OCCIDENTAL PETROLEUM CORP /DE/ - Quarter Report: 2013 June (Form 10-Q)

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

þ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2013

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ___________ to ___________

Commission file number 1-9210

_____________________

OCCIDENTAL PETROLEUM CORPORATION

(Exact name of registrant as specified in its charter)



Delaware (State or other jurisdiction of incorporation or organization)		95-4035997 (I.R.S. Employer Identification No.)

10889 Wilshire Boulevard Los Angeles, California (Address of principal executive offices)		90024 (Zip Code)

(310) 208-8800

(Registrant’s telephone number, including area code)

_____________________

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). R Yes £ No

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

Large Accelerated FilerR Accelerated Filer£ Non-Accelerated Filer£ Smaller Reporting Company£

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

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.



	Class		Outstanding at June 30, 2013
	Common stock $.20 par value		805,763,948 shares

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

TABLE OF CONTENTS



				PAGE

Part I	Financial Information

	Item 1.	Financial Statements (unaudited)

		Consolidated Condensed Balance Sheets —
			June 30, 2013 and December 31, 2012	2

		Consolidated Condensed Statements of Income —
			Three and six months ended June 30, 2013 and 2012	4

		Consolidated Condensed Statements of Comprehensive Income —
			Three and six months ended June 30, 2013 and 2012	5

		Consolidated Condensed Statements of Cash Flows —
			Six months ended June 30, 2013 and 2012	6

		Notes to Consolidated Condensed Financial Statements		7

	Item 2.	Management’s Discussion and Analysis of Financial
			Condition and Results of Operations	18

	Item 3.	Quantitative and Qualitative Disclosures About Market Risk		27

	Item 4.	Controls and Procedures		27

Part II	Other Information

	Item 1.	Legal Proceedings		28

	Item 2.	Share Repurchase Activities		28

	Item 6.	Exhibits		29

PART I FINANCIAL INFORMATION


Item 1.	Financial Statements (unaudited)

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED CONDENSED BALANCE SHEETS

JUNE 30, 2013 AND DECEMBER 31, 2012

(Amounts in millions)



	2013		2012

ASSETS

CURRENT ASSETS

Cash and cash equivalents	$	3,069	$	1,592

Trade receivables, net	5,221		4,916

Inventories	1,340		1,344

Other current assets	1,229		1,640

Total current assets	10,859		9,492

INVESTMENTS IN UNCONSOLIDATED ENTITIES	1,808		1,894

PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation, depletion and amortization of $30,536 at June 30, 2013 and $28,032 at December 31, 2012	53,949		52,064

LONG-TERM RECEIVABLES AND OTHER ASSETS, NET	806		760

TOTAL ASSETS	$	67,422	$	64,210

The accompanying notes are an integral part of these consolidated financial statements.

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED CONDENSED BALANCE SHEETS

JUNE 30, 2013 AND DECEMBER 31, 2012

(Amounts in millions)



	2013			2012

LIABILITIES AND STOCKHOLDERS’ EQUITY

CURRENT LIABILITIES

Current maturities of long-term debt	$	600		$	600

Accounts payable	5,274			4,708

Accrued liabilities	2,331			1,966

Domestic and foreign income taxes	29			16

Total current liabilities	8,234			7,290

LONG-TERM DEBT, NET	7,026			7,023

DEFERRED CREDITS AND OTHER LIABILITIES

Deferred domestic and foreign income taxes	6,658			6,039

Other	3,654			3,810

	10,312			9,849
STOCKHOLDERS' EQUITY

Common stock, at par value	178			178

Treasury stock	(5,113		)	(5,091		)

Additional paid-in capital	7,510			7,441

Retained earnings	39,634			37,990

Accumulated other comprehensive loss	(456		)	(502		)

Total equity attributable to common stock	41,753			40,016

Noncontrolling interest	97			32

Total stockholders’ equity	41,850			40,048

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	67,422		$	64,210

The accompanying notes are an integral part of these consolidated financial statements.

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF INCOME

FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2013 AND 2012

(Amounts in millions, except per-share amounts)



	Three months ended June 30						Six months ended June 30
	2013			2012			2013			2012
REVENUES AND OTHER INCOME
Net sales	$	5,962		$	5,768		$	11,834		$	12,036
Interest, dividends and other income	28			24			63			39
Gain on sale of equity investment	131			—			131			—
	6,121			5,792			12,028			12,075
COSTS AND OTHER DEDUCTIONS
Cost of sales	3,180			3,060			6,317			6,010
Selling, general and administrative and other operating expenses	495			335			888			769
Taxes other than on income	196			167			382			341
Exploration expense	78			96			128			194
Interest and debt expense, net	30			28			64			58
	3,979			3,686			7,779			7,372

Income before income taxes and other items	2,142			2,106			4,249			4,703
Provision for domestic and foreign income taxes	(901		)	(875		)	(1,745		)	(2,014		)
Income from equity investments	86			101			182			203
Income from continuing operations	1,327			1,332			2,686			2,892
Discontinued operations, net	(5		)	(4		)	(9		)	(5		)
NET INCOME	$	1,322		$	1,328		$	2,677		$	2,887


BASIC EARNINGS PER COMMON SHARE
Income from continuing operations	$	1.65		$	1.64		$	3.33		$	3.56
Discontinued operations, net	(0.01		)	—			(0.01		)	(0.01		)
BASIC EARNINGS PER COMMON SHARE	$	1.64		$	1.64		$	3.32		$	3.55

DILUTED EARNINGS PER COMMON SHARE
Income from continuing operations	$	1.64		$	1.64		$	3.33		$	3.56
Discontinued operations, net	—			—			(0.01		)	(0.01		)
DILUTED EARNINGS PER COMMON SHARE	$	1.64		$	1.64		$	3.32		$	3.55

DIVIDENDS PER COMMON SHARE	$	0.64		$	0.54		$	1.28		$	1.08

The accompanying notes are an integral part of these consolidated financial statements.

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF COMPREHENSIVE INCOME

FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2013 AND 2012

(Amounts in millions)



	Three months ended June 30					Six months ended June 30
	2013		2012			2013			2012
Net income	$	1,322	$	1,328		$	2,677		$	2,887
Other comprehensive income (loss) items:
Foreign currency translation gains (losses)	1		(12		)	2			(8		)
Reclassification to income of realized foreign currency translation losses ^(a)	28		—			28			—
Pension and postretirement gains ^(b)	9		8			18			13
Unrealized gains (losses) on derivatives ^(c)	7		(2		)	1			12
Reclassification to income of realized losses (gains) on derivatives ^(d)	1		4			(3		)	(24		)
Other comprehensive income (loss), net of tax ^(e)	46		(2		)	46			(7		)
Comprehensive income	$	1,368	$	1,326		$	2,723		$	2,880


(a)	Included in the net gain on sale of the investment in Carbocloro, a Brazilian chemical facility.


(b)	Net of tax of $(6) and $(5) for the three months ended June 30, 2013 and 2012, respectively, and $(11) and $(8) for the six months ended June 30, 2013 and 2012.


