Edgar Filing: OCCIDENTAL PETROLEUM CORP /DE/

Document

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, 2016

¨ 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.)

5 Greenway Plaza, Suite 110 Houston, Texas (Address of principal executive offices)		77046 (Zip Code)

(713) 215-7000

(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.

þ Yes o 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).

þ Yes o 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 Filer þ Accelerated Filer o Non-Accelerated Filer o Smaller Reporting Company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act)

o Yes þ 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, 2016
	Common stock $.20 par value		763,926,260

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

TABLE OF CONTENTS



				PAGE

Part I	Financial Information

	Item 1.	Financial Statements (unaudited)

		Consolidated Condensed Balance Sheets —
			June 30, 2016 and December 31, 2015	2

		Consolidated Condensed Statements of Operations —
			Three and six months ended June 30, 2016 and 2015	4

		Consolidated Condensed Statements of Comprehensive Income —
			Three and six months ended June 30, 2016 and 2015	5

		Consolidated Condensed Statements of Cash Flows —
			Six months ended June 30, 2016 and 2015	6

		Notes to Consolidated Condensed Financial Statements		7

	Item 2.	Management’s Discussion and Analysis of Financial
			Condition and Results of Operations	19

	Item 3.	Quantitative and Qualitative Disclosures About Market Risk		28

	Item 4.	Controls and Procedures		28

Part II	Other Information

	Item 1.	Legal Proceedings		29

	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds		29

	Item 5.	Other Information		29

	Item 6.	Exhibits		30

PART I FINANCIAL INFORMATION


Item 1.	Financial Statements (unaudited)

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED CONDENSED BALANCE SHEETS

JUNE 30, 2016 AND DECEMBER 31, 2015

(Amounts in millions)



	2016		2015

ASSETS

CURRENT ASSETS

Cash and cash equivalents	$	3,751	$	3,201

Restricted cash	—		1,193

Trade receivables, net	3,113		2,970

Inventories	906		986

Assets held for sale	—		141

Other current assets	1,202		911

Total current assets	8,972		9,402



INVESTMENTS

Investment in unconsolidated entities	1,360		1,267

Available for sale investment	—		167

Total investments	1,360		1,434

PROPERTY, PLANT AND EQUIPMENT, net of accumulated depreciation, depletion and amortization of $41,212 at June 30, 2016 and $39,419 at December 31, 2015	31,038		31,639

LONG-TERM RECEIVABLES AND OTHER ASSETS, NET	1,025		934

TOTAL ASSETS	$	42,395	$	43,409

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

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED CONDENSED BALANCE SHEETS

JUNE 30, 2016 AND DECEMBER 31, 2015

(Amounts in millions except share amounts)



	2016			2015

LIABILITIES AND STOCKHOLDERS’ EQUITY
CURRENT LIABILITIES
Current maturities of long-term debt	$	—		$	1,450
Accounts payable	3,126			3,069
Accrued liabilities	2,141			2,213
Liabilities of assets held for sale	—			110
Total current liabilities	5,267			6,842

LONG-TERM DEBT, NET	8,331			6,855

DEFERRED CREDITS AND OTHER LIABILITIES
Deferred domestic and foreign income taxes	1,646			1,323
Other	4,050			4,039
	5,696			5,362
STOCKHOLDERS' EQUITY
Common stock, at par value (891,807,415 shares at June 30, 2016 and 891,360,091 shares at December 31, 2015)	178			178
Treasury stock (127,881,155 shares at June 30, 2016 and 127,681,335 shares at December 31, 2015)	(9,136		)	(9,121		)
Additional paid-in capital	7,697			7,640
Retained earnings	24,661			25,960
Accumulated other comprehensive loss	(299		)	(307		)
Total stockholders’ equity	23,101			24,350

TOTAL LIABILITIES AND STOCKHOLDERS’ EQUITY	$	42,395		$	43,409

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

OCCIDENTAL PETROLEUM CORPORATION AND SUBSIDIARIES

CONSOLIDATED CONDENSED STATEMENTS OF OPERATIONS

FOR THE THREE AND SIX MONTHS ENDED JUNE 30, 2016 AND 2015

(Amounts in millions, except per-share amounts)



	Three months ended June 30						Six months ended June 30
	2016			2015			2016			2015

REVENUES AND OTHER INCOME
Net sales	$	2,531		$	3,469		$	4,654		$	6,558
Interest, dividends and other income	27			26			47			57
Gain (loss) on sale of assets, net	—			19			138			(5		)
	2,558			3,514			4,839			6,610
COSTS AND OTHER DEDUCTIONS
Cost of sales	1,244			1,480			2,525			3,037
Selling, general and administrative and other operating expenses	338			347			610			658
Taxes other than on income	74			107			149			214
Depreciation, depletion and amortization	1,070			1,116			2,172			2,145
Asset impairments and related items	—			—			78			324
Exploration expense	27			10			36			18
Interest and debt expense, net	88			8			148			38
	2,841			3,068			5,718			6,434

Income (loss) before income taxes and other items	(283		)	446			(879		)	176
Benefit (provision) for domestic and foreign income taxes	96			(324		)	299			(305		)
Income from equity investments	51			58			84			94
Income (loss) from continuing operations	(136		)	180			(496		)	(35		)
Discontinued operations, net	(3		)	(4		)	435			(7		)
NET INCOME (LOSS)	$	(139	)	$	176		$	(61	)	$	(42	)

