance — Beginning of Year	$	344		$	360		$	366
	Remediation expenses and interest accretion	60			56			53
	Changes from acquisitions/dispositions	—			—			14
	Payments	(74		)	(72		)	(73		)
	Balance — End of Year	$	330		$	344		$	360
Environmental cost for each segment	'
	In millions	2013			2012			2011
	Operating Expenses
	Oil and Gas	$	137		$	160		$	158
	Chemical	75			70			68
	Midstream and Marketing	17			20			21
		$	229		$	250		$	247
	Capital Expenditures
	Oil and Gas	$	97		$	122		$	110
	Chemical	14			18			15
	Midstream and Marketing	7			12			15
		$	118		$	152		$	140
	Remediation Expenses
	Corporate	$	60		$	56		$	52

DOMESTIC_AND_FOREIGN_INCOME_TA1

DOMESTIC AND FOREIGN INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2013
DOMESTIC AND FOREIGN INCOME TAXES	'
Domestic and foreign components of income from continuing operations before domestic and foreign income taxes	'
	For the years ended December 31, (in millions)	Domestic			Foreign			Total
	2013	$	4,930		$	4,747		$	9,677
	2012	$	2,117		$	5,636		$	7,753
	2011	$	4,806		$	6,035		$	10,841
Provisions (credits) for domestic and foreign income taxes on continuing operations	'
	For the years ended December 31, (in millions)	United States			State			Foreign			Total
		Federal			and Local
	2013
	Current	$	361		$	37		$	2,170		$	2,568
	Deferred	1,145			59			(17		)	1,187
		$	1,506		$	96		$	2,153		$	3,755
	2012
	Current	$	(401	)	$	8		$	2,383		$	1,990
	Deferred	1,046			41			41			1,128
		$	645		$	49		$	2,424		$	3,118
	2011
	Current	$	320		$	88		$	2,357		$	2,765
	Deferred	1,340			47			49			1,436
		$	1,660		$	135		$	2,406		$	4,201
Reconciliation of the United States federal statutory income tax rate to Occidental's worldwide effective tax rate on income from continuing operations stated as a percentage of pre-tax income	'
	For the years ended December 31,	2013		2012		2011
	United States federal statutory tax rate	35	%	35	%	35	%
	Operations outside the United States	4		5		4
	State income taxes, net of federal benefit	1		1		1
	Other	(1	)	(1	)	(1	)
	Worldwide effective tax rate	39	%	40	%	39	%
Tax effects of temporary differences resulting in deferred income taxes	'
		2013						2012
	Tax effects of temporary differences (in millions)	Deferred Tax			Deferred Tax			Deferred Tax			Deferred Tax
		Assets			Liabilities			Assets			Liabilities
	Property, plant and equipment differences	$	—		$	8,363		$	—		$	7,316
	Equity investments, partnerships and foreign subsidiaries	—			225			—			351
	Environmental reserves	121			—			126			—
	Postretirement benefit accruals	376			—			413			—
	Deferred compensation and benefits	222			—			278			—
	Asset retirement obligations	407			—			367			—
	Foreign tax credit carryforwards	1,091			—			1,277			—
	Other tax credit carryforwards	—			—			195			—
	Federal benefit of state income taxes	136			—			89			—
	All other	344			82			334			161
	Subtotal	2,697			8,670			3,079			7,828
	Valuation allowance	(1,074		)	—			(1,040		)	—
	Total deferred taxes	$	1,623		$	8,670		$	2,039		$	7,828
Reconciliation of the beginning and ending amount of unrecognized tax benefits	'
	For the years ended December 31, (in millions)	2013			2012
	Balance at January 1,	$	76		$	67
	Additions based on tax positions related to the current year	—			16
	Reductions based on tax positions related to prior years and settlements	(15		)	(7		)
	Balance at December 31,	$	61		$	76

STOCKHOLDERS_EQUITY_Tables

STOCKHOLDERS' EQUITY (Tables)	12 Months Ended
	Dec. 31, 2013
STOCKHOLDERS' EQUITY	'
Summary of common stock issuances	'
	Shares in thousands	Common Stock
	Balance, December 31, 2010	885,275
	Issued	1,302
	Options exercised and other, net	232
	Balance, December 31, 2011	886,809
	Issued	1,746
	Options exercised and other, net	246
	Balance, December 31, 2012	888,801
	Issued	826
	Options exercised and other, net	292
	Balance, December 31, 2013	889,919
Calculation of basic and diluted EPS	'
	In millions, except per-share amounts	2013			2012			2011
	Basic EPS
	Income from continuing operations	$	5,922		$	4,635		$	6,640
	Discontinued operations, net	(19		)	(37		)	131
	Net income	5,903			4,598			6,771
	Less: Net income allocated to participating securities	(13		)	(8		)	(11		)
	Net income, net of participating securities	$	5,890		$	4,590		$	6,760
	Weighted average number of basic shares	804.1			809.3			812.1
	Basic EPS	$	7.33		$	5.67		$	8.32
	Diluted EPS
	Net income, net of participating securities	$	5,890		$	4,590		$	6,760
	Weighted average number of basic shares	804.1			809.3			812.1
	Dilutive securities	0.5			0.7			0.8
	Total diluted weighted average common shares	804.6			810			812.9
	Diluted EPS	$	7.32		$	5.67		$	8.32
Components of accumulated other comprehensive income (loss)	'
	Balance at December 31, (in millions)	2013			2012
	Foreign currency translation adjustments	$	(5	)	$	(34	)
	Unrealized losses on derivatives	(14		)	(7		)
	Pension and post-retirement adjustments (a)	(284		)	(461		)
	Total	$	(303	)	$	(502	)
	(a)   See Note 13 for further information.

STOCKBASED_INCENTIVE_PLANS_Tab

STOCK-BASED INCENTIVE PLANS (Tables)	12 Months Ended
	Dec. 31, 2013
STOCK-BASED INCENTIVE PLANS	'
Summary of certain stock-based incentive amounts	'
	For the years ended December 31, (in millions)	2013			2012			2011
	Compensation expense	$	152		$	78		$	110
	Income tax benefit recognized in the income statement	$	55		$	29		$	40
	Intrinsic value of options and stock-settled SARs exercised	$	24		$	18		$	21
	Cash paid (a)	$	96		$	83		$	124
	Fair value of RSUs and TSRIs vested during the year (b)	$	83		$	28		$	53
	(a)   Includes cash paid under the cash-settled portion of the SARs, RSUs and TSRIs.
	(b)   As measured on the vesting date for the stock-settled portion of the RSUs and TSRIs.
Summary of changes in Occidental's unvested cash- and stock- settled RSUs	'
		Cash-Settled					Stock-Settled
		RSUs (000’s)		Weighted-Average			RSUs (000’s)		Weighted-Average
				Grant-Date					Grant-Date
				Fair Value					Fair Value
	Unvested at January 1	1,332		$	90.27		1,375		$	88.23
	Granted	785		89.7			793		90.35
	Vested	(613	)	89.89			(438	)	84.51
	Forfeitures	(73	)	90.26			(123	)	88.59
	Unvested at December 31	1,431		90.12			1,607		90.26
Grant-date assumptions used in the Monte Carlo simulation models for the estimated payout level of TSRIs	'
		TSRIs
	Year Granted	2013			2012			2011
	Assumptions used:
	Risk-free interest rate	0.6		%	0.4		%	0.6		%
	Dividend yield	2.8		%	2.6		%	1.8		%
	Volatility factor	30		%	34		%	33		%
	Expected life (years)	3			3			3
	Grant-date fair value of underlying Occidental common stock	$	91.97		$	84.57		$	102.97
Summary of Option and SAR transactions	'
		Cash-Settled									Stock-Settled
		SARs		Weighted-			Weighted-		Aggregate		SARs &		Weighted-		Weighted-	Aggregate
		(000’s)		Average			Average		Intrinsic		Options		Average		Average	Intrinsic
				Exercise			Remaining		Value		(000’s)		Exercise		Remaining	Value
				Price			Contractual		(000’s)				Price		Contractual	(000’s)
							Term								Term
							(yrs)								(yrs)
	Beginning balance, January 1	494		$	24.66						537		$	31.88
	Exercised	(142	)	$	24.66						(391	)	$	28.12
	Forfeitures	—		$	—						(1	)	$	15.57
	Ending balance, December 31	352		$	24.66		0.5		$	24,783	145		$	42.11	1.9	$	7,701
	Exercisable at December 31	352		$	24.66		0.5		$	24,783	145		$	42.11	1.9	$	7,701
TSRIs	'
STOCK-BASED INCENTIVE PLANS	'
Summary of Occidental's unvested awards	'
		TSRIs
		Awards (000’s)		Weighted-Average
				Grant-Date Fair
				Value of Occidental Stock
	Unvested at January 1 (a)	1,930		$	80.39
	Granted (a)	135		91.97
	Vested (a)	(1,143	)	72.44
	Forfeitures	(90	)	87.05
	Unvested at December 31 (a)	832		92.49
	(a)   Presented at the target or mid-point payouts.