(c)	Net of tax of $(4) and zero for the three months ended June 30, 2013 and 2012, respectively, and $(1) and $(8) for the six months ended June 30, 2013 and 2012.


(d)	Net of tax of zero and $(2) for the three months ended June 30, 2013 and 2012, respectively, and $2 and $15 for the six months ended June 30, 2013 and 2012.


(e)	There were no other comprehensive income (loss) items related to noncontrolling interests in 2013 and 2012.

The accompanying notes are an integral part of these consolidated financial statements.

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS

FOR THE SIX MONTHS ENDED JUNE 30, 2013 AND 2012

(Amounts in millions)



	2013			2012
CASH FLOW FROM OPERATING ACTIVITIES
Net income	$	2,677		$	2,887
Adjustments to reconcile net income to net cash provided by operating activities:
Discontinued operations, net	9			5
Depreciation, depletion and amortization of assets	2,562			2,172
Deferred income tax provision	635			794
Other noncash charges to income	218			109
Gain on sale of equity investment	(131		)	—
Undistributed earnings from equity investments	(31		)	(8		)
Dry hole expenses	77			166
Changes in operating assets and liabilities, net	227			(150		)
Operating cash flow from continuing operations	6,243			5,975
Operating cash flow from discontinued operations, net of taxes	(18		)	(17		)
Net cash provided by operating activities	6,225			5,958
CASH FLOW FROM INVESTING ACTIVITIES
Capital expenditures	(4,280		)	(5,125		)
Payments for purchases of assets and businesses	(226		)	(1,081		)
Sale of equity investment, net	270			—
Other, net	(63		)	44
Net cash used by investing activities	(4,299		)	(6,162		)
CASH FLOW FROM FINANCING ACTIVITIES
Proceeds from long-term debt	—			1,736
Proceeds from issuance of common stock	24			58
Purchases of treasury stock	(28		)	(152		)
Contributions from noncontrolling interest	65			—
Cash dividends paid	(517		)	(813		)
Other, net	7			4
Net cash (used) provided by financing activities	(449		)	833
Increase in cash and cash equivalents	1,477			629
Cash and cash equivalents—beginning of period	1,592			3,781
Cash and cash equivalents—end of period	$	3,069		$	4,410

The accompanying notes are an integral part of these consolidated financial statements.

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS

June 30, 2013


1.	General

In these unaudited consolidated condensed financial statements, "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 has made its disclosures in accordance with United States generally accepted accounting principles as they apply to interim reporting, and condensed or omitted, as permitted by the Securities and Exchange Commission’s rules and regulations, certain information and disclosures normally included in consolidated financial statements and the notes. These consolidated condensed financial statements should be read in conjunction with the consolidated financial statements and the notes thereto in Occidental’s Annual Report on Form 10-K for the year ended December 31, 2012.

In the opinion of Occidental’s management, the accompanying consolidated condensed financial statements contain all adjustments (consisting of normal recurring adjustments) necessary to fairly present Occidental’s consolidated financial position as of June 30, 2013, and the consolidated statements of income, comprehensive income and cash flows for the three and six months ended June 30, 2013 and 2012, as applicable. The income and cash flows for the periods ended June 30, 2013 and 2012 are not necessarily indicative of the income or cash flows to be expected for the full year.

Certain financial statements and notes for the prior year have been reclassified to conform to the 2013 presentation.


2.	Asset Acquisitions, Dispositions and Other

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.

As previously reported, Edward Djerejian was elected Chairman of the Board of Directors on May 3, 2013, replacing Dr. Ray Irani. Dr. 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 quarter. As a result of these developments and actions, Occidental recorded a $55 million pre-tax charge in the second quarter for the currently estimated costs of Dr. Irani's employment and post-employment benefits, and the termination of other employees and consulting arrangements.

Occidental owns a 50% interest in BridgeTex Pipeline Company, LLC (BridgeTex), which is a variable interest entity that Occidental consolidates. This investment is not material to Occidental's financial statements. At June 30, 2013 and December 31, 2012, the BridgeTex assets and liabilities mainly comprised property, plant and equipment and cash and cash equivalents. At June 30, 2013 and December 31, 2012, BridgeTex held approximately $93 million and $50 million, respectively, of money market funds classified as cash equivalents, which approximated fair value using Level 1 inputs.


3.	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 that are subject to a master netting or similar arrangement and qualify for net presentation, but are not offset in the consolidated balance sheet.

Reclassifications 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.


4.	Supplemental Cash Flow Information

Occidental paid United States federal, state and foreign income taxes for continuing operations of approximately $0.8 billion and $1.3 billion during the six months ended June 30, 2013 and 2012, respectively. Interest paid totaled approximately $122 million and $95 million for the six months ended June 30, 2013 and 2012, respectively.


5.	Inventories

A portion of inventories is valued under the LIFO method. The valuation of LIFO inventory for interim periods is based on Occidental’s estimates of year-end inventory levels and costs. Inventories as of June 30, 2013 and December 31, 2012 consisted of the following (in millions):



		2013			2012
Raw materials	$	75		$	70
Materials and supplies		641			612
Finished goods		725			763
		1,441			1,445
LIFO reserve		(101	)		(101	)
Total	$	1,340		$	1,344


6.	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.

The laws that require or address environmental remediation, including the Comprehensive Environmental Response, Compensation, and Liability Act (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 June 30, 2013, Occidental participated in or monitored remedial activities or proceedings at 161 sites. The following table presents Occidental’s environmental remediation reserves as of June 30, 2013, the current portion of which is included in accrued liabilities ($80 million) and the remainder in deferred credits and other liabilities — other ($247 million). The reserves are grouped as environmental remediation sites listed or proposed for listing by the United States 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.



	Number of Sites		Reserve Balance (in millions)
NPL sites		33	$	52
Third-party sites		76		74
Occidental-operated sites		22		121
Closed or non-operated Occidental sites		30		80
Total		161	$	327

As of June 30, 2013, Occidental’s environmental reserves exceeded $10 million each at 11 of the 161 sites described above, and 114 of the sites had reserves from zero to $1 million each. 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 $375 million. The status of Occidental’s involvement with the sites and related significant assumptions have not changed materially since December 31, 2012. For management’s opinion with respect to environmental matters, refer to Note 7.


7.	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 assets with respect to which third parties retain liability or indemnify Occidental for conditions that existed prior to purchase.

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 June 30, 2013 and December 31, 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 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 June 30, 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.