BASIC EARNINGS PER COMMON SHARE
Income (loss) from continuing operations	$	(0.18	)	$	0.23		$	(0.65	)	$	(0.04	)
Discontinued operations, net	—			—			0.57			(0.01		)
BASIC EARNINGS PER COMMON SHARE	$	(0.18	)	$	0.23		$	(0.08	)	$	(0.05	)

DILUTED EARNINGS PER COMMON SHARE
Income (loss) from continuing operations	$	(0.18	)	$	0.23		$	(0.65	)	$	(0.04	)
Discontinued operations, net	—			—			0.57			(0.01		)
DILUTED EARNINGS PER COMMON SHARE	$	(0.18	)	$	0.23		$	(0.08	)	$	(0.05	)

DIVIDENDS PER COMMON SHARE	$	0.75		$	0.75		$	1.50		$	1.47

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, 2016 AND 2015

(Amounts in millions)



	Three months ended June 30						Six months ended June 30
	2016			2015			2016			2015

Net income (loss)	$	(139	)	$	176		$	(61	)	$	(42	)
Other comprehensive income (loss) items:
Foreign currency translation gains (losses)	—			—			1			(1		)
Unrealized gains (losses) on available for sale investment	—			(112		)	—			38
Unrealized losses on derivatives ^(a)	(3		)	—			(13		)	—
Pension and postretirement gains ^(b)	7			2			12			4
Reclassification to income of realized losses on derivatives^(c)	1			—			8			—
Other comprehensive income (loss), net of tax^(d)	5			(110		)	8			41
Comprehensive income (loss)	$	(134	)	$	66		$	(53	)	$	(1	)


(a)	Net of tax of $1 and $7 for the three and six months ended June 30, 2016, respectively.


(b)	Net of tax of $(4) and $(1) for the three months ended June 30, 2016 and 2015, respectively, and $(7) and $(2) for the six months ended June 30, 2016 and 2015.


(c)	Net of tax of zero and $(4) for the three and six months ended June 30, 2016, respectively.


(d)	There were no other comprehensive income (loss) items related to noncontrolling interests in the three and six months ended 2016 and 2015, respectively.

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, 2016 AND 2015

(Amounts in millions)



	2016			2015
CASH FLOW FROM OPERATING ACTIVITIES
Net Loss	$	(61	)	$	(42	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Discontinued operations, net	(435		)	7
Depreciation, depletion and amortization of assets	2,172			2,145
Deferred income tax provision	76			139
Other noncash charges to income	37			145
Asset impairments	78			236
(Gain) loss on sale of assets, net	(138		)	5
Dry hole expenses	28			3
Changes in operating assets and liabilities, net	(511		)	(954		)
Other operating, net	(304		)	(307		)
Operating cash flow from continuing operations	942			1,377
Operating cash flow from discontinued operations	876			(11		)
Net cash provided by operating activities	1,818			1,366

CASH FLOW FROM INVESTING ACTIVITIES
Capital expenditures	(1,247		)	(3,065		)
Change in capital accrual	(209		)	(585		)
Payments for purchases of assets and businesses	(34		)	(43		)
Sale of assets, net	260			58
Equity investments and other, net	(104		)	(254		)
Net cash used by investing activities	(1,334		)	(3,889		)

CASH FLOW FROM FINANCING ACTIVITIES
Change in restricted cash	1,193			1,637
Proceeds from long-term debt, net	2,718			1,478
Payment of long-term debt, net	(2,710		)	—
Proceeds from issuance of common stock	29			23
Purchases of treasury stock	(15		)	(536		)
Cash dividends paid	(1,149		)	(1,113		)
Other, net	—			1
Net cash provided by financing activities	66			1,490

Increase (decrease) in cash and cash equivalents	550			(1,033		)
Cash and cash equivalents — beginning of period	3,201			3,789
Cash and cash equivalents — end of period	$	3,751		$	2,756

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, 2016

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 (GAAP) as they apply to interim reporting, and condensed or omitted, as permitted by the Securities and Exchange Commission’s rules and regulations, certain information and disclosures normally included in consolidated financial statements and the notes. These unaudited consolidated condensed financial statements should be read in conjunction with the audited consolidated financial statements and the notes thereto in Occidental’s Annual Report on Form 10-K for the year ended December 31, 2015.

In the opinion of Occidental’s management, the accompanying unaudited 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, 2016, and the consolidated statements of operations, comprehensive income and cash flows for the three and six months ended June 30, 2016 and 2015, as applicable. The income and cash flows for the periods ended June 30, 2016 and 2015 are not necessarily indicative of the income or cash flows to be expected for the full year.

2. Asset Acquisitions, Dispositions and Other

In the second quarter of 2016, Occidental received $330 million as final payment from the settlement with the Republic of Ecuador. In January 2016, Occidental reached an understanding on the terms of payment for the approximate $1.0 billion payable to Occidental by the Republic of Ecuador under a November 2015 International Center for Settlement of Investment Disputes arbitration award. This award relates to Ecuador's 2006 expropriation of Occidental's Participation Contract for Block 15. Occidental recorded a pre-tax gain of $681 million in the first quarter of 2016. The results related to Ecuador were presented as discontinued operations.

In May and June 2016, respectively, Occidental utilized part of the proceeds from the April 2016 senior note offering (described below) to exercise the early redemption option on $1.25 billion of 1.75-percent senior notes due in the first quarter of 2017 and to retire all $750 million of 4.125-percent senior notes that matured in June 2016.