RETIREMENT_AND_POSTRETIREMENT_1

RETIREMENT AND POSTRETIREMENT BENEFIT PLANS (Tables)	12 Months Ended
	Dec. 31, 2013
RETIREMENT AND POSTRETIREMENT BENEFIT PLANS	'
Components of amounts recognized in the consolidated balance sheets (in millions)	'
		Pension Benefits						Postretirement Benefits
	As of December 31,	2013			2012			2013			2012
	Amounts recognized in the consolidated balance sheet:
	Other assets	$	104		$	24		$	—		$	—
	Accrued liabilities	(6		)	(4		)	(58		)	(59		)
	Deferred credits and other liabilities — other	(83		)	(136		)	(958		)	(1,068		)
		$	15		$	(116	)	$	(1,016	)	$	(1,127	)
After-tax balances included in AOCI (in millions)	'
		Pension Benefits						Postretirement Benefits
	As of December 31,	2013			2012			2013			2012
	AOCI included the following after-tax balances:
	Net loss	$	66		$	134		$	225		$	324
	Prior service cost	1			1			2			2
		$	67		$	135		$	227		$	326
Funding status of Occidental's plans (in millions)	'
	For the years ended December 31,
	Changes in the benefit obligation:
	Benefit obligation — beginning of year	$	615		$	592		$	1,127		$	1,092
	Service cost — benefits earned during the period	13			13			29			25
	Interest cost on projected benefit obligation	24			27			43			42
	Actuarial (gain) loss	(35		)	46			(126		)	26
	Foreign currency exchange rate (gain) loss	(5		)	2			—			—
	Benefits paid	(54		)	(57		)	(57		)	(58		)
	Settlements	(35		)	(8		)	—			—
	Benefit obligation — end of year	$	523		$	615		$	1,016		$	1,127
	Changes in plan assets:
	Fair value of plan assets — beginning of year	$	499		$	475		$	—		$	—
	Actual return on plan assets	88			61			—			—
	Foreign currency exchange rate loss	—			(3		)	—			—
	Employer contributions	29			31			—			—
	Benefits paid	(54		)	(57		)	—			—
	Settlements	(24		)	(8		)	—			—
	Fair value of plan assets — end of year	$	538		$	499		$	—		$	—
	Funded/(Unfunded) status:	$	15		$	(116	)	$	(1,016	)	$	(1,127	)
Schedule of projected benefit obligation, accumulated benefit obligation and fair value of plan assets for defined benefit pension plans with an accumulated benefit obligation in excess of plan assets and plan assets in excess of the accumulated benefit obligation	'
		Accumulated Benefit						Plan Assets
		Obligation in Excess of						in Excess of Accumulated
		Plan Assets						Benefit Obligation
	As of December 31, (in millions)	2013			2012			2013			2012
	Projected Benefit Obligation	$	122		$	305		$	401		$	310
	Accumulated Benefit Obligation	$	112		$	278		$	386		$	305
	Fair Value of Plan Assets	$	39		$	171		$	499		$	328
Components of the net periodic benefit cost (in millions)	'
		Pension Benefits									Postretirement Benefits
	For the years ended December 31, (in millions)	2013			2012			2011			2013			2012		2011
	Net periodic benefit costs:
	Service cost — benefits earned during the period	$	13		$	13		$	12		$	29		$	25	$	22
	Interest cost on projected benefit obligation	24			27			29			43			42		45
	Expected return on plan assets	(31		)	(31		)	(33		)	—			—		—
	Recognized actuarial loss	19			19			13			38			37		31
	Other costs and adjustments	(13		)	17			—			1			1		1
	Net periodic benefit cost	$	12		$	45		$	21		$	111		$	105	$	99
Weighted-average assumptions used to determine Occidental's benefit obligation and net periodic benefit cost for domestic plans	'
		Pension Benefits				Postretirement Benefits
	For the years ended December 31,	2013		2012		2013		2012
	Benefit Obligation Assumptions:
	Discount rate	4.45	%	3.59	%	4.75	%	3.89	%
	Rate of compensation increase	4	%	4	%	—		—
	Net Periodic Benefit Cost Assumptions:
	Discount rate	3.59	%	4.12	%	3.89	%	4.12	%
	Assumed long term rate of return on assets	6.5	%	6.5	%	—		—
	Rate of compensation increase	4	%	4	%	—		—
Fair values of Occidental's pension plan assets by asset category (in millions)	'
		Fair Value Measurements at December 31, 2013 Using
	Description	Level 1			Level 2			Level 3			Total
	Asset Class:
	U.S. government securities	$	16		$	—		$	—		$	16
	Corporate bonds (a)	—			84			—			84
	Common/collective trusts (b)	—			19			—			19
	Mutual funds:
	Bond funds	64			—			—			64
	Blend funds	105			—			—			105
	Value and growth funds	6			—			—			6
	Common and preferred stocks (c)	201			—			—			201
	Other	—			37			11			48
	Total pension plan assets (d)	$	392		$	140		$	11		$	543
		Fair Value Measurements at December 31, 2012 Using
	Description	Level 1			Level 2			Level 3			Total
	Asset Class:
	U.S. government securities	$	24		$	—		$	—		$	24
	Corporate bonds (a)	—			83			—			83
	Common/collective trusts (b)	—			11			—			11
	Mutual funds:
	Bond funds	84			—			—			84
	Blend funds	106			—			—			106
	Value and growth funds	5			—			—			5
	Common and preferred stocks (c)	146			—			—			146
	Other	—			35			11			46
	Total pension plan assets (d)	$	365		$	129		$	11		$	505
	(a)   This category represents investment grade bonds of U.S. and non-U.S. issuers from diverse industries.
	(b)   This category includes investment funds that primarily invest in U.S. and non-U.S. common stocks and fixed-income securities.
	(c)   This category represents direct investments in common and preferred stocks from diverse U.S. and non-U.S. industries.
	(d)   Amounts exclude net payables of approximately $5 million and $6 million as of December 31, 2013 and 2012, respectively.
Estimated future benefit payments, which reflect expected future service, as appropriate	'
	For the years ended December 31, (in millions)	Pension Benefits			Postretirement Benefits
	2014	$	46		$	59
	2015	$	44		$	60
	2016	$	49		$	61
	2017	$	41		$	62
	2018	$	40		$	63
	2019 — 2023	$	233		$	335

INVESTMENTS_AND_RELATEDPARTY_T1

INVESTMENTS AND RELATED-PARTY TRANSACTIONS (Tables)	12 Months Ended
	Dec. 31, 2013
INVESTMENTS AND RELATED-PARTY TRANSACTIONS	'
Summarized financial information of equity-method investments	'
	For the years ended December 31, (in millions)	2013		2012		2011
	Revenues	$	3,373	$	2,667	$	2,439
	Costs and expenses	2,987		2,310		2,046
	Net income	$	386	$	357	$	393
	As of December 31, (in millions)	2013		2012
	Current assets	$	1,813	$	2,242
	Non-current assets	$	4,412	$	5,449
	Current liabilities	$	1,308	$	1,799
	Long-term debt	$	2,506	$	2,833
	Other non-current liabilities	$	163	$	248
	Stockholders’ equity	$	2,248	$	2,811
Related-party transactions	'
	December 31, (in millions)	2013		2012		2011
	Sales (a)	$	663	$	419	$	392
	Purchases	$	—	$	8	$	10
	Services	$	30	$	17	$	10
	Advances and amounts due from	$	67	$	25	$	32
	Amounts due to	$	3	$	129	$	21
	(a)   In 2013, 2012 and 2011, sales of Occidental-produced oil and NGLs to Plains Pipeline accounted for 72 percent, 80 percent and 76 percent of these totals, respectively.  Additionally, Occidental conducts marketing and trading activities with Plains Pipeline for oil and NGLs.  These transactions are reported in Occidental’s income statement on a net margin basis.  The sales amounts above include the net margins on such transactions, which were negligible.

FAIR_VALUE_MEASUREMENTS_Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
FAIR VALUE MEASUREMENTS	'
Assets and liabilities measured at fair value on a recurring basis (in millions)	'
		Fair Value Measurements at December 31, 2013 Using
	Description	Level 1		Level 2		Level 3		Netting and			Total
								Collateral			Fair Value
	Assets:
	Commodity derivatives	$	185	$	195	$	—	$	(329	)	$	51
	Liabilities:
	Commodity derivatives	$	199	$	223	$	—	$	(364	)	$	58
		Fair Value Measurements at December 31, 2012 Using
	Description	Level 1		Level 2		Level 3		Netting and			Total
								Collateral			Fair Value
	Assets:
	Commodity derivatives	$	107	$	312	$	—	$	(301	)	$	118
	Liabilities:
	Commodity derivatives	$	99	$	398	$	—	$	(371	)	$	126

INDUSTRY_SEGMENTS_AND_GEOGRAPH1

INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS (Tables)	12 Months Ended
	Dec. 31, 2013
INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS	'
Industry segment and corporate disclosures (in millions)	'
		Oil and Gas			Chemical			Midstream			Corporate			Total
	In millions							and			and
								Marketing			Eliminations
	YEAR ENDED DECEMBER 31, 2013
	Net sales	$	19,132	(a)	$	4,673	(b)	$	1,538	(c)	$	(888	)	$	24,455
	Pretax operating profit (loss)	$	7,894	(d)	$	743	(e)	$	1,573	(f)	$	-533	(g),(i)	$	9,677	(d),(e),(f)
	Income taxes	—			—			—			-3,755		(h),(i)	(3,755		)
	Discontinued operations, net	—			—			—			(19		)	(19		)
	Net income (loss)	$	7,894		$	743		$	1,573		$	(4,307	)	$	5,903
	Investments in unconsolidated entities	$	108		$	34		$	1,307		$	10		$	1,459
	Property, plant and equipment additions, net (j)	$	7,106		$	435		$	1,482		$	165		$	9,188
	Depreciation, depletion and amortization	$	4,753		$	346		$	212		$	36		$	5,347
	Total assets	$	46,213		$	3,947		$	14,374		$	4,909		$	69,443
	YEAR ENDED DECEMBER 31, 2012
	Net sales	$	18,906	(a)	$	4,580	(b)	$	1,399	(c)	$	(713	)	$	24,172
	Pretax operating profit (loss)	$	7,095	(d)	$	720		$	439		$	-501	(g),(i)	$	7,753	(d)
	Income taxes	—			—			—			-3,118		(h),(i)	(3,118		)
	Discontinued operations, net	—			—			—			(37		)	(37		)
	Net income (loss)	$	7,095		$	720		$	439		$	(3,656	)	$	4,598
	Investments in unconsolidated entities	$	113		$	108		$	1,662		$	11		$	1,894
	Property, plant and equipment additions, net (j)	$	8,282		$	365		$	1,612		$	91		$	10,350
	Depreciation, depletion and amortization	$	3,933		$	345		$	206		$	27		$	4,511
	Total assets	$	44,004		$	3,854		$	12,762		$	3,590		$	64,210
	YEAR ENDED DECEMBER 31, 2011
	Net sales	$	18,419	(a)	$	4,815	(b)	$	1,447	(c)	$	(742	)	$	23,939
	Pretax operating profit (loss)	$	10,241	(d)	$	861		$	448		$	-709	(g),(i)	$	10,841	(d)
	Income taxes	—			—			—			-4,201		(h),(i)	(4,201		)
	Discontinued operations, net	—			—			—			131			131
	Net income (loss)	$	10,241	(d)	$	861		$	448		$	(4,779	)	$	6,771
	Investments in unconsolidated entities	$	128		$	121		$	1,812		$	11		$	2,072
	Property, plant and equipment additions, net (j)	$	6,192		$	241		$	1,120		$	51		$	7,604
	Depreciation, depletion and amortization	$	3,064		$	330		$	173		$	24		$	3,591
	Total assets	$	38,967		$	3,754		$	11,962		$	5,361		$	60,044
Net product sales for the chemical segment	'
		Basic Chemicals		Vinyls		Other Chemicals
	Year ended December 31, 2013	55%		42%		3%
	Year ended December 31, 2012	57%		40%		3%
	Year ended December 31, 2011	58%		39%		3%
Net sales for the midstream and marketing segment	'
		Gas Processing		Power		Marketing, Trading,
						Transportation and other
	Year ended December 31, 2013	51%		36%		13%
	Year ended December 31, 2012	59%		27%		14%
	Year ended December 31, 2011	64%		35%		1%
Significant items affecting earnings included in the Corporate segment	'
	Benefit (Charge)  (In millions)	2013			2012			2011
	CORPORATE
	Pre-tax operating profit (loss)
	Premium on debt extinguishments	$	—		$	—		$	(163	)
	Litigation reserves	—			(20		)	—
	Charge for former executives and consultants	(55		)	—			—
		$	(55	)	$	(20	)	$	(163	)
	Income taxes
	State income tax charge	$	—		$	—		$	(33	)
	Tax effect of pre-tax adjustments *	(179		)	636			50
		$	(179	)	$	636		$	17
	*   Amounts represent the tax effect of the pre-tax adjustments listed in this note, as well as those in footnotes (d), (e) and (f).
Net sales and property, plant and equipment, net by geographic areas	'
	In millions
		Net sales (a)									Property, plant and equipment, net
	For the years ended December 31,	2013			2012			2011			2013			2012			2011
	United States	$	16,009		$	15,359		$	15,040		$	42,956		$	40,786		$	36,283
	Foreign
	Qatar	2,995			3,356			3,432			2,605			2,676			2,735
	Oman	2,567			2,578			2,500			2,509			2,353			2,143
	Colombia	1,022			1,027			1,054			1,259			1,041			854
	United Arab Emirates	—			—			—			3,131			2,104			971
	Other Foreign	1,862			1,852			1,913			3,361			3,104			2,698
	Total Foreign	8,446			8,813			8,899			12,865			11,278			9,401
	Total	$	24,455		$	24,172		$	23,939		$	55,821		$	52,064		$	45,684
	(a)   Sales are shown by individual country based on the location of the entity making the sale.