8.	Retirement and Postretirement Benefit Plans

The following table sets forth the components of the net periodic benefit costs for Occidental’s defined benefit pension and postretirement benefit plans for the three and six months ended June 30, 2013 and 2012 (in millions):



Three months ended June 30		2013					2012
Net Periodic Benefit Costs	Pension Benefit			Postretirement Benefit		Pension Benefit			Postretirement Benefit
Service cost	$	3		$	7	$	3		$	6
Interest cost		7			10		7			11
Expected return on plan assets		(8	)		—		(8	)		—
Recognized actuarial loss		4			10		5			9
Total	$	6		$	27	$	7		$	26



Six months ended June 30		2013					2012
Net Periodic Benefit Costs	Pension Benefit			Postretirement Benefit		Pension Benefit			Postretirement Benefit
Service cost	$	7		$	14	$	6		$	13
Interest cost		13			21		14			22
Expected return on plan assets		(16	)		—		(16	)		—
Recognized actuarial loss		8			20		10			17
Total	$	12		$	55	$	14		$	52

Occidental contributed approximately $1 million and $2 million in the three-month periods ended June 30, 2013 and 2012, and approximately $2 million and $3 million in the six-month periods ended June 30, 2013 and 2012, respectively, to its defined benefit pension plans.


9.	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 identical assets or liabilities; Level 2 — using observable inputs, such as quoted prices for similar 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 price 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:

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. 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 generally 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.

The following tables provide fair value measurement information for such assets and liabilities that are measured on a recurring basis as of June 30, 2013 and December 31, 2012 (in millions):



	Fair Value Measurements at
	June 30, 2013 Using
Description	Level 1		Level 2		Level 3		Netting and Collateral			^(a)	Total Fair Value
Assets:
Commodity derivatives	$	246	$	326	$	—	$	(476	)		$	96
Liabilities:
Commodity derivatives	$	224	$	369	$	—	$	(529	)		$	64



	Fair Value Measurements at
	December 31, 2012 Using
Description	Level 1		Level 2		Level 3		Netting and Collateral			^(a)	Total Fair Value
Assets:
Commodity derivatives	$	107	$	312	$	—	$	(301	)		$	118
Liabilities:
Commodity derivatives	$	99	$	398	$	—	$	(371	)		$	126


(a)	Represents the impact of netting assets, liabilities and collateral when a legal right of offset exists.

Fair Values — Nonrecurring

During the three months ended June 30, 2013 and 2012, Occidental did not have assets or liabilities measured at fair value on a non-recurring basis.

Other Financial Instruments

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. 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 as of June 30, 2013 and December 31, 2012, were approximately $7.8 billion and $8.2 billion, respectively, and its carrying value at each date was $7.6 billion. Occidental classifies its debt as Level 1.


10.	Derivatives

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.

Occidental uses a variety of derivative instruments, including cash-flow hedges and derivative instruments not designated as hedging instruments, to establish, as of the date of production, the price it receives and to improve realized prices for oil and gas. Occidental only occasionally hedges its oil and gas production and, when it does, 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.

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.

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 June 30, 2013 and December 31, 2012, Occidental had approximately 13 billion cubic feet and 20 billion cubic feet of natural gas held in storage, respectively. As of June 30, 2013 and December 31, 2012, Occidental had cash-flow hedges for the forecast sale, to be settled by physical delivery, of approximately 15 billion cubic feet and 20 billion cubic feet of natural gas, respectively.

The following table presents the after-tax gains and losses recognized in, and reclassified to income from, Accumulated Other Comprehensive Income (AOCI) for derivative instruments classified as cash-flow hedges for the three and six months ended June 30, 2013 and 2012 (in millions):



							Periods ended June 30
	Three months									Six Months
	2013			2012			2013			2012
Beginning Balance — AOCI	$	(17	)	$	(13	)	$	(7	)	$	1
Unrealized gains (losses) recognized in AOCI	7			(2		)	1			12
Losses reclassified to income	1			4			(3		)	(24		)
Ending Balance — AOCI	$	(9	)	$	(11	)	$	(9	)	$	(11	)

Occidental expects to reclassify an insignificant amount, based on the valuation as of June 30, 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 three months ended June 30, 2013 and 2012.

Derivatives Not Designated as Hedging Instruments

The following table summarizes Occidental’s net volumes resulting from outstanding commodity derivatives contracts not designated as hedging instruments, including both financial and physical derivative contracts as of June 30, 2013 and December 31, 2012.



	Net Outstanding Position
	Long / (Short)
Commodity	2013		2012
Oil (million barrels)	(23	)	(17	)
Natural gas (billion cubic feet)	(80	)	(217	)
Precious metals (million troy ounces)	1		1

A large majority of the volumes in the table above include contracts tied to index prices, for which there is no fair value. These contracts do not expose Occidental to changes in commodity 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 June 30, 2013 and December 31, 2012.

Occidental fulfills its short positions through its own production or by third-party purchase contracts. Subsequent to June 30, 2013, Occidental entered into purchase contracts for a substantial portion of the outstanding positions at quarter-end and has production capacity and the ability to enter into additional purchase contracts sufficient to satisfy the remaining positions.

Approximately $75 million and $88 million of net losses from derivatives not designated as hedging instruments were recognized in net sales for the three months ended June 30, 2013 and 2012, respectively. Approximately $16 million and $36 million of net losses from derivatives not designated as hedging instruments were recognized in net sales for the six months ended June 30, 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 June 30, 2013 and December 31, 2012 (in millions):



	Asset Derivatives				Liability Derivatives
June 30, 2013	Balance Sheet Location	Fair Value			Balance Sheet Location	Fair Value
Cash-flow hedges ^(a)
Commodity contracts	Other current assets	$	5		Accrued liabilities	$	1
Commodity contracts	Long-term receivables and other assets, net	—			Deferred credits and other liabilities	—
		5				1
Derivatives not designated as hedging instruments ^(a)
Commodity contracts	Other current assets	544			Accrued liabilities	573
Commodity contracts	Long-term receivables and other assets, net	23			Deferred credits and other liabilities	19
		567				592
Total gross fair value		572				593
Less: counterparty netting and cash collateral ^{(b) (d)}		(476		)		(529		)
Total net fair value of derivatives		$	96			$	64



	Asset Derivatives				Liability Derivatives
December 31, 2012	Balance Sheet Location	Fair Value			Balance Sheet Location	Fair Value
Cash-flow hedges ^(a)
Commodity contracts	Other current assets	$	11		Accrued liabilities	$	1
Commodity contracts	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
Commodity contracts	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 qualify for net presentation in the consolidated balance sheet.


(b)	As of June 30, 2013, collateral received of $37 million has been netted against derivative assets and collateral paid of $90 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 $94 million and $116 million deposited by Occidental, has not been reflected in these derivative fair value tables, but is included in the other current assets balance as of June 30, 2013 and December 31, 2012, respectively.

See Note 9 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 June 30, 2013 and December 31, 2012, Occidental had a net liability of $25 million and $34 million, respectively, which are net of collateral posted of $12 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 June 30, 2013 and December 31, 2012.


11.	Industry Segments

Occidental conducts its operations through three segments: (1) oil and gas; (2) chemical; and (3) midstream, marketing and other (midstream and marketing). The oil and gas segment explores for, develops and produces oil and condensate, natural gas liquids (NGL) 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, carbon dioxide (CO₂) and power. It also trades around its assets, including transportation and storage capacity, and trades oil, NGLs, gas and other commodities. The segment also invests in entities that conduct similar activities.

Earnings of industry segments generally 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 assets and income from the segment 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.