In April 2016, Occidental issued $2.75 billion of senior notes, comprised of $0.4 billion of 2.6-percent senior notes due 2022, $1.15 billion of 3.4-percent senior notes due 2026 and $1.2 billion of 4.4-percent senior notes due 2046. Occidental received net proceeds of approximately $2.72 billion. Interest on the senior notes will be payable semi-annually in arrears in April and October of each year for each series of senior notes, beginning on October 15, 2016. Occidental used a portion of the proceeds to retire debt in May and June 2016, and will use the remaining proceeds for general corporate purposes.

In March 2016, Occidental distributed its remaining shares of California Resources Corporation (California Resources) through a special stock dividend to stockholders of record as of February 29, 2016. Upon distribution, Occidental recorded a $78 million loss to reduce the investment to its fair market value, and Occidental no longer owns any shares of California Resources common stock.

In March 2016, Occidental completed the sale of its Piceance Basin operations in Colorado for $153 million resulting in a pre-tax gain of $121 million. The assets and liabilities related to these operations were presented as held for sale at December 31, 2015, and primarily included property, plant and equipment and current accrued liabilities and asset retirement obligations.

In February 2016, Occidental repaid $700 million of 2.5-percent senior notes that matured.

In January 2016, Occidental completed the sale of its Occidental Tower building in Dallas, Texas, for net proceeds of approximately $85 million. The building was classified as held for sale as of December 31, 2015.

3. Accounting and Disclosure Changes

In March, April, and May of 2016, the Financial Accounting Standards Board ("FASB") amended revenue recognition rules clarifying several aspects of the new revenue recognition standard, previously issued in May 2014. Occidental is currently evaluating the impact of these rules on its financial statements.

In March 2016, the FASB issued rules affecting entities that issue share-based payment awards to their employees. These rules are designed to simplify several aspects of accounting for share-based payment award transactions, including: (1) accounting and cash flow classification for excess tax benefits and deficiencies, (2) forfeitures, and (3) tax withholding requirements and cash flow classification. The rules were adopted for the second quarter of 2016 and did not have a material impact on Occidental's financial statements upon adoption.

In March 2016, the FASB issued an update to eliminate the requirement to retrospectively adopt the equity method of accounting if an investment qualifies for use of the equity method as a result of an increase in the level of ownership or degree of influence. The update requires that the equity method investor add the cost of acquiring the additional interest and adopt the equity method of accounting as of the date the investment becomes qualified for equity method accounting. The rules become effective for the interim and annual periods beginning after December 15, 2016. The rules do not have a material impact on Occidental's financial statements upon adoption.

In March 2016, the FASB issued rules clarifying that a change in one of the parties to a derivative contract that is part of a hedge accounting relationship does not, by itself, require dedesignation of that relationship, as long as all other hedge accounting criteria continue to be met. The rules become effective for the interim and annual periods beginning after December 15, 2016. Occidental is currently evaluating the impact of these rules on its financial statements.

In February 2016, the FASB issued rules in which lessees will recognize most leases, including operating leases, on-balance sheet. These new rules will significantly increase reported assets and liabilities. The rules become effective for interim and annual periods beginning after December 15, 2018. Occidental is currently evaluating the impact of these rules on its financial statements.

In April 2015, the FASB issued rules simplifying the presentation of debt issuance costs. The new rules require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Occidental adopted these rules retrospectively as of January 1, 2016. The rules do not have a material impact on Occidental's financial statements.

4. Supplemental Cash Flow Information

Occidental paid foreign, state and federal income taxes of $288 million and $638 million during the six months ended June 30, 2016 and 2015, respectively. During the second quarter of 2016, Occidental received federal income tax refunds of $302 million as a result of the carryback of net operating losses generated in 2015. Interest paid totaled $154 million and $108 million in each of the six months ended June 30, 2016 and 2015, 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, 2016, and December 31, 2015, consisted of the following (in millions):



	2016			2015

Raw materials	$	73		$	73
Materials and supplies	502			568
Finished goods	381			395
	956			1,036

Revaluation to LIFO	(50		)	(50		)
Total	$	906		$	986

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 of hazardous substances; or operation and maintenance of remedial systems. These 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, 2016, Occidental participated in or monitored remedial activities or proceedings at 145 sites. The following table presents Occidental’s environmental remediation reserves as of June 30, 2016, the current portion of which is included in accrued liabilities ($70 million) and the remainder in deferred credits and other liabilities — other ($309 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	$	27
Third-party sites	65	128
Occidental-operated sites	17	102
Closed or non-operated Occidental sites	30	122
Total	145	$	379

As of June 30, 2016, Occidental’s environmental reserves exceeded $10 million each at 11 of the 145 sites described above, and 94 of the sites each had reserves of $1 million or less. 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.

Due to the uncertainties surrounding the Maxus-indemnified sites described further under Note 7, Lawsuits, Claims, Commitments and Contingencies, Occidental is currently unable to estimate an amount of reasonably possible losses

associated with these sites. For all other sites, Occidental believes its estimable range of reasonably possible additional losses beyond those liabilities recorded for environmental remediation at these sites could be up to $370 million. For additional information regarding 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 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.

During 2014, a New Jersey state court approved Occidental's settlement with the State of New Jersey (the State) to resolve claims asserted by the State against Occidental arising from Occidental’s acquisition of Diamond Shamrock Chemicals Company (DSCC) in 1986. Pursuant to the settlement agreement (the State Settlement), Occidental paid the State $190 million in 2015. As part of the State Settlement, Occidental agreed, under certain circumstances, to perform or fund future work on behalf of the State along a portion of the Passaic River. The State Settlement does not cover any potential Occidental share of costs associated with the EPA’s proposed clean-up plan of the Passaic River as set out in its March 4, 2016 Record of Decision (ROD). During the second quarter of 2016, the EPA sent Occidental a draft Administrative Order on Consent to complete the design of the proposed clean-up plan outlined in the ROD. Negotiations with the EPA are ongoing.