SUMMARY_OF_SIGNIFICANT_ACCOUNT3

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
RISKS AND UNCERTAINTIES	'	'	'
Assets, relating to operations in countries outside North America	$13,700,000,000	'	'
Net sales, relating to operations in countries outside North America	8,200,000,000	'	'
CASH AND CASH EQUIVALENTS	'	'	'
Total cash equivalents	2,900,000,000	1,000,000,000	'
PROPERTY, PLANT AND EQUIPMENT	'	'	'
Maximum time period after which costs of exploratory wells are charged to expense if determination of proved reserves has not been made	'12 months	'12 months	'12 months
Net capitalized costs attributable to unproved properties	3,600,000,000	'	'
Capitalized exploratory well costs for the years ended December 31:	'	'	'
Balance - Beginning of Year	124,000,000	189,000,000	77,000,000
Additions to capitalized exploratory well costs pending the determination of proved reserves	337,000,000	400,000,000	333,000,000
Reclassifications to property, plant and equipment based on the determination of proved reserves	-271,000,000	-389,000,000	-201,000,000
Capitalized exploratory well costs charged to expense	-50,000,000	-76,000,000	-20,000,000
Balance - End of Year	140,000,000	124,000,000	189,000,000
ACCRUED LIABILITIES-CURRENT	'	'	'
Accrued liabilities for accrued payroll, commissions and related expenses	459,000,000	385,000,000	'
ENVIRONMENTAL LIABILITIES AND EXPENDITURES	'	'	'
Minimum period of investigation and cleanup for Comprehensive Environmental Response, Compensation and Liability Act National Priorities List sites	'10 years	'10 years	'10 years
ASSET RETIREMENT OBLIGATIONS	'	'	'
Asset retirement obligation, included in deferred credits and other liabilities-other	1,283,000,000	1,212,000,000	'
For the years ended December 31	'	'	'
Beginning balance	1,266,000,000	1,089,000,000	'
Liabilities incurred - capitalized to PP&E	101,000,000	86,000,000	'
Liabilities settled and paid	-72,000,000	-58,000,000	'
Accretion expense	68,000,000	61,000,000	'
Acquisitions, dispositions and other - changes in PP&E	-10,000,000	50,000,000	'
Revisions to estimated cash flows - changes in PP&E	-21,000,000	38,000,000	'
Ending balance	1,332,000,000	1,266,000,000	1,089,000,000
Summary of significant accounting policies	'	'	'
Interest Paid	238,000,000	190,000,000	315,000,000
Minimum	'	'	'
Summary of significant accounting policies	'	'	'
The estimated useful lives of Occidental's chemical assets	'3 years	'	'
DERIVATIVE INSTRUMENTS	'	'	'
Range used to determine if derivative instrument is effective	80.00%	'	'
Maximum	'	'	'
Summary of significant accounting policies	'	'	'
The estimated useful lives of Occidental's chemical assets	'50 years	'	'
DERIVATIVE INSTRUMENTS	'	'	'
Range used to determine if derivative instrument is effective	125.00%	'	'
Debt extinguishment premium	'	'	'
Summary of significant accounting policies	'	'	'
Interest Paid	'	'	154,000,000
Continuing operations	'	'	'
Summary of significant accounting policies	'	'	'
United States federal, state and foreign income taxes paid for continuing operations	1,800,000,000	2,400,000,000	2,900,000,000
Production, property and other taxes paid	$792,000,000	$694,000,000	$635,000,000

ACQUISITIONS_DISPOSITIONS_AND_1

ACQUISITIONS, DISPOSITIONS AND OTHER TRANSACTIONS (Details) (USD $)	3 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended	1 Months Ended	12 Months Ended	1 Months Ended		1 Months Ended
	Jun. 30, 2013	Dec. 31, 2013	31-May-13	Dec. 31, 2013	Oct. 31, 2013	Dec. 31, 2013	Oct. 31, 2013	Dec. 31, 2013	Feb. 28, 2014
			Brazilian chemical facility	Brazilian chemical facility	General Partner of Plains All American Pipeline,L.P	General Partner of Plains All American Pipeline,L.P	Ingleside	Ingleside	Subsequent event
							lb		Hugoton Field operations
									MMcfe
Acquisitions, dispositions and other transactions	'	'	'	'	'	'	'	'	'
Pre-tax proceeds from sale of assets	'	'	'	'	'	'	'	'	$1,400,000,000
Average net production per day	'	'	'	'	'	'	'	'	110,000,000
Percentage of oil in average net production	'	'	'	'	'	'	'	'	30.00%
Sale of equity investment, net	'	'	270,000,000	'	1,400,000,000	'	'	'	'
Gain on sale of equity investments	'	1,175,000,000	131,000,000	131,000,000	1,000,000,000	1,000,000,000	'	'	'
Ethylene production capacity of ethane steam cracking unit, per year (in pounds)	'	'	'	'	'	'	1,200,000,000	'	'
Total portion of construction costs	'	'	'	'	'	'	'	23,000,000	'
Charge for former employees and consultants	$55,000,000	'	'	'	'	'	'	'	'

ACQUISITIONS_DISPOSITIONS_AND_2

ACQUISITIONS, DISPOSITIONS AND OTHER TRANSACTIONS (Details 2) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Nov. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

BridgeTex

BridgeTex

BridgeTex

BridgeTex

BridgeTex

Domestic Oil and Gas Properties

Domestic Oil and Gas Properties

Producing properties in South Texas

Domestic Oil and Gas Properties

bbl

Magellan

Magellan

mi

Acquisitions, dispositions and other transactions

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash paid on acquisition

'

'

'

'

'

'

'

'

'

$500,000,000

$2,300,000,000

$1,800,000,000

$2,600,000,000

Length of BridgeTex Pipeline (mile)

'

'

'

'

450

'

'

'

'

'

'

'

'

BridgeTex Pipeline, crude oil transportation capacity per day (bbl)

'

'

'

'

300,000

'

'

'

'

'

'

'

'

Percentage of ownership interest

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

Percentage of interest owned by noncontrolling interest partner

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

Cash

3,393,000,000

1,592,000,000

3,781,000,000

2,578,000,000

'

82,000,000

50,000,000

'

'

'

'

'

'

PP&E

55,821,000,000

52,064,000,000

45,684,000,000

'

'

420,000,000

9,000,000

'

'

'

'

'

'

Non-controlling amounts

$246,000,000

$32,000,000

'

'

'

'

'

$246,000,000

$32,000,000

'

'

'

'

ACQUISITIONS_DISPOSITIONS_AND_3

ACQUISITIONS, DISPOSITIONS AND OTHER TRANSACTIONS (Details 3) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2011	31-May-11	Nov. 30, 2012
	Al Hosn gas project	Al Hosn gas project	BridgeTex
			bbl
Acquisitions, dispositions and other transactions	'	'	'
Aggregate oil storage capacity of pipeline to be constructed	'	'	2,600,000
Percentage of interest acquired in oil and gas properties and projects	40.00%	'	'
Term of joint venture agreement	'30 years	'	'
Pre-acquisition development expenditures	'	$500	'

ACQUISITIONS_DISPOSITIONS_AND_4

ACQUISITIONS, DISPOSITIONS AND OTHER TRANSACTIONS (Details 4) (Libya activity, USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2011
Libya activity	'
Acquisitions, dispositions and other transactions	'
Capitalized and suspended exploration costs written off	$35

INVENTORIES_Details

INVENTORIES (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
INVENTORIES	'	'
Net carrying values of inventories valued under the LIFO method	$205	$185
Raw materials	74	70
Materials and supplies	628	612
Finished goods	589	763
Inventories, Gross	1,291	1,445
LIFO reserve	-91	-101
Total	$1,200	$1,344

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)

3 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2012

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Aug. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Jun. 30, 2012

Mar. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Aug. 31, 2011

Jun. 30, 2012

Dolphin Energy

Dolphin Energy

4.10% senior notes due 2021

4.10% senior notes due 2021

1.75% senior notes due 2017

1.75% senior notes due 2017

1.75% senior notes due 2017

2.70% senior notes due 2023

2.70% senior notes due 2023

2.70% senior notes due 2023

7.0% senior notes due 2013

3.125% senior notes due 2022

3.125% senior notes due 2022

3.125% senior notes due 2022

4.125% senior notes due 2016

4.125% senior notes due 2016

2.5% senior notes due 2016

2.5% senior notes due 2016

1.45% senior notes due 2013

1.45% senior notes due 2013

1.50% senior notes due 2018

1.50% senior notes due 2018

1.50% senior notes due 2018

6.75% senior notes due 2012

8.45% senior notes due 2029

8.45% senior notes due 2029

9.25% senior debentures due 2019

9.25% senior debentures due 2019

7.2% senior debentures due 2028

7.2% senior debentures due 2028

Variable rate bonds due 2030 (0.04% and 0.13% as of December 31, 2013 and 2012, respectively)