The following tables present Occidental’s industry segment and corporate disclosures (in millions):



						Midstream		Corporate
						and		and
	Oil and Gas		Chemical			Marketing		Eliminations				Total

Three months ended
June 30, 2013

Net sales	$	4,721	$	1,187		$	269	$	(215	)		$	5,962

Pretax operating profit (loss)	$	2,100	$	275	^(a)	$	48	$	(195	)	^(b)	$	2,228
Income taxes	—		—			—		(901		)	^(c)	(901		)
Discontinued operations, net	—		—			—		(5		)		(5		)
Net income (loss)	$	2,100	$	275		$	48	$	(1,101	)		$	1,322

Three months ended
June 30, 2012

Net sales	$	4,495	$	1,172		$	262	$	(161	)		$	5,768

Pretax operating profit (loss)	$	2,043	$	194		$	77	$	(107	)	^(b)	$	2,207
Income taxes	—		—			—		(875		)	^(c)	(875		)
Discontinued operations, net	—		—			—		(4		)		(4		)
Net income (loss)	$	2,043	$	194		$	77	$	(986	)		$	1,328



						Midstream		Corporate
						and		and
	Oil and Gas		Chemical			Marketing		Eliminations				Total

Six months ended
June 30, 2013

Net sales	$	9,161	$	2,362		$	722	$	(411	)		$	11,834

Pretax operating profit (loss)	$	4,020	$	434	^(a)	$	263	$	(286	)	^(b)	$	4,431
Income taxes	—		—			—		(1,745		)	^(c)	(1,745		)
Discontinued operations, net	—		—			—		(9		)		(9		)
Net income (loss)	$	4,020	$	434		$	263	$	(2,040	)		$	2,677

Six months ended
June 30, 2012

Net sales	$	9,397	$	2,320		$	655	$	(336	)		$	12,036

Pretax operating profit (loss)	$	4,547	$	378		$	208	$	(227	)	^(b)	$	4,906
Income taxes	—		—			—		(2,014		)	^(c)	(2,014		)
Discontinued operations, net	—		—			—		(5		)		(5		)
Net income (loss)	$	4,547	$	378		$	208	$	(2,246	)		$	2,887


(a)	The three- and six-month periods ended June 30, 2013 include a $131 million pre-tax gain for the sale of an investment in Carbocloro, a Brazilian chemical facility.

(b)

Includes unallocated net interest expense, administration expense, environmental remediation and other pre-tax items. The three- and six-month periods ended June 30, 2013 include a $55 million pre-tax charge for the currently estimated cost related to employment and post-employment benefits for Occidental's former Executive Chairman and termination of certain other employees and consulting arrangements.


(c)	Includes all foreign and domestic income taxes from continuing operations.


12.	Earnings Per Share

Occidental’s instruments containing rights to nonforfeitable dividends granted in stock-based payment transactions are considered participating securities prior to vesting and, therefore, have been included in the earnings allocations in computing basic and diluted EPS under the two-class method.

Basic EPS was computed by dividing net income, 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.

The following table presents the calculation of basic and diluted EPS for the three and six months ended June 30, 2013 and 2012:



	Periods ended June 30
	Three months									Six months
(in millions, except per-share amounts)	2013			2012			2013				2012

Basic EPS

Income from continuing operations	$	1,327		$	1,332		$	2,686			$	2,892
Discontinued operations, net	(5		)	(4		)	(9		)		(5		)
Net income	1,322			1,328			2,677				2,887
Less: Net income allocated to participating securities	(3		)	(2		)	(5		)		(4		)
Net income, net of participating securities	$	1,319		$	1,326		$	2,672			$	2,883

Weighted average number of basic shares	804.9			810.3			804.8				810.4

Basic EPS	$	1.64		$	1.64		$	3.32			$	3.55

Diluted EPS

Net income, net of participating securities	$	1,319		$	1,326		$	2,672			$	2,883
Weighted average number of basic shares	804.9			810.3			804.8				810.4
Dilutive effect of potentially dilutive securities	0.5			0.7			0.5				0.8
Total diluted weighted average common shares	805.4			811.0			805.3				811.2

Diluted EPS	$	1.64		$	1.64		$	3.32			$	3.55


Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations

Consolidated Results of Operations

In this report, “Occidental” means Occidental Petroleum Corporation (OPC), or OPC and one or more entities in which it owns a controlling interest (subsidiaries). Occidental reported net income of $1.3 billion for the second quarter of 2013 on net sales of $6.0 billion, compared to net income of $1.3 billion on net sales of $5.8 billion for the same period of 2012. Diluted earnings per share (EPS) were $1.64 for the second quarter of 2013 and 2012. Occidental reported net income of $2.7 billion for the first six months of 2013 on net sales of $11.8 billion, compared to net income of $2.9 billion on net sales of $12.0 billion for the same period of 2012. Diluted EPS were $3.32 for the six months of 2013, compared to $3.55 for the same period of 2012.

Net income for the three months ended June 30, 2013, compared to the same period of 2012, reflected higher domestic realized prices for oil and natural gas, lower oil and gas segment operating costs and higher liquids volumes, partially offset by higher oil and gas segment depreciation, depletion and amortization (DD&A) rates, lower Middle East/North Africa realized oil prices, higher equity compensation expense due to Occidental's improved stock price and higher energy prices for the chemical segment. Net income for the six months ended June 30, 2013, compared to the same period of 2012, reflected lower worldwide oil and natural gas liquids (NGL) prices, higher oil and gas segment DD&A rates, higher energy prices for the chemical segment and higher equity compensation expense due to Occidental's improved stock price, partially offset by higher domestic gas prices and lower oil and gas segment operating costs.

Income for the three and six months ended June 30, 2013 included an after-tax gain of $85 million from the sale of Occidental's investment in Carbocloro, a Brazilian chemical facility, and a $34 million after-tax charge for the currently estimated cost related to employment and post-employment benefits for Occidental's former Executive Chairman and termination of certain other employees and consulting arrangements.

Selected Income Statement Items

Net sales for the three months ended June 30, 2013, of $6.0 billion, compared to $5.8 billion for the same period of 2012, reflected higher domestic realized prices for oil and natural gas and higher liquids volumes, partially offset by lower Middle East/North Africa realized oil prices. Net sales for the six months ended June 30, 2013, of $11.8 billion, compared to $12.0 billion for the same period of 2012, reflected lower worldwide oil and NGL prices, partially offset by higher domestic gas prices.

Cost of sales for the three and six months ended June 30, 2013, compared to the same periods in 2012, reflected higher oil and gas segment DD&A rates and higher chemical segment energy and feedstock costs, partially offset by lower oil and gas segment operating costs. Selling, general and administrative and other operating expenses for the three and six months ended June 30, 2013, compared to the same periods in the prior year, reflected higher equity compensation expense due to Occidental's improved stock price and the currently estimated cost related to employment and post-employment benefits for Occidental's former Executive Chairman and termination of certain other employees and consulting arrangements.