When Occidental acquired DSCC, Maxus Energy Corporation (Maxus), currently a subsidiary of YPF S.A. (YPF), agreed to a broad indemnity for a number of environmental sites, including the Diamond Alkali Superfund Site, which is at issue in the State Settlement and the ROD. As a result, Occidental has been pursuing Maxus and its parent company, YPF, as the alter ego of Maxus, to recover the costs paid by Occidental under the State Settlement and other indemnified costs. Trial on Occidental’s claims against Maxus and YPF was scheduled to begin on June 21, 2016. On June 17, 2016, Maxus and several affiliated companies filed for Chapter 11 bankruptcy in Federal District Court in the State of Delaware. Occidental is continuing to pursue claims against Maxus and YPF in the bankruptcy court and other appropriate forums. Prior to filing for bankruptcy, Maxus defended and indemnified Occidental in connection with federal clean-up and other costs associated with the Diamond Alkali Superfund Site and other sites.

Occidental also evaluates the amount of reasonably possible losses that it could incur as a result of outstanding lawsuits, claims and proceedings and has disclosed its estimable range of reasonably possible additional losses for sites where it is a participant in environmental remediation. Occidental believes that other reasonably possible losses for non-environmental matters 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. Occidental's potential obligations for the Maxus-indemnified sites described above, including any potential share of costs associated with the ROD for the Passaic River, are not currently included in such estimates, as the amounts cannot be reasonably estimated at this time for several reasons, including, but not limited to, the existence of other potentially responsible parties, the presence of contaminants of concern that are not associated with DSCC or Occidental's operations, the inherent uncertainties in estimating clean-up costs and the Maxus bankruptcy filing.

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 that are subject to IRS review. Taxable years from 2002 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, 2016, 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 Post-retirement Benefit Plans

The following tables set forth the components of the net periodic benefit costs for Occidental’s defined benefit pension and post-retirement benefit plans for the three and six months ended June 30, 2016 and 2015 (in millions):



Three months ended June 30	2016					2015
Net Periodic Benefit Costs	Pension Benefit			Post-retirement Benefit		Pension Benefit			Post-retirement Benefit
Service cost	$	2		$	5	$	2		$	7
Interest cost	4			10		5			10
Expected return on plan assets	(6		)	—		(7		)	—
Recognized actuarial loss	3			6		2			7
Settlement loss	2			—		—			—
Total	$	5		$	21	$	2		$	24



Six months ended June 30	2016					2015
Net Periodic Benefit Costs	Pension Benefit			Post-retirement Benefit		Pension Benefit			Post-retirement Benefit
Service cost	$	4		$	10	$	4		$	14
Interest cost	8			20		10			20
Expected return on plan assets	(12		)	—		(14		)	—
Recognized actuarial loss	6			11		4			14
Settlement loss	2			—		—			—
Total	$	8		$	41	$	4		$	48

Occidental contributed approximately $1 million and zero in the three months ended June 30, 2016 and 2015, respectively, and approximately $2 million and $5 million in the six months ended June 30, 2016 and 2015, respectively, to its defined benefit 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 the assets or liabilities; Level 2 — using observable inputs other than quoted prices for the assets or liabilities; and Level 3 — using unobservable inputs. Transfers between levels, if any, are recognized at the end of each reporting period.

Fair Values — Recurring

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	Occidental values exchange-cleared commodity derivatives using closing prices provided by the exchange as of the balance sheet date. Occidental values its available for sale investment based on the common stock closing share price as of the balance sheet date. These derivatives and investments 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 classified as Level 2 and 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 values 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 generally unobservable in the marketplace or are observable but have been adjusted based upon various assumptions, and the fair value is designated as Level 3 within the valuation hierarchy.

Occidental generally uses an income approach to measure fair value when observable inputs are unavailable. 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, 2016 and December 31, 2015 (in millions):



Fair Value Measurements at June 30, 2016:
Description	Level 1		Level 2		Level 3		Netting and Collateral			Total Fair Value
Assets:
Commodity derivatives	$	94	$	31	$	—	$	(85	)	$	40
Liabilities:
Commodity derivatives	$	116	$	304	$	—	$	(100	)	$	320



Fair Value Measurements at December 31, 2015:
Description	Level 1		Level 2		Level 3		Netting and Collateral			Total Fair Value
Assets:
Commodity derivatives	$	557	$	87	$	—	$	(535	)	$	109
Available for sale investment	$	167	$	—	$	—	$	—		$	167
Liabilities:
Commodity derivatives	$	544	$	404	$	—	$	(525	)	$	423

Fair Values — Nonrecurring

During the three and six months ended June 30, 2016, Occidental did not have any assets or liabilities measured at fair value on a nonrecurring basis. The following table provides fair value measurement for such proved domestic and international oil and gas properties that are measured on a nonrecurring basis as of December 31, 2015. 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 as of balance sheet date and, where applicable, contractual prices, estimates of oil and gas reserves, estimates of future expected operating and development costs, and a risk adjusted discount rate of 8 to 20 percent. These properties were impacted by persistently low worldwide oil and natural gas prices and changing 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.