Variable rate bonds due 2030 (0.04% and 0.13% as of December 31, 2013 and 2012, respectively)

8.75% medium-term notes due 2023

8.75% medium-term notes due 2023

Senior notes due in 2021 and later

1.75% senior notes due 2017, 3.125% senior notes due 2022

2.70% senior notes due 2023, 1.50% senior notes due 2018

Debt instrument

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Variable interest rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.04%

0.13%

'

'

'

'

'

Long-term debt, gross

'

$6,964

$7,654

'

'

'

$1,249

$1,300

$1,250

$1,250

'

$1,224

$1,250

'

'

$887

$900

'

$750

$750

$700

$700

'

$600

$500

$500

'

'

$116

$116

$116

$116

$82

$82

$68

$68

$22

$22

'

'

'

Unamortized discount, net

'

-25

-31

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current maturities

'

'

-600

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt

'

6,939

7,023

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument interest rate stated percentage

'

'

'

'

'

'

4.10%

4.10%

1.75%

1.75%

'

2.70%

2.70%

'

'

3.13%

3.13%

'

4.13%

4.13%

2.50%

2.50%

1.45%

1.45%

1.50%

1.50%

'

'

8.45%

8.45%

9.25%

9.25%

7.20%

7.20%

'

'

8.75%

8.75%

'

'

'

Notes repurchased

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90

'

'

Long term debt matured

'

690

'

1,523

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

600

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument issued

'

'

'

'

'

'

'

'

'

'

1,250

'

'

1,250

'

'

'

900

'

'

'

'

'

'

'

'

500

'

'

'

'

'

'

'

'

'

'

'

'

2,150

1,750

Net proceeds from issuance of long-term debt

'

'

1,736

2,111

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,100

1,740

Face amount of notes redeemed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000

'

'

'

'

'

'

'

'

'

'

'

'

368

'

'

'

'

'

'

'

'

'

'

'

'

'

Pre-tax charge related to this redemption of notes

163

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notional amount of limited recourse guarantees with respect to Dolphin Energy's debt

'

'

'

'

$354

$370

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

LONGTERM_DEBT_Details_2

LONG-TERM DEBT (Details 2) (Credit Facility, USD $)	12 Months Ended
In Billions, unless otherwise specified	Dec. 31, 2013
Credit Facility	'
Debt instrument	'
Credit Facility, maximum borrowing capacity	$2
Average annual facility fee as percent of the total commitment amounts	0.08%
Maximum amount of credit facility available in the form of letters of credit	$1

LONGTERM_DEBT_Details_3

LONG-TERM DEBT (Details 3) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Principal payments on long-term debt	'	'
Due in 2014	$0	'
Due in 2015	0	'
Due in 2016	1,500,000,000	'
Due in 2017	1,200,000,000	'
Due in 2018	500,000,000	'
Due in 2019 and thereafter	3,800,000,000	'
Aggregate future principal payments	7,000,000,000	'
Other Fixed-Rate and Variable-Rate Debt Disclosures	'	'
Estimated fair values of long-term debt	7,100,000,000	8,200,000,000
Debt carrying value	$6,964,000,000	$7,654,000,000
Variable-rate debt as percent of Occidental's total debt	1.00%	1.00%

LEASE_COMMITMENTS_Details

LEASE COMMITMENTS (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Future net minimum operating lease payments	'	'	'
Operating lease, 2014	$141	'	'
Operating lease, 2015	122	'	'
Operating lease, 2016	97	'	'
Operating lease, 2017	89	'	'
Operating lease, 2018	128	'	'
Operating lease, Thereafter	589	'	'
Total minimum lease payments	1,166	'	'
Sublease rental amounts, 2014	3	'	'
Rental expense for operating leases, net of sublease rental income	204	176	179
Sublease income	$3	$4	$4

DERIVATIVES_Details

DERIVATIVES (Details)	Dec. 31, 2013	Dec. 31, 2012	Nov. 30, 2012	Mar. 31, 2012	Dec. 31, 2011
	ft3	ft3	Natural Gas - Swaps through March 2014 (in cubic feet)	Natural Gas - Swaps through March 2012 (in cubic feet)	Crude Oil - Collars through December 2011 (in barrels)
			ft3	ft3	bbl
Cash-Flow Hedges	'	'	'	'	'
Daily volume	'	'	50,000,000	50,000,000	12,000
Weighted-average strike price (in dollars per cubic foot)	'	'	0.0043	0.00607	'
Average Floor (in dollars per barrel)	'	'	'	'	32.92
Average Cap (in dollars per barrel)	'	'	'	'	46.35
Natural gas held in storage (in cubic feet)	11,000,000,000	20,000,000,000	'	'	'
Forecast sale of natural gas from storage designated as cash-flow hedges (in cubic feet)	13,000,000,000	20,000,000,000	'	'	'

DERIVATIVES_Details_2

DERIVATIVES (Details 2) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Net After-tax Derivative Activity recorded in AOCI	'		'		'
Beginning Balance - AOCI	($7)		$1		'
Unrealized (losses) gains recognized in AOCI	-3	[1]	16	[1]	14	[1]
Gains reclassified to income	-4	[2]	-24	[2]	98	[2]
Ending Balance - AOCI	($14)		($7)		$1
[1]	Net of tax of $2, $(9) and $(7) in 2013, 2012 and 2011, respectively.
[2]	Net of tax of $2, $14 and $(56) in 2013, 2012 and 2011, respectively.

DERIVATIVES_Details_3

DERIVATIVES (Details 3) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Outstanding commodity derivatives contracts not designated as hedging instruments	'	'
Net gains from derivatives not designated as hedging instruments recognized in net sales (in dollars)	$11	$49
Oil (in barrels)	'	'
Outstanding commodity derivatives contracts not designated as hedging instruments	'	'
Net Outstanding Position Long/(Short)	-22,000,000	-4,000,000
Natural Gas (in cubic feet)	'	'
Outstanding commodity derivatives contracts not designated as hedging instruments	'	'
Net Outstanding Position Long/(Short)	-10,000,000,000	-170,000,000,000
Precious metals (in troy ounces)	'	'
Outstanding commodity derivatives contracts not designated as hedging instruments	'	'
Net Outstanding Position Long/(Short)	1,000,000	1,000,000

DERIVATIVES_Details_4

DERIVATIVES (Details 4) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Gross and net fair values of outstanding derivatives (in millions)	'	'
Less: counterparty netting and cash collateral, asset	($329)	($301)
Less: counterparty netting and cash collateral, liability	-364	-371
Total net fair value, asset	51	118
Total net fair value, liability	58	126
Collateral received netted against derivative assets	11	25
Collateral paid netted against derivative liabilities	46	95
Collateral deposited with clearinghouses and brokers	103	116
Credit risk contingent features	'	'
Net derivative liabilities with credit-risk-contingent features	8	34
Amount of collateral posted	23	64
Commodity Contracts	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative asset, gross	380	419
Commodity contract derivative liability, gross	422	497
Cash-flow hedges | Commodity Contracts	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative asset, gross	'	11
Commodity contract derivative liability, gross	4	2
Cash-flow hedges | Commodity Contracts | Other current assets	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative asset, gross	'	11
Cash-flow hedges | Commodity Contracts | Accrued liabilities	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative liability, gross	4	1
Cash-flow hedges | Commodity Contracts | Deferred credits and other liabilities	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative liability, gross	'	1
Not designated as hedging instruments | Commodity Contracts	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative asset, gross	380	408
Commodity contract derivative liability, gross	418	495
Not designated as hedging instruments | Commodity Contracts | Other current assets	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative asset, gross	367	386
Not designated as hedging instruments | Commodity Contracts | Long-term receivables and other assets, net	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative asset, gross	13	22
Not designated as hedging instruments | Commodity Contracts | Accrued liabilities	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative liability, gross	407	479
Not designated as hedging instruments | Commodity Contracts | Deferred credits and other liabilities	'	'
Gross and net fair values of outstanding derivatives (in millions)	'	'
Commodity contract derivative liability, gross	$11	$16

ENVIRONMENTAL_LIABILITIES_AND_2

ENVIRONMENTAL LIABILITIES AND EXPENDITURES (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
	site	site	site
ENVIRONMENTAL LIABILITIES AND EXPENDITURES	'	'	'	'
Environmental remediation reserves, current, included in accrued liabilities	$78	$80	$79	'
Environmental remediation reserves, noncurrent, included in deferred credits and other liabilities - other	252	264	281	'
Environmental remediation reserves	'	'	'	'
Number of Sites	157	161	160	'
Reserve Balance	330	344	360	366
Environmental reserves, exceeding $ ten million, threshold value	10	'	'	'
Environmental reserves, exceeding $ ten million, number of sites	10	'	'	'
Environmental reserves, range between zero to $ one million site category, number of sites	108	'	'	'
Minimum period of expending second half of environmental reserves	'10 years	'	'	'
Environmental remediation additional loss range	380	'	'	'
Environmental costs, including certain estimates by segment	'	'	'	'
Operating Expenses	229	250	247	'
Capital Expenditures	118	152	140	'
Low end of range	'	'	'	'
Environmental remediation reserves	'	'	'	'
Environmental reserves, range between zero to $ one million site category	0	'	'	'
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	'	'	'
Oil and Gas	'	'	'	'
Environmental costs, including certain estimates by segment	'	'	'	'
Operating Expenses	137	160	158	'
Capital Expenditures	97	122	110	'
Chemical	'	'	'	'
Environmental costs, including certain estimates by segment	'	'	'	'
Operating Expenses	75	70	68	'
Capital Expenditures	14	18	15	'
Midstream, Marketing and Other	'	'	'	'
Environmental costs, including certain estimates by segment	'	'	'	'
Operating Expenses	17	20	21	'
Capital Expenditures	7	12	15	'
Corporate	'	'	'	'
Environmental costs, including certain estimates by segment	'	'	'	'
Remediation Expenses	60	56	52	'
NPL sites	'	'	'	'
Environmental remediation reserves	'	'	'	'
Number of Sites	31	35	36	'
Reserve Balance	25	54	63	'
Number of sites with significant environmental remediation reserves	2	'	'	'
Percentage of environmental reserves accounted for by associated sites	60.00%	'	'	'
Number of sites indemnified by third party	14	'	'	'
Third-party sites	'	'	'	'
Environmental remediation reserves	'	'	'	'
Number of Sites	74	75	73	'
Reserve Balance	83	84	88	'
Number of sites with significant environmental remediation reserves	3	'	'	'
Percentage of environmental reserves accounted for by associated sites	52.00%	'	'	'
Number of sites indemnified by third party	8	'	'	'
Number of sites not indemnified by third party	66	'	'	'
Occidental-operated sites	'	'	'	'
Environmental remediation reserves	'	'	'	'
Number of Sites	20	22	22	'
Reserve Balance	118	123	120	'
Number of sites with significant environmental remediation reserves	4	'	'	'
Percentage of environmental reserves accounted for by associated sites	61.00%	'	'	'
Closed or non-operated Occidental sites	'	'	'	'
Environmental remediation reserves	'	'	'	'
Number of Sites	32	29	29	'
Reserve Balance	$104	$83	$89	'
Number of sites with significant environmental remediation reserves	4	'	'	'
Percentage of environmental reserves accounted for by associated sites	64.00%	'	'	'