The decrease in the provision for domestic and foreign income taxes for the six months ended June 30, 2013, compared to the same period of 2012, was due to lower pre-tax income in 2013 and a lower effective tax rate, which included a benefit resulting from the relinquishment of an international exploration block.

Selected Analysis of Financial Position

See “Liquidity and Capital Resources” for discussion about the changes in cash and cash equivalents.

The increase in trade receivables, net, reflected higher domestic crude oil prices in the second quarter of 2013, compared to the fourth quarter of 2012, and the timing of settlements, partially offset by lower international crude oil lifting volumes and prices in the comparable periods. The decrease in other current assets was mainly due to the collection of an expected tax receivable during the second quarter. The increase in property, plant and equipment, net, reflected net capital expenditures of $4.2 billion, partially offset by DD&A.

The increase in accounts payable reflected higher domestic crude oil prices for the marketing and trading operations during the second quarter of 2013, compared to the fourth quarter of 2012, and the timing of payments at year end 2012 compared to the end of the second quarter of 2013. The increase in accrued liabilities was due to the accelerated

payout of the fourth quarter 2012 dividend during 2012, resulting in a lower year-end balance. The June 30, 2013 balance included the accrual of the second quarter 2013 dividend to be paid in the third quarter. The increase in deferred domestic and foreign income taxes was mainly due to accelerated tax depreciation of the capital expenditures in the first six months of 2013. The increase in stockholders' equity reflected net income for the first six months of 2013, partially offset by dividends.

Segment Operations

Occidental conducts its operations through three segments: (1) oil and gas; (2) chemical; and (3) midstream, marketing and other (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, carbon dioxide (CO₂) and power. It also trades around its assets, including transportation and storage capacity, and trades oil, NGLs, gas and other commodities. The segment also invests in entities that conduct similar activities.

The following table sets forth the sales and earnings of each operating segment and corporate items for the three and six months ended June 30, 2013 and 2012 (in millions):



								Periods ended June 30
				Three Months							Six Months
	2013				2012			2013				2012

Net Sales ^(a)
Oil and Gas	$	4,721			$	4,495		$	9,161			$	9,397
Chemical	1,187				1,172			2,362				2,320
Midstream and Marketing	269				262			722				655
Eliminations	(215		)		(161		)	(411		)		(336		)

	$	5,962			$	5,768		$	11,834			$	12,036
Segment Earnings ^(b)
Oil and Gas	$	2,100			$	2,043		$	4,020			$	4,547
Chemical	275				194			434				378
Midstream and Marketing	48				77			263				208
	2,423				2,314			4,717				5,133

Unallocated Corporate Items ^(b)
Interest expense, net	(29		)		(25		)	(59		)		(53		)
Income taxes	(901		)		(875		)	(1,745		)		(2,014		)
Other expense, net	(166		)		(82		)	(227		)		(174		)

Income from continuing operations	1,327				1,332			2,686				2,892
Discontinued operations, net	(5		)		(4		)	(9		)		(5		)

Net income	$	1,322			$	1,328		$	2,677			$	2,887


(a)	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.


(b)	Refer to “Significant Transactions and Events Affecting Earnings,” “Oil and Gas Segment,” “Chemical Segment,” “Midstream and Marketing Segment” and "Corporate" discussions that follow.

Significant Transactions and Events Affecting Earnings

The following table sets forth, for the three and six months ended June 30, 2013 and 2012, significant transactions and events affecting Occidental’s earnings that vary widely and unpredictably in nature, timing and amount (in millions):



								Periods Ended June 30
				Three Months							Six Months
	2013				2012			2013				2012

Oil & Gas
No significant items affecting earnings	$	—			$	—		$	—			$	—
Total Oil and Gas	$	—			$	—		$	—			$	—

Chemical
Carbocloro sale gain	$	131			$	—		$	131			$	—
Total Chemical	$	131			$	—		$	131			$	—

Midstream and Marketing
No significant items affecting earnings	$	—			$	—		$	—			$	—
Total Midstream and Marketing	$	—			$	—		$	—			$	—

Corporate
Charge for former executives and consultants	$	(55	)		$	—		$	(55	)		$	—
Tax effect of pre-tax adjustments	(25		)		—			(25		)		—
Discontinued operations, net*	(5		)		(4		)	(9		)		(5		)
Total Corporate	$	(85	)		$	(4	)	$	(89	)		$	(5	)

Total	$	46			$	(4	)	$	42			$	(5	)

*Amounts shown after tax.

Worldwide Effective Tax Rate

The following table sets forth the calculation of the worldwide effective tax rate for income from continuing operations for the three and six months ended June 30, 2013 and 2012 ($ in millions):



								Periods ended June 30
				Three Months							Six Months
	2013				2012			2013				2012

Oil & Gas earnings	$	2,100			$	2,043		$	4,020			$	4,547
Chemical earnings	275				194			434				378
Midstream and Marketing earnings	48				77			263				208
Unallocated corporate items	(195		)		(107		)	(286		)		(227		)
Pre-tax income	2,228				2,207			4,431				4,906

Income tax expense
Federal and state	332				254			624				700
Foreign	569				621			1,121				1,314
Total	901				875			1,745				2,014

Income from continuing operations	$	1,327			$	1,332		$	2,686			$	2,892

Worldwide effective tax rate	40%				40%			39%			^(a)	41%


(a)	Includes the benefit from the relinquishment of an international exploration block during the first quarter of 2013.

Oil and Gas Segment

The following tables set forth the production and sales volumes of oil, NGLs and natural gas per day for the three and six months ended June 30, 2013 and 2012. The differences between the production and sales volumes per day are generally due to the timing of shipments at Occidental’s international locations where product is loaded onto tankers.



				Periods Ended June 30
		Three Months			Six Months
Production per Day	2013		2012	2013		2012

Oil (MBBL)
United States	261		249	262		246
Middle East/North Africa	193		181	184		186
Latin America	28		31	29		27

NGLs (MBBL)
United States	77		73	77		73
Middle East/North Africa	7		9	7		9

Natural Gas (MMCF)
United States	792		840	808		837
Middle East/North Africa	433		481	433		464
Latin America	13		14	13		14

Total production (MBOE) ^(a)	772		766	768		760

Sales Volumes per Day

Oil (MBBL)
United States	261		249	262		246
Middle East/North Africa	186		175	172		178
Latin America	26		31	28		27

NGLs (MBBL)
United States	77		73	77		73
Middle East/North Africa	7		9	7		9

Natural Gas (MMCF)
United States	795		835	810		835
Middle East/North Africa	433		481	433		464
Latin America	13		14	13		14

Total sales volumes (MBOE) ^(a)	764		759	755		752

Note: MBBL represents thousand barrels. MMCF represents million cubic feet. MBOE represents thousand barrels of oil equivalent.

(a)

Natural gas volumes have been converted to barrels of oil equivalent (BOE) based on energy content of six thousand cubic feet (Mcf) of gas to one barrel of oil. Barrels of oil equivalence does not necessarily result in price equivalence. The price of natural gas on a BOE basis is currently substantially lower than the corresponding price for oil and has been similarly lower for a number of years. For example, for the six months ending June 30, 2013, the average prices of West Texas Intermediate (WTI) oil and New York Mercantile Exchange (NYMEX) natural gas were $94.30 per barrel and $3.68 per Mcf, respectively, resulting in an oil to gas ratio of over 25.