(in millions)	Fair Value Measurements at December 31, 2015 Using						Net Book Value			Total Pre-tax (Non-cash) Impairment Loss

Description	Level 1		Level 2		Level 3				^(a)
Assets:
Impaired proved oil and gas assets - international	$	—	$	—	$	2,666	$	7,359		$	4,693
Impaired proved oil and gas assets - domestic	$	—	$	—	$	625	$	1,655		$	1,030
Impaired Midstream assets	$	—	$	—	$	50	$	891		$	841
Impaired Chemical property, plant, and equipment	$	—	$	—	$	3	$	124		$	121

(a) Amount represents net book value at date of assessment.

Other Financial Instruments

The carrying amounts of cash and cash equivalents and other on-balance-sheet financial instruments, other than long-term fixed-rate debt, approximate fair value. The cost, if any, to terminate Occidental's off-balance-sheet financial instruments is not significant. Occidental estimates the fair value of fixed-rate debt based on the quoted market prices for those instruments or on quoted market yields for similarly rated debt instruments, taking into account such instruments’ maturities. The estimated fair value of Occidental’s debt as of June 30, 2016,and December 31, 2015, was $9.1 billion and $8.4 billion, respectively, and its carrying value net of unamortized discount as of June 30, 2016 and December 31, 2015, was $8.3 billion. The majority of Occidental's debt is classified as Level 1, with $273 million classified as Level 2.

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 obtain 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, the volumes are usually insignificant.

Cash-Flow Hedges

Occidental's marketing and trading operations, from time to time, 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 2017. As of June 30, 2016, Occidental had approximately 6 billion cubic feet of natural gas held in storage, and had cash-flow hedges for the forecast sale, to be settled by physical delivery, of approximately 6 billion cubic feet of stored natural gas. As of December 31, 2015, Occidental had approximately 13 billion cubic feet of natural gas held in storage, and had cash-flow hedges for the forecast sale, to be settled by physical delivery, of approximately 14 billion cubic feet of stored natural gas. The following table summarizes Occidental’s other comprehensive income related to derivatives for the three and six months ended June 30, 2016 and June 30, 2015:



	After-tax
	Three months ended June 30					Six months ended June 30
	2016			2015		2016			2015
Unrealized losses on derivatives	$	(2	)	$	—	$	(14	)	$	—
Reclassification to income of realized loss on derivatives	$	—		$	—	$	7		$	—

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 June 30, 2016 and December 31, 2015:



	Net Outstanding Position
	Long / (Short)
Commodity	2016		2015
Oil (million barrels)	149		83
Natural gas (billion cubic feet)	(71	)	(58	)
Carbon dioxide(billion cubic feet)	571		603

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 excluded contracts do not expose Occidental to price risk because the contract prices fluctuate with index prices.

Occidental fulfills short positions through its own production or by third-party purchase contracts. Subsequent to June 30, 2016, Occidental entered into purchase contracts for a substantial portion of the short positions outstanding at quarter end and has sufficient production capacity and the ability to enter into additional purchase contracts to satisfy the remaining positions.

Approximately $38 million and $45 million of net gains from derivatives not designated as hedging instruments were recognized in net sales for the three months ended June 30, 2016 and 2015, respectively. Approximately $26 million of net gains and $44 million of net losses from derivatives not designated as hedging instruments were recognized in net sales for the six months ended June 30, 2016 and 2015, respectively.

Fair Value of Derivatives

The following table presents the gross and net fair values of Occidental’s outstanding derivatives as of June 30, 2016 and December 31, 2015 (in millions):



	Asset Derivatives	Fair			Liability Derivatives	Fair
June 30, 2016	Balance Sheet Location	Value			Balance Sheet Location	Value
Cash-flow hedges^(a)
Commodity contracts	Other current assets	$	—		Accrued liabilities	$	4

Derivatives not designated as hedging instruments ^(a)
Commodity contracts	Other current assets	117			Accrued liabilities	190
Commodity contracts	Long-term receivables and other assets, net	8			Deferred credits and other liabilities	227
		125				417
Total gross fair value		125				421
Less: counterparty netting and cash collateral ^(b,d)		(85		)		(101		)
Total net fair value of derivatives		$	40			$	320



	Asset Derivatives	Fair			Liability Derivatives	Fair
December 31, 2015	Balance Sheet Location	Value			Balance Sheet Location	Value
Cash-flow hedges^(a)
Commodity contracts	Other current assets	$	9		Accrued liabilities	$	1

Derivatives not designated as hedging instruments ^(a)
Commodity contracts	Other current assets	626			Accrued liabilities	672
Commodity contracts	Long-term receivables and other assets, net	9			Deferred credits and other liabilities	275
		635				947
Total gross fair value		644				948
Less: counterparty netting and cash collateral ^(c,d)		(535		)		(525		)
Total net fair value of derivatives		$	109			$	423


(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 June 30, 2016, collateral received of zero has been netted against the derivative assets, and collateral paid of $15 million has been netted against derivative liabilities.


(c)	As of December 31, 2015, collateral received of $14 million has been netted against derivative assets, and collateral paid of $4 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 $44 million and $3 million deposited by Occidental has not been reflected in these derivative fair value tables as of June 30, 2016 and December 31, 2015, respectively. This collateral is included in other current assets in the consolidated balance sheets as of June 30, 2016 and December 31, 2015, respectively.

See Note 9, Fair Value Measurements, for fair value measurement disclosures on derivatives.

Credit Risk

The majority of Occidental's counterparty credit risk is related to the physical delivery of energy commodities to its customers and their inability to meet their settlement commitments. Occidental manages this credit risk by selecting counterparties that it believes to be financially strong, by entering into master netting arrangements with counterparties and by requiring collateral, as appropriate. Occidental actively reviews the creditworthiness of its counterparties and monitors credit exposures against assigned credit limits by adjusting credit limits to reflect counterparty risk, if necessary. Occidental also enters into future contracts through regulated exchanges with select clearinghouses and brokers, which are subject to minimal credit risk as a significant portion of these transactions settle on a daily margin basis.