ENVIRONMENTAL_LIABILITIES_AND_3

ENVIRONMENTAL LIABILITIES AND EXPENDITURES (Details 2) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Environmental reserve activity	'	'	'
Balance - Beginning of Year	$344	$360	$366
Remediation expenses and interest accretion	60	56	53
Changes from acquisitions/dispositions	'	'	14
Payments	-74	-72	-73
Balance - End of Year	$330	$344	$360

LAWSUITS_CLAIMS_COMMITMENTS_AN1

LAWSUITS, CLAIMS, COMMITMENTS AND CONTINGENCIES (Details) (USD $)	Dec. 31, 2013
In Billions, unless otherwise specified
Long term purchase and contractual obligations	'
Purchase obligations	'
Total purchase obligations	$10
Purchase obligations, due in fiscal year 2014	3
Purchase obligations, due in fiscal year 2015	1.7
Purchase obligations, due in fiscal year 2016	1
Purchase obligations, due in fiscal year 2017	0.6
Purchase obligations, due in fiscal year 2018	0.8
Capital Additions	'
Purchase obligations	'
Commitments for major fixed and determinable capital expenditures during 2014 and thereafter	$2.10

DOMESTIC_AND_FOREIGN_INCOME_TA2

DOMESTIC AND FOREIGN INCOME TAXES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Domestic and foreign components of income from continuing operations before domestic and foreign income taxes	'	'	'
Income from continuing operations before income taxes, Domestic	$4,930,000,000	$2,117,000,000	$4,806,000,000
Income from continuing operations before income taxes, Foreign	4,747,000,000	5,636,000,000	6,035,000,000
Income from continuing operations before income taxes, Total	9,677,000,000	7,753,000,000	10,841,000,000
Provisions (credits) for domestic and foreign income taxes on continuing operations	'	'	'
Current United States Federal tax expense (benefit)	361,000,000	-401,000,000	320,000,000
Current State and Local tax expense (benefit)	37,000,000	8,000,000	88,000,000
Current Foreign tax expense (benefit)	2,170,000,000	2,383,000,000	2,357,000,000
Current Total tax expense (benefit)	2,568,000,000	1,990,000,000	2,765,000,000
Deferred United States Federal tax expense (benefit)	1,145,000,000	1,046,000,000	1,340,000,000
Deferred State and Local tax expense (benefit)	59,000,000	41,000,000	47,000,000
Deferred Foreign tax expense (benefit)	-17,000,000	41,000,000	49,000,000
Deferred Total tax expense (benefit)	1,187,000,000	1,128,000,000	1,436,000,000
United States Federal Total tax expense (benefit)	1,506,000,000	645,000,000	1,660,000,000
State and Local Total tax expense (benefit)	96,000,000	49,000,000	135,000,000
Foreign Total tax expense (benefit)	2,153,000,000	2,424,000,000	2,406,000,000
Total tax expense (benefit)	3,755,000,000	3,118,000,000	4,201,000,000
Reconciliation of the United States federal statutory income tax rate to Occidental's worldwide effective tax rate on income from continuing operations	'	'	'
United States federal statutory tax rate (as a percent)	35.00%	35.00%	35.00%
Operations outside the United States (as a percent)	4.00%	5.00%	4.00%
State income taxes, net of federal benefit (as a percent)	1.00%	1.00%	1.00%
Other (as a percent)	-1.00%	-1.00%	-1.00%
Worldwide effective tax rate (as a percent)	39.00%	40.00%	39.00%
Deferred Tax Assets and Liabilities	'	'	'
Deferred Tax Assets, environmental reserves	121,000,000	126,000,000	'
Deferred Tax Assets, postretirement benefit accruals	376,000,000	413,000,000	'
Deferred Tax Assets, deferred compensation and benefits	222,000,000	278,000,000	'
Deferred Tax Assets, asset retirement obligations	407,000,000	367,000,000	'
Deferred Tax Assets, foreign tax credit carryforwards	1,091,000,000	1,277,000,000	'
Deferred Tax Assets, Other tax credit carryforwards	'	195,000,000	'
Deferred tax Assets, federal benefit of state income taxes	136,000,000	89,000,000	'
Deferred Tax Assets, all other	344,000,000	334,000,000	'
Deferred Tax Assets, subtotal	2,697,000,000	3,079,000,000	'
Deferred Tax Assets, valuation allowance	-1,074,000,000	-1,040,000,000	'
Deferred Tax Assets, total deferred taxes	1,623,000,000	2,039,000,000	'
Deferred Tax Liabilities, property, plant and equipment differences	8,363,000,000	7,316,000,000	'
Deferred Tax Liabilities, equity investments, partnerships and foreign subsidiaries	225,000,000	351,000,000	'
Deferred Tax Liabilities, all other	82,000,000	161,000,000	'
Deferred Tax Liabilities, total deferred taxes	8,670,000,000	7,828,000,000	'
Deferred tax assets, current	150,000,000	250,000,000	'
Unremitted earnings of certain consolidated foreign subsidiaries	10,600,000,000	'	'
Deferred tax liability not recognized, indefinitely reinvested foreign earnings	134,000,000	'	'
Discontinued operations income tax charges (benefits)	9,000,000	7,000,000	86,000,000
Credit to additional paid-in capital, excess tax benefit from the exercise of certain stock-based compensation awards	6,000,000	8,000,000	14,000,000
Unrecognized tax benefits included in deferred credits and other liabilities - other that would affect effective tax rate	61,000,000	'	'
Reconciliation of unrecognized tax benefits	'	'	'
Balance, at beginning of period	76,000,000	67,000,000	'
Additions based on tax positions related to the current year	'	16,000,000	'
Reductions based on tax positions related to prior years and settlements	-15,000,000	-7,000,000	'
Balance, at end of period	$61,000,000	$76,000,000	$67,000,000

STOCKHOLDERS_EQUITY_Details

STOCKHOLDERS' EQUITY (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Feb. 28, 2014
				Subsequent event
Common stock issuances	'	'	'	'
Balance at the beginning of the year	888,801,436	886,809,000	885,275,000	'
Issued	826,000	1,746,000	1,302,000	'
Options exercised and other, net	292,000	246,000	232,000	'
Balance at the end of the year	889,919,058	888,801,436	886,809,000	'
TREASURY STOCK	'	'	'	'
Share repurchase program, increase in authorized shares	'	'	'	30,000,000
Share repurchase program, authorized shares	95,000,000	'	'	'
TREASURY STOCK	'	'	'	'
Shares purchased under share repurchase program	10,300,000	7,200,000	'	'
Share repurchase program, average cost per share of shares repurchased during period	$94.42	$77.98	'	'
Treasury stock, shares	93,928,179	83,287,187	75,800,000	'
NONREDEEMABLE PREFERRED STOCK	'	'	'	'
Preferred stock, authorized shares	50,000,000	50,000,000	50,000,000	'
Preferred stock, par value	$1	$1	$1	'
Preferred stock, outstanding shares	0	0	0	'
Basic EPS	'	'	'	'
Income from continuing operations	$5,922	$4,635	$6,640	'
Discontinued operations, net	-19	-37	131	'
NET INCOME	5,903	4,598	6,771	'
Less: Net income allocated to participating securities	-13	-8	-11	'
Net income, net of participating securities	5,890	4,590	6,760	'
Weighted average number of basic shares	804,100,000	809,300,000	812,100,000	'
Basic EPS (in dollars per share)	$7.33	$5.67	$8.32	'
Diluted EPS	'	'	'	'
Net income, net of participating securities	5,890	4,590	6,760	'
Weighted average number of basic shares	804,100,000	809,300,000	812,100,000	'
Dilutive securities (in shares)	500,000	700,000	800,000	'
Total diluted weighted average common shares	804,600,000	810,000,000	812,900,000	'
Diluted EPS (in dollars per share)	$7.32	$5.67	$8.32	'
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)	'	'	'	'
Foreign currency translation adjustments	-5	-34	'	'
Unrealized losses on derivatives	-14	-7	1	'
Pension and post-retirement adjustments	-284	-461	'	'
Accumulated other comprehensive income (loss)	($303)	($502)	'	'