The following tables present information about Occidental's average realized prices and index prices for the three and six months ended June 30, 2013 and 2012:



						Periods Ended June 30
			Three Months						Six Months
Average Realized Prices	2013			2012			2013			2012
Oil ($/BBL)
United States	$	95.08		$	92.34		$	93.33		$	97.88
Middle East/North Africa	$	101.83		$	109.70		$	104.40		$	112.28
Latin America	$	98.85		$	98.15		$	103.29		$	100.40
Total Worldwide	$	97.91		$	99.34		$	97.99		$	103.63

NGLs ($/BBL)
United States	$	39.70		$	43.75		$	40.15		$	49.14
Middle East/North Africa	$	29.14		$	29.32		$	32.65		$	34.76
Total Worldwide	$	38.78		$	42.06		$	39.52		$	47.52

Natural Gas ($/MCF)
United States	$	3.82		$	2.09		$	3.44		$	2.46
Latin America	$	11.32		$	12.06		$	11.46		$	11.84
Total Worldwide	$	2.83		$	1.72		$	2.60		$	1.97




						Periods Ended June 30
			Three Months					Six Months
Average Index Prices	2013			2012		2013			2012
WTI oil ($/barrel)	$	94.22		$	93.49	$	94.30		$	98.21
Brent oil ($/barrel)	$	103.35		$	108.90	$	108.00		$	113.63
NYMEX gas ($/Mcf)	$	4.00		$	2.28	$	3.68		$	2.55




				Periods Ended June 30
		Three Months			Six Months
Average Realized Prices as Percentage of
Average Index Prices	2013		2012	2013		2012
Worldwide oil as a percentage of average WTI	104%		106%	104%		106%
Worldwide oil as a percentage of average Brent	95%		91%	91%		91%
Worldwide NGLs as a percentage of average WTI	41%		45%	42%		48%
Domestic natural gas as a percentage of average
NYMEX	95%		91%	93%		97%

Oil and gas segment earnings for the three and six months ended June 30, 2013 were $2.1 billion and $4.0 billion, respectively, compared to $2.0 billion and $4.5 billion for the same periods of 2012. The increase in oil and gas segment earnings for the three months ended June 30, 2013, compared to the same period of 2012, reflected higher domestic realized prices for oil and natural gas, lower operating costs and higher liquids volumes, partially offset by higher DD&A rates and lower Middle East/North Africa realized oil prices. The decrease for the six months ended June 30, 2013, compared to the same period of 2012, reflected lower worldwide oil and NGL prices and higher DD&A rates, partially offset by higher domestic gas prices and lower operating costs.

Approximately 60 percent of Occidental's oil production tracks world oil prices, such as Brent, and 40 percent tracks WTI. Price changes at current global prices and levels of production affect Occidental's quarterly pre-tax income by approximately $38 million for a $1.00 per barrel change in global oil prices and approximately $8 million for a $1.00 per barrel change in NGL prices. A change of $0.50 per Mcf in domestic gas prices affects quarterly pre-tax earnings by approximately $30 million. These price change sensitivities include the impact of volume changes from production-

sharing and similar contracts. If production levels change in the future, the sensitivity of Occidental's results to oil, NGL and gas prices also would change.

Oil and gas production in the second quarter of 2013 was 772,000 BOE per day, compared with 766,000 BOE per day for the same period of 2012. The second quarter 2013 production increase resulted from 8,000 BOE per day of increased volumes from domestic operations, partially offset by lower volumes of 2,000 BOE per day from international operations. Domestic production increases were achieved in California and the Permian. The second quarter 2013 domestic production was negatively impacted by 3,000 BOE per day due to severe storms in West Texas and the effect of planned turnarounds in the Permian. Internationally, Colombian production was lower due to higher insurgent activity. The impact of full cost recovery under production-sharing and similar contracts and other adjustments reduced production by 8,000 BOE per day. Sales volumes increased from 759,000 BOE per day in the second quarter of 2012 to 764,000 BOE per day in the second quarter of 2013. Sales volumes were lower than production volumes in the second quarter of 2013 due to the timing of liftings in Middle East/North Africa and Colombia, which lowered pre-tax earnings for the second quarter by approximately $75 million.

Oil and gas production for the first six months of 2013 was 768,000 BOE per day, compared with 760,000 BOE per day for the same period of 2012. Year-over-year, Occidental's domestic production increased by approximately 3.5 percent or 16,000 BOE per day. In the second quarter of 2013, volumes were negatively impacted by severe storms in West Texas and the planned turnarounds in the Permian. International production was 8,000 BOE per day lower due to the first quarter 2013 planned maintenance turnaround in Qatar, the impact of full cost recovery at the Dolphin operations and higher insurgent activity in Colombia. Sales volumes were 755,000 BOE per day in the first six months of 2013, compared with 752,000 BOE per day for the same period in 2012. Sales volumes were lower than production volumes due to the timing of liftings mainly in Middle East/North Africa.

Oil and gas average production costs decreased from $14.99 per BOE for the total year 2012 to $13.40 per BOE and $13.66 per BOE for the three and six months ended June 30, 2013, respectively. This decrease reflected the impact of the domestic operational efficiency initiative, where production costs were $3.26 per barrel lower in the first six months of 2013 than the full year of 2012. In particular, Occidental has taken steps that resulted in lower costs for well maintenance, workovers and surface operations, which together make up a significant portion of the operating costs. These domestic production cost reductions were partially offset by the first quarter 2013 costs of planned maintenance turnarounds in Qatar and the Dolphin operations. Taxes other than on income, which are generally related to product prices, were $2.66 per BOE for the first six months of 2013, compared to $2.39 per BOE for the total year 2012. The 2013 amount includes California greenhouse gas expense of $0.05 per BOE.

Chemical Segment

Chemical segment earnings for the three months ended June 30, 2013 were $144 million, excluding the $131 million pre-tax gain from the sale of the investment in Carbocloro, compared with $194 million for the same period of 2012. The second quarter 2013 results reflected lower caustic soda export volumes due to continued weak economic conditions in Europe and slowing demand in Asia, particularly within the pulp and paper and alumina segments; reduced alumina demand in South America; continued weak chlorinated organics pricing in export markets resulting from new organics production in Asia; and higher energy and feedstock costs.

Chemical segment earnings for the six months ended June 30, 2013 were $303 million, excluding the $131 million pre-tax gain, compared to $378 million for the same period of 2012. The 2013 results, compared to 2012, reflected higher energy and feedstock prices and continued weak export chlorinated organics pricing resulting from new organics production in Asia, partially offset by modest volume improvements across most products.

Midstream and Marketing Segment

Midstream and marketing segment earnings for the three months ended June 30, 2013 and 2012 were $48 million and $77 million, respectively. Earnings for the second quarter of 2013, compared to the same period of 2012, reflected lower marketing and trading performance driven by commodity price movements.