Certain 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. 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, 2016 and December 31, 2015.

11. Industry Segments

Occidental conducts its 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, natural gas liquids (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. Additionally, the midstream and marketing segment invests in entities that conduct similar activities.

Results 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 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.

The following tables present Occidental’s industry segments (in millions):



	Oil					Midstream			Corporate
	and					and			and
	Gas			Chemical		Marketing			Eliminations				Total
Three months ended June 30, 2016
Net sales	$	1,625		$	908	$	141		$	(143	)		$	2,531
Pre-tax operating profit (loss)	$	(117	)	$	88	$	(58	)	$	(145	)	^(a)	$	(232	)
Income taxes	—			—		—			96			^(b)	96
Discontinued operations, net	—			—		—			(3		)		(3		)
Net income (loss)	$	(117	)	$	88	$	(58	)	$	(52	)		$	(139	)

Three months ended June 30, 2015
Net sales	$	2,342		$	1,030	$	294		$	(197	)		$	3,469
Pre-tax operating profit (loss)	$	355		$	136	$	87		$	(74	)	^(a)	$	504
Income taxes	—			—		—			(324		)	^(b)	(324		)
Discontinued operations, net	—			—		—			(4		)		(4		)
Net income (loss)	$	355		$	136	$	87		$	(402	)		$	176



	Oil						Midstream			Corporate
	and						and			and
	Gas				Chemical		Marketing			Eliminations				Total
Six months ended June 30, 2016
Net sales	$	2,900			$	1,798	$	274		$	(318	)		$	4,654
Pre-tax operating profit (loss)	$	(602	)		$	302	$	(153	)	$	(342	)	^(a)	$	(795	)
Income taxes	—				—		—			299			^(b)	299
Discontinued operations, net	—				—		—			435				435
Net income (loss)	$	(602	)		$	302	$	(153	)	$	392			$	(61	)

Six months ended June 30, 2015
Net sales	$	4,351			$	2,030	$	491		$	(314	)		$	6,558
Pre-tax operating profit (loss)	$	89		^(c)	$	275	$	72		$	(166	)	^(a,c)	$	270
Income taxes	—				—		—			(305		)	^(b)	(305		)
Discontinued operations, net	—				—		—			(7		)		(7		)
Net income (loss)	$	89			$	275	$	72		$	(478	)		$	(42	)

(a) Includes unallocated net interest expense, administration expense, environmental remediation and other pre-tax items.

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

(c) Includes pre-tax charges of $310 million for the impairment of certain domestic and international oil and gas assets and other items and $14 million of corporate other items.

12. 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, net income allocated to these participating securities has 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.

The following table presents the calculation of basic and diluted EPS for the three and six months ended June 30, 2016 and 2015 (in millions, except per-share amounts):



	Three months ended June 30						Six months ended June 30
	Three months ended June 30						Six months ended June 30
	2016			2015			2016			2015
Basic EPS
Income (loss) from continuing operations	$	(136	)	$	180		$	(496	)	$	(35	)
Discontinued operations, net	(3		)	(4		)	435			(7		)
Net income (loss)	(139		)	176			(61		)	(42		)

Less: Net income allocated to participating securities	—			—			—			—
Net income (loss), net of participating securities	(139		)	176			(61		)	(42		)

Weighted average number of basic shares	763.6			766.4			763.5			768.0
Basic EPS	$	(0.18	)	$	0.23		$	(0.08	)	$	(0.05	)

Diluted EPS
Net income (loss), net of participating securities	$	(139	)	$	176		$	(61	)	$	(42	)
Weighted average number of basic shares	763.6			766.4			763.5			768.0
Dilutive effect of potentially dilutive securities	—			0.2			—			—
Total diluted weighted average common shares	763.6			766.6			763.5			768.0
Diluted EPS	$	(0.18	)	$	0.23		$	(0.08	)	$	(0.05	)

Item 2.Management’s Discussion and Analysis of Financial Condition and 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). 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 from anticipated results, sometimes materially, and reported results should not be considered an indication of future performance. Factors that could cause results to differ include, but are not limited to: global commodity pricing fluctuations; supply and demand considerations for Occidental’s products; higher-than-expected costs; the regulatory approval environment; reorganization or restructuring of Occidental’s operations; not successfully completing, or any material delay of, field developments, expansion projects, capital expenditures, efficiency projects, acquisitions or dispositions; uncertainties about the estimated quantities of oil and natural gas reserves; 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 including 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 Occidental's Annual Report on Form 10-K for the year ended December 31, 2015 (the 2015 Form 10-K).

Consolidated Results of Operations

Occidental reported a net loss from continuing operations of $136 million for the second quarter of 2016 on net sales of $2.5 billion, compared to net income from continuing operations of $180 million on net sales of $3.5 billion for the second quarter of 2015. Diluted loss per share from continuing operations was $0.18 for the second quarter of 2016, compared to diluted earnings of $0.23 per share for the second quarter of 2015.

Occidental reported a net loss from continuing operations of $496 million for the first six months of 2016 on net sales of $4.7 billion, compared to a net loss of $35 million on net sales of $6.6 billion for the same period in 2015. Diluted loss per share from continuing operations was $0.65 per share for the first six months of 2016, compared to a loss per share of $0.04 for the same period of 2015. Income from discontinued operations was $435 million or $0.57 per share for the first six months of 2016, compared with a loss of $7 million or $0.01 per share for the same period of 2015.