STOCKBASED_INCENTIVE_PLANS_Det

STOCK-BASED INCENTIVE PLANS (Details) (USD $)	1 Months Ended			12 Months Ended
	Jul. 31, 2013	Jul. 31, 2012	Jul. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation Arrangement by Share-based Payment Award	'	'	'	'	'	'
Aggregate number of shares authorized for issuance	'	'	'	66,000,000	'	'
Cumulative shares issued during the period	'	'	'	16,000,000	'	'
Maximum shares available for future issuance	'	'	'	20,000,000	'	'
Number of shares counted for each share covered by an award in determining the number of shares that are available for future awards	'	'	'	3	'	'
Number of times, as applicable, shares available for future awards may increase by shares that fail to vest, or are forfeited or canceled, or correspond to the portion of any stock-based awards settled in cash	'	'	'	3	'	'
Restricted stock granted to non-employee directors	'	'	'	37,100	'	'
Certain stock-based incentive amounts	'	'	'	'	'	'
Compensation expense (in dollars)	'	'	'	$152,000,000	$78,000,000	$110,000,000
Income tax benefit recognized in the income statement (in dollars)	'	'	'	55,000,000	29,000,000	40,000,000
Intrinsic value of options and stock-settled SARs exercised (in dollars)	'	'	'	24,000,000	18,000,000	21,000,000
Cash paid	'	'	'	96,000,000	83,000,000	124,000,000
Fair value of RSUs and TSRIs vested during the year	'	'	'	83,000,000	28,000,000	53,000,000
Unrecognized compensation expense	'	'	'	205,000,000	'	'
Weighted-average period over which unrecognized compensation expense is expected to be recognized	'	'	'	'2 years	'	'
RSUs	'	'	'	'	'	'
Stock-Based Awards	'	'	'	'	'	'
Number of anniversaries for performance objectives to be satisfied	'	'	'	7	'	'
Award vesting period	'	'	'	'2 years	'	'
RSUs | Minimum	'	'	'	'	'	'
Stock-Based Awards	'	'	'	'	'	'
Award vesting period	'	'	'	'2 years	'2 years	'2 years
RSUs | Maximum	'	'	'	'	'	'
Stock-Based Awards	'	'	'	'	'	'
Award vesting period	'	'	'	'3 years	'3 years	'3 years
Cliff vested RSU's | Minimum	'	'	'	'	'	'
Certain stock-based incentive amounts	'	'	'	'	'	'
Weighted-average period over which unrecognized compensation expense is expected to be recognized	'	'	'	'2 years	'2 years	'2 years
Cliff vested RSU's | Maximum	'	'	'	'	'	'
Certain stock-based incentive amounts	'	'	'	'	'	'
Weighted-average period over which unrecognized compensation expense is expected to be recognized	'	'	'	'3 years	'3 years	'3 years
Cash-Settled RSUs	'	'	'	'	'	'
Roll-forward of stock awards other than options and SARS.	'	'	'	'	'	'
Unvested, beginning of period (in shares)	'	'	'	1,332,000	'	'
Granted (in shares)	'	'	'	785,000	'	'
Vested (in shares)	'	'	'	-613,000	'	'
Forfeitures (in shares)	'	'	'	-73,000	'	'
Unvested, end of period (in shares)	'	'	'	1,431,000	1,332,000	'
Stock awards other than options and SARs, weighted-average grant-date fair value (in dollars per share)	'	'	'	'	'	'
Unvested, beginning of period, weighted-average grant-date fair value (in dollars per share)	'	'	'	$90.27	'	'
Granted, weighted-average grant-date fair value (in dollars per share)	'	'	'	$89.70	$84.38	$104.74
Vested, weighted-average grant-date fair value (in dollars per share)	'	'	'	$89.89	'	'
Forfeitures, weighted-average grant-date fair value (in dollars per share)	'	'	'	$90.26	'	'
Unvested, end of period, weighted-average grant-date fair value (in dollars per share)	'	'	'	$90.12	$90.27	'
Stock-Settled RSUs	'	'	'	'	'	'
Roll-forward of stock awards other than options and SARS.	'	'	'	'	'	'
Unvested, beginning of period (in shares)	'	'	'	1,375,000	'	'
Granted (in shares)	'	'	'	793,000	'	'
Vested (in shares)	'	'	'	-438,000	'	'
Forfeitures (in shares)	'	'	'	-123,000	'	'
Unvested, end of period (in shares)	'	'	'	1,607,000	1,375,000	'
Stock awards other than options and SARs, weighted-average grant-date fair value (in dollars per share)	'	'	'	'	'	'
Unvested, beginning of period, weighted-average grant-date fair value (in dollars per share)	'	'	'	$88.23	'	'
Granted, weighted-average grant-date fair value (in dollars per share)	'	'	'	$90.35	$84.81	$102.97
Vested, weighted-average grant-date fair value (in dollars per share)	'	'	'	$84.51	'	'
Forfeitures, weighted-average grant-date fair value (in dollars per share)	'	'	'	$88.59	'	'
Unvested, end of period, weighted-average grant-date fair value (in dollars per share)	'	'	'	$90.26	$88.23	'
Cash-settled SARs	'	'	'	'	'	'
Option and SAR transactions	'	'	'	'	'	'
Beginning balance (in shares)	'	'	'	494,000	'	'
Exercised (in shares)	'	'	'	-142,000	'	'
Ending balance (in shares)	'	'	'	352,000	'	'
Exercisable, end of period (in shares)	'	'	'	352,000	'	'
Option and SAR transactions	'	'	'	'	'	'
Beginning balance, weighted average exercise price (in dollars per share)	'	'	'	$24.66	'	'
Exercised, weighted average exercise price (in dollars per share)	'	'	'	$24.66	'	'
Ending balance, weighted average exercise price (in dollars per share)	'	'	'	$24.66	'	'
Exercisable, end of period, weighted average exercise price (in dollars per share)	'	'	'	$24.66	'	'
Ending balance, weighted average remaining contractual term	'	'	'	'6 months	'	'
Exercisable, end of period, weighted average remaining contractual term	'	'	'	'6 months	'	'
Ending balance, aggregate intrinsic value (in dollars)	'	'	'	24,783,000	'	'
Exercisable, end of period, aggregate intrinsic value (in dollars)	'	'	'	24,783,000	'	'
TSRIs	'	'	'	'	'	'
Stock-Based Awards	'	'	'	'	'	'
Award vesting period	'	'	'	'3 years	'	'
Roll-forward of stock awards other than options and SARS.	'	'	'	'	'	'
Unvested, beginning of period (in shares)	'	'	'	1,930,000	'	'
Granted (in shares)	'	'	'	135,000	'	'
Vested (in shares)	'	'	'	-1,143,000	'	'
Forfeitures (in shares)	'	'	'	-90,000	'	'
Unvested, end of period (in shares)	'	'	'	832,000	1,930,000	'
Stock awards other than options and SARs, weighted-average grant-date fair value (in dollars per share)	'	'	'	'	'	'
Unvested, beginning of period, weighted-average grant-date fair value (in dollars per share)	'	'	'	$80.39	'	'
Granted, weighted-average grant-date fair value (in dollars per share)	'	'	'	$91.97	$84.57	$102.97
Vested, weighted-average grant-date fair value (in dollars per share)	'	'	'	$72.44	'	'
Forfeitures, weighted-average grant-date fair value (in dollars per share)	'	'	'	$87.05	'	'
Unvested, end of period, weighted-average grant-date fair value (in dollars per share)	'	'	'	$92.49	$80.39	'
Grant-date assumptions used in the Monte Carlo simulation models	'	'	'	'	'	'
Risk-free interest rate (as a percent)	'	'	'	0.60%	0.40%	0.60%
Dividend yield (as a percent)	'	'	'	2.80%	2.60%	1.80%
Volatility factor (as a percent)	'	'	'	30.00%	34.00%	33.00%
Expected life	'	'	'	'3 years	'3 years	'3 years
Other disclosures	'	'	'	'	'	'
Performance-based awards settled in stock (as a percent)	100.00%	100.00%	50.00%	'	'	'
Performance-based awards settled for cash (as a percent)	'	'	50.00%	'	'	'
TSRIs | Minimum	'	'	'	'	'	'
Other disclosures	'	'	'	'	'	'
Payouts for Performance-based awards granted (as a percent)	0.00%	0.00%	0.00%	'	'	'
TSRIs | Maximum	'	'	'	'	'	'
Other disclosures	'	'	'	'	'	'
Payouts for Performance-based awards granted (as a percent)	150.00%	100.00%	100.00%	'	'	'
Stock-settled SARs and Options	'	'	'	'	'	'
Stock-Based Awards	'	'	'	'	'	'
Award vesting period	'	'	'	'3 years	'	'
Option and SAR transactions	'	'	'	'	'	'
Beginning balance (in shares)	'	'	'	537,000	'	'
Exercised (in shares)	'	'	'	-391,000	'	'
Forfeitures (in shares)	'	'	'	-1,000	'	'
Ending balance (in shares)	'	'	'	145,000	'	'
Exercisable, end of period (in shares)	'	'	'	145,000	'	'
Option and SAR transactions	'	'	'	'	'	'
Beginning balance, weighted average exercise price (in dollars per share)	'	'	'	$31.88	'	'
Exercised, weighted average exercise price (in dollars per share)	'	'	'	$28.12	'	'
Forfeitures, weighted average exercise price (in dollars per share)	'	'	'	$15.57	'	'
Ending balance, weighted average exercise price (in dollars per share)	'	'	'	$42.11	'	'
Exercisable, end of period, weighted average exercise price (in dollars per share)	'	'	'	$42.11	'	'
Ending balance, weighted average remaining contractual term	'	'	'	'1 year 10 months 24 days	'	'
Exercisable, end of period, weighted average remaining contractual term	'	'	'	'1 year 10 months 24 days	'	'
Ending balance, aggregate intrinsic value (in dollars)	'	'	'	7,701,000	'	'
Exercisable, end of period, aggregate intrinsic value (in dollars)	'	'	'	$7,701,000	'	'
Options and SARs | Minimum	'	'	'	'	'	'
Stock-Based Awards	'	'	'	'	'	'
Term of award	'	'	'	'	'3 years	'
Options and SARs | Maximum	'	'	'	'	'	'
Stock-Based Awards	'	'	'	'	'	'
Term of award	'	'	'	'	'10 years	'
Other awards granted in 2013	'	'	'	'	'	'
Stock-Based Awards	'	'	'	'	'	'
Award vesting period	'	'	'	'3 years	'	'
Roll-forward of stock awards other than options and SARS.	'	'	'	'	'	'
Granted (in shares)	'	'	'	160,000	'	'
Stock awards other than options and SARs, weighted-average grant-date fair value (in dollars per share)	'	'	'	'	'	'
Granted, weighted-average grant-date fair value (in dollars per share)	'	'	'	$80.98	'	'
Other disclosures	'	'	'	'	'	'
Performance-based awards settled in stock (as a percent)	'	'	'	100.00%	'	'
Other awards granted in 2013 | Minimum	'	'	'	'	'	'
Other disclosures	'	'	'	'	'	'
Payouts for Performance-based awards granted (as a percent)	'	'	'	0.00%	'	'
Other awards granted in 2013 | Maximum	'	'	'	'	'	'
Other disclosures	'	'	'	'	'	'
Payouts for Performance-based awards granted (as a percent)	'	'	'	200.00%	'	'