Midstream and marketing segment earnings for the six months ended June 30, 2013 and 2012, were $263 million and $208 million, respectively. Earnings for the first six months of 2013, compared to the same period of 2012, reflected improved performance in marketing and trading in the first quarter of 2013 and better results in the power generation business, offset by weaker results in the gas processing and foreign pipeline businesses.

Corporate

Liquidity and Capital Resources

At June 30, 2013, Occidental had approximately $3.1 billion in cash on hand. In addition, 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. Income and cash flows are largely dependent on the oil and gas segment's prices and volumes. Occidental believes that cash on hand and cash generated from operations will be sufficient to fund its operating needs and planned capital expenditures, dividends and any debt payments. Occidental, from time to time, may access and has accessed debt markets for general corporate purposes, including acquisitions.

Although net income decreased by $0.2 billion for the six months ended June 30, 2013, compared to the same period in 2012, net cash provided by operating activities increased by $0.3 billion for 2013. Compared to 2012, net income in 2013 included higher DD&A, which, as a non-cash charge, reduced net income but not cash provided by operating activities. The year-over-year changes also reflected decreases in other 2013 non-cash items, compared to 2012, mainly comprising deferred income taxes and dry hole expenses. The 2013 cash flow from operating activities included an inflow from the collection of an expected $0.4 billion tax receivable, partially offset by $0.2 billion working capital changes.

Additionally, cash flow from operations in the first six months of 2013, compared to the same period of 2012, reflected 5-percent lower average realized worldwide oil prices and 17-percent lower worldwide NGL prices, partially offset by 40-percent higher average realized domestic gas prices and lower operating costs. The impact of the chemical and the midstream and marketing segments on overall cash flows is typically less significant than the impact of the oil and gas segment because the chemical and midstream and marketing segments are significantly smaller.

Occidental’s net cash used by investing activities was $4.3 billion for the first six months of 2013, compared to $6.2 billion for the same period of 2012. Capital expenditures, net, for the first six months of 2013 were $4.2 billion, including $3.4 billion for oil and gas. Capital expenditures for the first six months of 2012 were $5.1 billion, including $4.2 billion for oil and gas. The 2013 amount included $0.3 billion of cash received from the sale of the investment in Carbocloro, partially offset by payments of $0.2 billion for acquisitions of various interests in domestic oil and gas properties. The 2012 amount included payments of $1.1 billion for acquisitions of various interests in domestic oil and gas properties.

Occidental’s net cash used by financing activities was approximately $0.4 billion for the first six months of 2013, compared to net cash provided by financing activities of approximately $0.8 billion for the same period of 2012. The 2013 amount mainly comprised dividend payments of $517 million. The 2012 amount included borrowings of $1.7 billion, dividend payments of $813 million and purchases of treasury stock of $152 million. The dividend payments for the first six months of 2013 were lower than the first six months of 2012 due to the accelerated payment of the fourth quarter of 2012 dividend.

As of June 30, 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.

Occidental expects the 2013 capital spending to be generally in line with its previous estimate of $9.6 billion and will be focused on increasing oil production and ensuring Occidental's returns remain well above its cost of capital given current prices and the cost environment. Occidental believes there is a reasonable possibility that the 2013 capital spending could be lower due to the success of the capital efficiency efforts, which have resulted in significant cost reductions.

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. Occidental’s environmental compliance costs have generally increased over time and are expected to rise in the future. Occidental factors environmental expenditures for its operations into its business planning process as an integral part of producing quality products responsive to market demand.

As of June 30, 2013, Occidental participated in or monitored remedial activities or proceedings at 161 sites. The following table presents Occidental’s environmental remediation reserves as of June 30, 2013, grouped as environmental remediation sites listed or proposed for listing by the United States 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.



	Number of Sites		Reserve Balance (in millions)
NPL sites		33	$	52
Third-party sites		76		74
Occidental-operated sites		22		121
Closed or non-operated Occidental sites		30		80
Total		161	$	327

Refer to the “Environmental Liabilities and Expenditures” section of Management’s Discussion and Analysis of Financial Condition and Results of Operations in Occidental’s Annual Report on Form 10-K for the year ended December 31, 2012, for additional information regarding Occidental’s environmental expenditures.

Lawsuits, Claims, Commitments and Contingencies

Recently Adopted Accounting and Disclosure Changes

These new disclosures were not material to Occidental's financial statements.

Safe Harbor Statement Regarding Outlook and Forward-Looking Information

Portions of this report contain forward-looking statements and involve risks and uncertainties that could materially affect expected results of operations, liquidity, cash flows and business prospects. Actual results may differ materially from the results predicted, and reported results should not be considered an indication of future performance. Factors that could cause results to differ materially include, but are not limited to: global commodity pricing fluctuations; supply and demand considerations for Occidental's specific products; higher-than-expected costs; the regulatory approval environment; not successfully completing, or any material delay of, field developments, expansion projects, capital expenditures, efficiency projects, acquisitions or dispositions; lower-than-expected production from development projects or acquisitions; exploration risks; general economic slowdowns domestically or internationally; political conditions and events; liability under environmental regulations and litigation for remedial actions; litigation; disruption or interruption of production or manufacturing or facility damage due to accidents, chemical releases, labor unrest, weather, natural disasters, cyber attacks or insurgent activity; failure of risk management; changes in law or regulations; or changes in tax rates. Words such as “estimate,” “project,” “predict,” “will,” “would,” “should,” “could,” “may,” “might,” “anticipate,” “plan,” “intend,” “believe,” “expect,” “aim,” “goal,” “target,” “objective,” “likely” or similar expressions that convey the prospective nature of events or outcomes generally indicate forward-looking statements. You should not place undue reliance on these forward-looking statements, which speak only as of the date of this report. Unless legally required, Occidental does not undertake any obligation to update any forward-looking statements, as a result of new information, future events or otherwise. Material risks that may affect Occidental's results of operations and financial position appear in Part I, Item 1A “Risk Factors” of the 2012 Form 10-K.


Item 3.	Quantitative and Qualitative Disclosures About Market Risk

For the three and six months ended June 30, 2013, there were no material changes in the information required to be provided under Item 305 of Regulation S-K included under the caption “Management’s Discussion and Analysis of Financial Condition and Results of Operations (Incorporating Item 7A) — Derivative Activities and Market Risk” in the 2012 Form 10-K.


Item 4.	Controls and Procedures

Occidental's President and Chief Executive Officer and its Executive Vice President and Chief Financial Officer supervised and participated in Occidental's evaluation of its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) as of the end of the period covered by this report. Based upon that evaluation, Occidental's President and Chief Executive Officer and Executive Vice President and Chief Financial Officer concluded that Occidental's disclosure controls and procedures were effective as of June 30, 2013.

There has been no change in Occidental's internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934) during the second quarter of 2013 that has materially affected, or is reasonably likely to materially affect, Occidental's internal control over financial reporting.