The net losses from continuing operations in the three and six months ended June 30, 2016, when compared to the same periods in 2015, reflect the impact of lower realized commodity prices in the oil and gas and chemical segments and lower marketing margins due to unfavorable Permian to Gulf Coast differentials. The lower prices were partially offset by lower per-barrel operating costs and lower chemical raw material and energy costs. Income from discontinued operations for the six months ended June 30, 2016, resulted from the settlement from the Republic of Ecuador under a November 2015 arbitration award.

Selected Statements of Operations Items

Net sales decreased for the three and six months ended June 30, 2016, compared to the same periods in 2015, due to lower realized commodity prices. Gain (loss) on sale of assets, net, for the six months ended June 30, 2016, primarily reflected a gain on the sale of the Piceance Basin operations in Colorado of $121 million and a gain on the sale of the Occidental Tower building in Dallas of $57 million.

Compared to the same periods in 2015, cost of sales for the three and six months ended June 30, 2016 reflected lower oil and gas production costs, mainly from maintenance and support activities and lower raw material and energy costs for the chemical business.

Asset impairments and related items for the six months ended June 30, 2016, reflected impairment charges of $78 million related to the special stock dividend of California Resources shares. Asset impairments and related items

for the six months ended June 30, 2015, reflected impairment charges for Occidental's South Texas Eagle Ford non-operated properties, investments in Yemen, mark-to-market losses on a CO₂ purchase contract and rig idling and termination fees.

Lower taxes other than on income for the three and six months ended June 30, 2016, compared to the same periods of 2015, reflected lower production and ad valorem taxes, which are mostly tied to oil and gas prices.

Higher interest and debt expense, net for the three and six months ended June 30, 2016, compared to the same periods of 2015, reflected lower capitalized interest as well as additional interest accrued for senior notes issued in April 2016 and a premium on the early retirement in May 2016 of the $1.25 billion of 1.75-percent senior notes due February 2017.

The domestic and foreign income tax benefit for the three and six months ended June 30, 2016, compared to income tax provisions in the same periods of 2015, are due to higher pre-tax operating losses in 2016 compared to 2015 and the relinquishment of foreign exploration blocks.

Selected Analysis of Financial Position

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

The increase in trade receivables, net, at June 30, 2016, compared to December 31, 2015, was due to an increase in oil and gas realized prices. The decrease in assets held for sale and available for sale investment reflect the sale of Piceance operations in Colorado and the Occidental Tower in Dallas, and the distribution of Occidental's remaining California Resources common stock to its shareholders. The increase in investments in unconsolidated entities is primarily a result of capital contributions associated with the joint venture for the ethylene cracker at the OxyChem Ingleside facility. The decrease in property, plant and equipment, net, is primarily the result of DD&A, offset partially by Occidental's capital spending of $1.2 billion in the first half of 2016.

Current maturities of long-term debt at June 30, 2016, decreased from December 31, 2015, due to the payments of $700 million 2.5-percent senior notes due February 2016 and $750 million 4.125-percent senior notes due June 2016. The increase in long-term debt, net since December 31, 2015 is the result of the issuance of $2.75 billion of senior notes in April 2016, partially offset by the early redemption in May 2016 of $1.25 billion 1.75-percent senior notes due February 2017.

The decrease in accrued liabilities at June 30, 2016, is due to first quarter payments of ad-valorem taxes. Liabilities of assets held for sale as of June 30, 2016, decreased due to the sale of Piceance operations in Colorado.

Segment Operations

Occidental conducts its 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. Additionally, the midstream and marketing segment 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, 2016 and 2015 (in millions):



	Three months ended June 30						Six months ended June 30
	2016			2015			2016			2015
Net Sales ^(a)
Oil and Gas	$	1,625		$	2,342		$	2,900		$	4,351
Chemical	908			1,030			1,798			2,030
Midstream and Marketing	141			294			274			491
Eliminations	(143		)	(197		)	(318		)	(314		)
	$	2,531		$	3,469		$	4,654		$	6,558
Segment Results ^(b)
Oil and Gas	$	(117	)	$	355		$	(602	)	$	89
Chemical	88			136			302			275
Midstream and Marketing	(58		)	87			(153		)	72
	(87		)	578			(453		)	436
Unallocated Corporate Items ^(b)
Interest expense, net	(84		)	(7		)	(141		)	(35		)
Income tax benefit (provision)	96			(324		)	299			(305		)
Other expense, net	(61		)	(67		)	(201		)	(131		)

Income (loss) from continuing operations	(136		)	180			(496		)	(35		)
Discontinued operations, net	(3		)	(4		)	435			(7		)
Net Income (loss)	$	(139	)	$	176		$	(61	)	$	(42	)

(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 significant transactions and events affecting Occidental’s earnings that vary widely and unpredictably in nature, timing and amount for the three and six months ended June 30, 2016 and 2015 (in millions):



	Three months ended June 30						Six months ended June 30
	2016			2015			2016			2015

Oil and Gas
Asset sales gains and other	$	—		$	18		$	23		$	5
Asset impairments and related items - Domestic	—			14			—			(250		)
Asset impairments and related items - International	—			(1		)	—			(47		)
Total Oil and Gas	$	—		$	31		$	23		$	(292	)

Chemical
Asset sales gains	$	—		$	—		$	88		$	—
Total Chemical	$	—		$	—		$	88		$	—

Midstream and Marketing
Total Midstream and Marketing	$	—		$	3		$	—		$	(7	)

Corporate
Asset impairments and related items	—			—			(78		)	—
Spin-off costs and related items	—			(6		)	—			(20		)
Asset sales losses	—			—			—			(11		)
Tax effect of pre-tax adjustments ^(a)	—			(13		)	33			99
Discontinued operations, net ^(b)	(3		)	(4		)	435			(7		)
Total Corporate	$	(3	)	$	(23	)	$	390		$	61

Total	$	(3	)	$	11		$	501		$	(238	)

(a) The 2016 amount included benefits for the relinquishment of foreign exploration blocks.