RETIREMENT_AND_POSTRETIREMENT_2

RETIREMENT AND POSTRETIREMENT BENEFIT PLANS (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
DEFINED CONTRIBUTION PLANS	'	'	'
Accrued liabilities for the supplemental retirement plan	$166	$145	'
Expenses under provisions of defined contribution and supplemental retirement plans	140	137	110
Postretirement and Other Benefit Plans Disclosure	'	'	'
Total benefit costs including postretirement costs	229	218	194
AOCI included the following after-tax balances	'	'	'
AOCI after-tax balances	284	461	'
Pension Benefit	'	'	'
Amounts recognized in the consolidated balance sheets	'	'	'
Other assets	104	24	'
Accrued liabilities	-6	-4	'
Deferred credits and other liabilities - other	-83	-136	'
Amounts recognized in the consolidated balance sheets, total	15	-116	'
AOCI included the following after-tax balances	'	'	'
Net loss	66	134	'
Prior service cost	1	1	'
AOCI after-tax balances	67	135	'
Changes in the benefit obligation:	'	'	'
Benefit obligation - beginning of year	615	592	'
Service cost - benefits earned during the period	13	13	12
Interest cost on projected benefit obligation	24	27	29
Actuarial (gain) loss	-35	46	'
Foreign currency exchange rate (gain) loss	-5	2	'
Benefits paid	-54	-57	'
Settlements	-35	-8	'
Benefit obligation - end of year	523	615	592
Changes in plan assets:	'	'	'
Fair value of plan assets - beginning of year	499	475	'
Actual return on plan assets	88	61	'
Foreign currency exchange rate loss	'	-3	'
Employer contributions	29	31	'
Benefits paid	-54	-57	'
Settlements	-24	-8	'
Fair value of plan assets - end of year	538	499	475
Funded/(Unfunded) status:	15	-116	'
Pension plans with accumulated benefit obligations in excess of plan assets	'	'	'
Pension plans with accumulated benefit obligations in excess of plan assets, projected benefit obligation	122	305	'
Pension plans with accumulated benefit obligations in excess of plan assets, accumulated benefit obligation	112	278	'
Pension plans with accumulated benefit obligations in excess of plan assets, fair value of plan assets	39	171	'
Pension plans with plan assets in excess of accumulated benefit obligations	'	'	'
Pension plans with plan assets in excess of accumulated benefit obligations, projected benefit obligation	401	310	'
Pension plans with plan assets in excess of accumulated benefit obligations, accumulated benefit obligation	386	305	'
Pension plans with plan assets in excess of accumulated benefit obligations, fair value of plan assets	499	328	'
Net periodic benefit costs:	'	'	'
Service cost - benefits earned during the period	13	13	12
Interest cost on projected benefit obligation	24	27	29
Expected return on plan assets	-31	-31	-33
Recognized actuarial loss	19	19	13
Other costs and adjustments	-13	17	'
Net periodic benefit cost	12	45	21
Amounts that will be amortized from accumulated other comprehensive income (Loss) in next fiscal year	'	'	'
Estimated net loss that will be amortized from AOCI into net periodic benefit cost over the next fiscal year	6	'	'
Estimated prior service cost that will be amortized from AOCI into net periodic benefit cost over the next fiscal year	0	'	'
Benefit Obligation Assumptions:	'	'	'
Discount rate (as a percent)	4.45%	3.59%	'
Rate of compensation increase (as a percent)	4.00%	4.00%	'
Net Periodic Benefit Cost Assumptions:	'	'	'
Discount rate (as a percent)	3.59%	4.12%	'
Assumed long tem rate of return on assets in excess of inflation (as a percent)	6.50%	6.50%	'
Rate of compensation increase (as a percent)	4.00%	4.00%	'
Domestic Pension Benefits	'	'	'
Postretirement and Other Benefit Plans Disclosure	'	'	'
Number of employees accruing benefits under defined benefit plans	1,000	'	'
Foreign Pension Plans	'	'	'
Postretirement and Other Benefit Plans Disclosure	'	'	'
Number of employees accruing benefits under defined benefit plans	1,500	'	'
Net Periodic Benefit Cost Assumptions:	'	'	'
Assumed long tem rate of return on assets in excess of inflation (as a percent)	6.50%	6.50%	'
Foreign Pension Plans | High end of range	'	'	'
Net Periodic Benefit Cost Assumptions:	'	'	'
Discount rate (as a percent)	10.00%	10.00%	'
Rate of compensation increase (as a percent)	10.00%	'	'
Foreign Pension Plans | Low end of range	'	'	'
Net Periodic Benefit Cost Assumptions:	'	'	'
Discount rate (as a percent)	1.50%	1.50%	'
Rate of compensation increase (as a percent)	1.50%	'	'
Postretirement Benefit	'	'	'
Amounts recognized in the consolidated balance sheets	'	'	'
Accrued liabilities	-58	-59	'
Deferred credits and other liabilities - other	-958	-1,068	'
Amounts recognized in the consolidated balance sheets, total	-1,016	-1,127	'
AOCI included the following after-tax balances	'	'	'
Net loss	225	324	'
Prior service cost	2	2	'
AOCI after-tax balances	227	326	'
Changes in the benefit obligation:	'	'	'
Benefit obligation - beginning of year	1,127	1,092	'
Service cost - benefits earned during the period	29	25	22
Interest cost on projected benefit obligation	43	42	45
Actuarial (gain) loss	-126	26	'
Benefits paid	-57	-58	'
Benefit obligation - end of year	1,016	1,127	1,092
Changes in plan assets:	'	'	'
Funded/(Unfunded) status:	-1,016	-1,127	'
Net periodic benefit costs:	'	'	'
Service cost - benefits earned during the period	29	25	22
Interest cost on projected benefit obligation	43	42	45
Recognized actuarial loss	38	37	31
Other costs and adjustments	1	1	1
Net periodic benefit cost	111	105	99
Amounts that will be amortized from accumulated other comprehensive income (Loss) in next fiscal year	'	'	'
Estimated net loss that will be amortized from AOCI into net periodic benefit cost over the next fiscal year	24	'	'
Estimated prior service cost that will be amortized from AOCI into net periodic benefit cost over the next fiscal year	1	'	'
Benefit Obligation Assumptions:	'	'	'
Discount rate (as a percent)	4.75%	3.89%	'
Net Periodic Benefit Cost Assumptions:	'	'	'
Discount rate (as a percent)	3.89%	4.12%	'
Assumed health care cost trend rates	'	'	'
Consumer Price Index (CPI) increase (as a percent)	2.36%	2.39%	'
Projected annual rates of health care cost trend rates (as a percent)	8.00%	'	'
Projected ultimate health care cost trend rates (as a percent)	5.00%	'	'
Year the projected health care cost trend rate reaches ultimate trend rate	'2025	'	'
Increase (decrease) in projected annual rates of health care cost trend rates (as a percent)	-0.25%	'	'
Effect of 1-percent increase or a 1-percent decrease in these assumed health care cost trend rates	'	'	'
Effect of 1-percent increase in assumed health care cost trend rates on postretirement benefit obligation	38	'	'
Effect of 1-percent decrease in assumed health care cost trend rates on postretirement benefit obligation	$32	'	'

RETIREMENT_AND_POSTRETIREMENT_3

RETIREMENT AND POSTRETIREMENT BENEFIT PLANS (Details 2) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	$538	$499	$475
Estimated future benefit payments	'	'	'
2014	46	'	'
2015	44	'	'
2016	49	'	'
2017	41	'	'
2018	40	'	'
2019 - 2023	233	'	'
Expected contribution to defined benefit pension plans during 2014	6	'	'
Postretirement Benefits	'	'	'
Estimated future benefit payments	'	'	'
2014	59	'	'
2015	60	'	'
2016	61	'	'
2017	62	'	'
2018	63	'	'
2019 - 2023	335	'	'
Debt securities	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Target allocation of plan assets (as a percent)	35.00%	'	'
Pension Plan Assets - Gross | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	543	505	'
U.S. government securities | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	16	24	'
Common and preferred stocks	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Target allocation of plan assets (as a percent)	65.00%	'	'
Common and preferred stocks | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	201	146	'
Corporate bonds | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	84	83	'
Common/collective trusts | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	19	11	'
Bond funds | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	64	84	'
Blend funds | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	105	106	'
Value and growth funds | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	6	5	'
Other | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	48	46	'
Net Payables | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	5	6	'
Level 1 | Pension Plan Assets - Gross | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	392	365	'
Level 1 | U.S. government securities | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	16	24	'
Level 1 | Common and preferred stocks | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	201	146	'
Level 1 | Bond funds | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	64	84	'
Level 1 | Blend funds | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	105	106	'
Level 1 | Value and growth funds | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	6	5	'
Level 2 | Pension Plan Assets - Gross | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	140	129	'
Level 2 | Corporate bonds | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	84	83	'
Level 2 | Common/collective trusts | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	19	11	'
Level 2 | Other | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	37	35	'
Level 3 | Pension Plan Assets - Gross | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	11	11	'
Level 3 | Other | Pension Benefit	'	'	'
Defined Benefit Plan Disclosure	'	'	'
Fair value of plan assets	$11	$11	'

INVESTMENTS_AND_RELATEDPARTY_T2

INVESTMENTS AND RELATED-PARTY TRANSACTIONS (Details) (USD $)	1 Months Ended	12 Months Ended
	Oct. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
EQUITY INVESTMENTS	'	'	'	'
Pre-tax gain on sale of equity investment	'	1,175,000,000	'	'
RELATED-PARTY TRANSACTIONS	'	'	'	'
Sales to related parties	'	663,000,000	419,000,000	392,000,000
Purchases from related parties	'	'	8,000,000	10,000,000
Services to related parties	'	30,000,000	17,000,000	10,000,000
Advances and amounts due from related parties	'	67,000,000	25,000,000	32,000,000
Amounts due to related parties	'	3,000,000	129,000,000	21,000,000
Equity Method Investments	'	'	'	'
Equity method investment amounts	'	1,500,000,000	1,900,000,000	'
Equity investments dividends paid	'	447,000,000	526,000,000	349,000,000
Cumulative undistributed earnings of equity-method investees	'	65,000,000	'	'
Excess of investments in equity investees over the underlying equity in net assets	'	900,000,000	'	'
Excess of investments in equity investees over the underlying equity in net assets, which represents goodwill	'	750,000,000	'	'
Equity-method investments financial information summarized by Income Statement line item	'	'	'	'
Revenues	'	3,373,000,000	2,667,000,000	2,439,000,000
Costs and expenses	'	2,987,000,000	2,310,000,000	2,046,000,000
Net income	'	386,000,000	357,000,000	393,000,000
Equity-method investments financial information summarized by Balance Sheet line item	'	'	'	'
Current assets	'	1,813,000,000	2,242,000,000	'
Non-current assets	'	4,412,000,000	5,449,000,000	'
Current liabilities	'	1,308,000,000	1,799,000,000	'
Long-term debt	'	2,506,000,000	2,833,000,000	'
Other non-current liabilities	'	163,000,000	248,000,000	'
Stockholders' equity	'	2,248,000,000	2,811,000,000	'
General Partner of Plains All American Pipeline,L.P	'	'	'	'
EQUITY INVESTMENTS	'	'	'	'
Ownership interest (as a percent)	'	25.00%	'	'
Proceed from sale of investment	1,400,000,000	'	'	'
Pre-tax gain on sale of equity investment	$1,000,000,000	'	'	'
RELATED-PARTY TRANSACTIONS	'	'	'	'
Sales to related party (as a percent)	'	72.00%	80.00%	76.00%
Dolphin Energy	'	'	'	'
EQUITY INVESTMENTS	'	'	'	'
Equity method investment ownership percentage	'	24.50%	'	'
Ownership interest (as a percent)	'	24.50%	'	'
Number of separate economic interests comprising investment in unconsolidated affiliate	'	2	'	'