PART II OTHER INFORMATION


Item 1.	Legal Proceedings

For information regarding legal proceedings, see the information in Note 7 to the consolidated condensed financial statements in Part I of this Form 10-Q and Part I, Item 3, “Legal Proceedings” in the Form 10-K for the year ended December 31, 2012.

In the second quarter, an OPC subsidiary settled a previously disclosed claim of the New Mexico Environment Department under the New Mexico Air Quality Control Act for a cash penalty of $95,000 and an agreement to spend at least $826,000 to install additional emission controls at a facility in Lea County, New Mexico.


Item 2.	Share Repurchase Activities

Occidental's share repurchase activities for the three and six months ended June 30, 2013, were as follows:



Period	Total Number of Shares Purchased		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs		Maximum Number of Shares that May Yet be Purchased Under the Plans or Programs

First Quarter 2013	—		$	—		—
April 1 – 30, 2013	—		$	—		—
May 1 – 31, 2013	239,444	^(a)	$	90.23		—
June 1 – 30, 2013	—		$	—		—
Second Quarter 2013	239,444		$	90.23		—
Total	239,444		$	90.23		—	17,255,575


(a)	Purchased from the trustee of Occidental’s defined contribution savings plan; not part of publicly announced plans or programs.


Item 6.	Exhibits



	3.(ii)	By-laws of Occidental, as amended through May 3, 2013 (filed as Exhibit 3.(ii) to the Current Report on Form 8-K of Occidental dated May 3, 2013 (date of earliest event reported), filed May 8, 2013, File No. 1-9210).

	10.1	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Restricted Stock Incentive Award Terms and Conditions (filed as Exhibit 10.1 to the Current Report on Form 8-K of Occidental dated July 10, 2013 (date of earliest event reported), filed July 16, 2013, File No. 1-9210).

	10.2	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Total Shareholder Return Incentive Award Terms and Conditions (Equity-Based and Equity-Settled Award) (filed as Exhibit 10.1 to the Current Report on Form 8-K of Occidental dated July 22, 2013 (date of earliest event reported), filed July 26, 2013, File No. 1-9210).

	10.3	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Restricted Stock Incentive Award Terms and Conditions (Performance-Based) (filed as Exhibit 10.2 to the Current Report on Form 8-K of Occidental dated July 22, 2013 (date of earliest event reported), filed July 26, 2013, File No. 1-9210).

	10.4	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Return on Capital Employed Incentive Award Terms and Conditions (Equity-Based, Equity-Settled Award) (filed as Exhibit 10.3 to the Current Report on Form 8-K of Occidental dated July 22, 2013 (date of earliest event reported), filed July 26, 2013, File No. 1-9210).

	10.5	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Oil and Gas Corporation Return on Assets Incentive Award Terms and Conditions (Equity-Based, Equity-Settled Award) (filed as Exhibit 10.4 to the Current Report on Form 8-K of Occidental dated July 22, 2013 (date of earliest event reported), filed July 26, 2013, File No. 1-9210).

	10.6	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Oil and Gas Corporation Return on Assets Incentive Award Terms and Conditions (Equity-Based, Equity-Settled Award) (Americas) (filed as Exhibit 10.5 to the Current Report on Form 8-K of Occidental dated July 22, 2013 (date of earliest event reported), filed July 26, 2013, File No. 1-9210).

	10.7	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Oil and Gas Corporation Return on Assets Incentive Award Terms and Conditions (Equity-Based, Equity-Settled Award) (MENA) (filed as Exhibit 10.6 to the Current Report on Form 8-K of Occidental dated July 22, 2013 (date of earliest event reported), filed July 26, 2013, File No. 1-9210).

	10.8	Occidental Petroleum Corporation Acknowledgement Letter dated April 29, 2013.

	10.9	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Restricted Stock Incentive Award Terms and Conditions.

	10.10	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Return on Capital Employed Incentive Award Terms and Conditions (Cash-Based, Cash-Settled Award).

	10.11	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Chemical Corporation Return on Assets Incentive Award Terms and Conditions (Cash-Based, Cash-Settled Award).

	10.12	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Oil and Gas Corporation Return on Assets Incentive Award Terms and Conditions (Cash-Based, Cash-Settled Award).



	10.13	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Oil and Gas Corporation Return on Assets Incentive Award Terms And Conditions (Cash-Based, Cash-Settled Award) (Americas).

	10.14	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Oil and Gas Corporation Return on Assets Incentive Award Terms and Conditions (Cash-Based, Cash-Settled Award) (MENA).

	10.15	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Chemical Corporation Return on Assets Incentive Award Terms and Conditions (Equity-Based, Equity-Settled Award).

	12	Statement regarding the computation of total enterprise ratios of earnings to fixed charges for the six months ended June 30, 2013 and 2012 and for each of the five years in the period ended December 31, 2012.

	31.1	Certification of CEO Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

	31.2	Certification of CFO Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

	32.1	Certifications of CEO and CFO Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

	101.INS	XBRL Instance Document.

	101.SCH	XBRL Taxonomy Extension Schema Document.

	101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document.

	101.LAB	XBRL Taxonomy Extension Label Linkbase Document.

	101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document.

	101.DEF	XBRL Taxonomy Extension Definition Linkbase Document.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



	OCCIDENTAL PETROLEUM CORPORATION



DATE:	August 5, 2013	/s/ Roy Pineci
		Roy Pineci
		Vice President, Controller and
		Principal Accounting Officer

EXHIBIT INDEX

EXHIBITS



	10.8	Occidental Petroleum Corporation Acknowledgement Letter dated April 29, 2013.

	10.9	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Restricted Stock Incentive Award Terms and Conditions.

	10.10	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Return on Capital Employed Incentive Award Terms and Conditions (Cash-Based, Cash-Settled Award).

	10.11	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Chemical Corporation Return on Assets Incentive Award Terms and Conditions (Cash-Based, Cash-Settled Award).

	10.12	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Oil and Gas Corporation Return on Assets Incentive Award Terms and Conditions (Cash-Based, Cash-Settled Award).

	10.13	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Oil and Gas Corporation Return on Assets Incentive Award Terms And Conditions (Cash-Based, Cash-Settled Award) (Americas).

	10.14	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Oil and Gas Corporation Return on Assets Incentive Award Terms and Conditions (Cash-Based, Cash-Settled Award) (MENA).

	10.15	Occidental Petroleum Corporation 2005 Long-Term Incentive Plan Occidental Chemical Corporation Return on Assets Incentive Award Terms and Conditions (Equity-Based, Equity-Settled Award).

	12	Statement regarding the computation of total enterprise ratios of earnings to fixed charges for the six months ended June 30, 2013 and 2012 and for each of the five years in the period ended December 31, 2012.

	31.1	Certification of CEO Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

	31.2	Certification of CFO Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

	32.1	Certifications of CEO and CFO Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

	101.INS	XBRL Instance Document.

	101.SCH	XBRL Taxonomy Extension Schema Document.

	101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document.

	101.LAB	XBRL Taxonomy Extension Label Linkbase Document.

	101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document.

	101.DEF	XBRL Taxonomy Extension Definition Linkbase Document.