FAIR_VALUE_MEASUREMENTS_Detail

FAIR VALUE MEASUREMENTS (Details) (USD $)

12 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Non recurring

Non recurring

Non recurring

Level 1

Level 1

Level 2

Level 2

Netting and Collateral

Netting and Collateral

Total Fair Value

Total Fair Value

Minimum

Assets:

'

'

'

'

'

'

'

'

'

'

'

'

'

Commodity derivatives

'

'

$185

$107

$195

$312

($329)

($301)

$51

$118

'

'

'

Liabilities:

'

'

'

'

'

'

'

'

'

'

'

'

'

Commodity derivatives

'

'

199

99

223

398

-364

-371

58

126

'

'

'

Asset impairments and related items

$621

$1,751

'

'

'

'

'

'

'

'

$0.60

$1,700

'

Percentage of pre-tax impairment charges related to natural gas properties

'

'

'

'

'

'

'

'

'

'

'

'

90.00%

Average period over which natural gas properties were acquired

'

'

'

'

'

'

'

'

'

'

'

'

'5 years

INDUSTRY_SEGMENTS_AND_GEOGRAPH2

INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

31-May-13

Dec. 31, 2013

Oct. 31, 2013

Dec. 31, 2013

segment

segment

segment

Total Foreign

Total Foreign

Total Foreign

Colombia

Colombia

Colombia

Libya

Oil and Gas

Oil and Gas

Oil and Gas

Oil and Gas

Oil and Gas

Chemical

Chemical

Chemical

Chemical

Chemical

Chemical

Chemical

Chemical

Chemical

Midstream and Marketing

Midstream and Marketing

Midstream and Marketing

Midstream and Marketing

Midstream and Marketing

Midstream and Marketing

Midstream and Marketing

Midstream and Marketing

Midstream and Marketing

Operating segments

Operating segments

Operating segments

Operating segments

Operating segments

Operating segments

Operating segments

Operating segments

Operating segments

Corporate and Eliminations

Corporate and Eliminations

Corporate and Eliminations

Brazilian chemical facility

Brazilian chemical facility

Plains Pipeline and other items

Plains Pipeline and other items

Oil

Oil

Oil

Basic Chemicals

Basic Chemicals

Basic Chemicals

Vinyls

Vinyls

Vinyls

Other Chemicals

Other Chemicals

Other Chemicals

Gas Processing

Gas Processing

Gas Processing

Power

Power

Power

Marketing, Trading, Transportation and other

Marketing, Trading, Transportation and other

Marketing, Trading, Transportation and other

Oil and Gas

Oil and Gas

Oil and Gas

Chemical

Chemical

Chemical

Midstream and Marketing

Midstream and Marketing

Midstream and Marketing

INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS

'

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'

Number of operating segments

3

3

3

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Segment Information

'

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Net sales

$24,455

$24,172

$23,939

$8,446

$8,813

$8,899

$1,022

$1,027

$1,054

'

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'

'

'

'

'

'

$19,132

$18,906

$18,419

$4,673

$4,580

$4,815

$1,538

$1,399

$1,447

($888)

($713)

($742)

'

'

'

'

Pretax operating profit (loss)

9,677

7,753

10,841

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,894

7,095

10,241

743

720

861

1,573

439

448

-533

-501

-709

'

'

'

'

Income taxes

-3,755

-3,118

-4,201

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-3,755

-3,118

-4,201

'

'

'

'

Discontinued operations, net

-19

-37

131

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-19

-37

131

'

'

'

'

Net income (loss)

5,903

4,598

6,771

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,894

7,095

10,241

743

720

861

1,573

439

448

-4,307

-3,656

-4,779

'

'

'

'

Investments in unconsolidated entities

1,459

1,894

2,072

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

108

113

128

34

108

121

1,307

1,662

1,812

10

11

11

'

'

'

'

Property, plant and equipment additions, net

9,188

10,350

7,604

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7,106

8,282

6,192

435

365

241

1,482

1,612

1,120

165

91

51

'

'

'

'

Depreciation, depletion and amortization

5,347

4,511

3,591

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,753

3,933

3,064

346

345

330

212

206

173

36

27

24

'

'

'

'

Total assets

69,443

64,210

60,044

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

46,213

44,004

38,967

3,947

3,854

3,754

14,374

12,762

11,962

4,909

3,590

5,361

'

'

'

'

Product revenue to net sales (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

89.00%

90.00%

87.00%

55.00%

57.00%

58.00%

42.00%

40.00%

39.00%

3.00%

3.00%

3.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sales revenues for businesses as a percentage of total sales revenues

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

51.00%

59.00%

64.00%

36.00%

27.00%

35.00%

13.00%

14.00%

1.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset impairments and related items

621

1,751

'

'

'

'

'

'

'

'

607

1,700

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Capitalized and suspended exploration costs written off

'

'

'

'

'

'

'

'

'

35

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Colombian net worth tax

'

'

'

'

'

'

'

'

29

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pre-tax gain for sale of interest in Colombian pipeline

'

'

'

'

'

'

'

'

22

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Pre-tax gain on sale of investment

$1,175

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$131

$131

$1,000

$1,000

INDUSTRY_SEGMENTS_AND_GEOGRAPH3

INDUSTRY SEGMENTS AND GEOGRAPHIC AREAS (Details 2) (USD $)	3 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	Mar. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Information	'	'	'	'	'
Net sales	'	'	$24,455	$24,172	$23,939
Property, plant and equipment, net	'	'	55,821	52,064	45,684
Corporate significant items affecting earnings/Pre-tax operating profit (loss)	'	'	'	'	'
Corporate significant items affecting earnings/premium on debt extinguishments	'	-163	'	'	'
Corporate significant items affecting earnings/charge for former executives and consultants	-55	'	'	'	'
United States	'	'	'	'	'
Segment Information	'	'	'	'	'
Net sales	'	'	16,009	15,359	15,040
Property, plant and equipment, net	'	'	42,956	40,786	36,283
Total Foreign	'	'	'	'	'
Segment Information	'	'	'	'	'
Net sales	'	'	8,446	8,813	8,899
Property, plant and equipment, net	'	'	12,865	11,278	9,401
Qatar	'	'	'	'	'
Segment Information	'	'	'	'	'
Net sales	'	'	2,995	3,356	3,432
Property, plant and equipment, net	'	'	2,605	2,676	2,735
Oman	'	'	'	'	'
Segment Information	'	'	'	'	'
Net sales	'	'	2,567	2,578	2,500
Property, plant and equipment, net	'	'	2,509	2,353	2,143
Colombia	'	'	'	'	'
Segment Information	'	'	'	'	'
Net sales	'	'	1,022	1,027	1,054
Property, plant and equipment, net	'	'	1,259	1,041	854
United Arab Emirates	'	'	'	'	'
Segment Information	'	'	'	'	'
Property, plant and equipment, net	'	'	3,131	2,104	971
Other Foreign	'	'	'	'	'
Segment Information	'	'	'	'	'
Net sales	'	'	1,862	1,852	1,913
Property, plant and equipment, net	'	'	3,361	3,104	2,698
Corporate	'	'	'	'	'
Corporate significant items affecting earnings/Pre-tax operating profit (loss)	'	'	'	'	'
Corporate significant items affecting earnings/Pre-tax operating profit (loss) total	'	'	-55	-20	-163
Corporate significant items affecting earnings/Income Taxes	'	'	'	'	'
State income tax charge	'	'	'	'	-33
Tax effect of pre-tax adjustments	'	'	-179	636	50
Corporate significant items affecting earnings/Income Taxes Total	'	'	-179	636	17
Corporate | Litigation reserves	'	'	'	'	'
Corporate significant items affecting earnings/Pre-tax operating profit (loss)	'	'	'	'	'
Corporate significant items affecting earnings/Litigation reserves	'	'	'	-20	'
Corporate | Charge for former executives and consultants	'	'	'	'	'
Corporate significant items affecting earnings/Pre-tax operating profit (loss)	'	'	'	'	'
Corporate significant items affecting earnings/charge for former executives and consultants	'	'	-55	'	'
Corporate | Premium on debt extinguishments	'	'	'	'	'
Corporate significant items affecting earnings/Pre-tax operating profit (loss)	'	'	'	'	'
Corporate significant items affecting earnings/premium on debt extinguishments	'	'	'	'	($163)

Schedule_II_Valuation_and_Qual1

Schedule II - Valuation and Qualifying Accounts (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Valuation and qualifying accounts	'	'	'
Balance at Beginning of Period	$573	$558	$559
Charged to Costs and Expenses	63	113	90
Charged to Other Accounts	4	'	14
Deductions	-144	-98	-105
Balance at End of Period	496	573	558
Valuation and qualifying accounts, classified as current	101	98	100
Allowance for doubtful accounts	'	'	'
Valuation and qualifying accounts	'	'	'
Balance at Beginning of Period	16	16	19
Charged to Costs and Expenses	1	0	'
Deductions	'	'	-3
Balance at End of Period	17	16	16
Environmental	'	'	'
Valuation and qualifying accounts	'	'	'
Balance at Beginning of Period	344	360	366
Charged to Costs and Expenses	60	56	53
Charged to Other Accounts	'	'	14
Deductions	-74	-72	-73
Balance at End of Period	330	344	360
Litigation, tax and other reserves	'	'	'
Valuation and qualifying accounts	'	'	'
Balance at Beginning of Period	229	198	193
Charged to Costs and Expenses	3	57	37
Charged to Other Accounts	4	'	'
Deductions	-70	-26	-32
Balance at End of Period	$166	$229	$198