(b) 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, 2016 and 2015 (in millions):



	Three months ended June 30						Six months ended June 30
	2016			2015			2016			2015

Oil and Gas results	$	(117	)	$	355		$	(602	)	$	89
Chemical results	88			136			302			275
Midstream and Marketing results	(58		)	87			(153		)	72
Unallocated corporate items	(145		)	(74		)	(342		)	(166		)
Pre-tax income (loss)	(232		)	504			(795		)	270

Income tax benefit (provision)
Federal and state	234			47			525			172
Foreign	(138		)	(371		)	(226		)	(477		)
Total	96			(324		)	299			(305		)

Income (loss) from continuing operations	$	(136	)	$	180		$	(496	)	$	(35	)

Worldwide effective tax rate	41		%	64		%	38		%	113		%

Occidental's worldwide effective tax rate of 38 percent for the six months ended June 30, 2016 is lower than the comparative period of 2015 due to the mix of domestic operating losses and foreign operating income, as well as the current year domestic tax benefit associated with the relinquishment of foreign exploration blocks. Excluding the impact of asset sales and other nonrecurring items, Occidental's worldwide effective tax rate for the six months ended June 30, 2016 would be 32 percent.

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, 2016 and 2015. The differences between the production and sales volumes per day are generally due to the timing of shipments at Occidental’s international locations where the product is loaded onto tankers.



	Three months ended June 30		Six months ended June 30
Production Volumes per Day	2016	2015	2016	2015

Oil (MBBL)
United States	190	205	193	201
Middle East/North Africa	168	188	175	189
Latin America	34	40	36	39
NGLs (MBBL)
United States	52	55	54	55
Middle East/North Africa	30	12	26	11
Natural Gas (MMCF)
United States	357	437	372	441
Middle East/North Africa	708	498	648	488
Latin America	8	10	8	11
Total Production Volumes (MBOE) ^(a)	653	658	655	652

	Three months ended June 30		Six months ended June 30
Sales Volumes per Day	2016	2015	2016	2015

Oil (MBBL)
United States	190	205	193	201
Middle East/North Africa	172	192	177	188
Latin America	38	35	36	35
NGLs (MBBL)
United States	52	55	54	55
Middle East/North Africa	29	12	25	11
Natural Gas (MMCF)
United States	357	437	372	441
Middle East/North Africa	708	498	648	488
Latin America	8	10	8	11
Total Sales Volumes (MBOE)^(a⁾	660	657	656	647

(See footnote following the table below)

The following tables set forth the production and sales volumes of ongoing operations for oil, NGLs and natural gas per day for the three and six months ended June 30, 2016 and 2015, this excludes operations sold, exited or exiting.



	Three months ended June 30		Six months ended June 30
Production Volumes per Day	2016	2015	2016	2015

Oil (MBBL)
United States ^(b)	190	188	193	184
Middle East/North Africa ^(c)	162	157	162	154
Latin America	34	40	36	39
NGLs (MBBL)
United States ^(b)	52	51	53	51
Middle East/North Africa	30	12	26	11
Natural Gas (MMCF)
United States ^(b)	357	357	350	358
Middle East/North Africa ^(c)	481	258	420	246
Latin America	8	10	8	11
Total Production Ongoing Operations (MBOE)	609	552	599	542
Operations Sold, Exited and Exiting	44	106	56	110
Total Production Volumes (MBOE) ^(a)	653	658	655	652

	Three months ended June 30		Six months ended June 30
Sales Volumes per Day	2016	2015	2016	2015

Oil (MBBL)
United States ^(b)	190	188	193	184
Middle East/North Africa ^(d)	166	157	164	156
Latin America	38	35	36	35
NGLs (MBBL)
United States ^(b)	52	51	53	51
Middle East/North Africa	29	12	25	11
Natural Gas (MMCF)
United States ^(b)	357	357	350	358
Middle East/North Africa ^(d)	481	258	420	246
Latin America	8	10	8	11
Total Sales Ongoing Operations (MBOE)	616	547	600	540
Operations Sold, Exited and Exiting	44	110	56	107
Total Sales Volumes (MBOE)^(a⁾	660	657	656	647

Note: MBBL represents thousand barrels. MMCF represents million cubic feet.

(a) Natural gas volumes have been converted to thousands of barrels of oil equivalent (MBOE) based on energy content of six million cubic feet (MMCF) of gas to one thousand barrels of oil (MBOE). Barrels of oil equivalence does not necessarily result in price equivalence.

(b) Excludes 17 MBBL, 4 MBBL and 80 MMCF of oil, NGLs and gas for the three months ended June 30, 2015 related to Williston and Piceance. Excludes 22 MMCF of gas for the six months ended June 30, 2016, related to Piceance and 17 MBBL, 4 MBBL and 83 MMCF of oil, NGLs, and gas for the six months ended June 30, 2015, related to Williston and Piceance.

(c) Excludes 6 MBBL and 227 MMCF of oil and gas for the three months ended June 30, 2016 and 31 MMBL and 240 MMCF of oil and gas for the three months ended June 30, 2015, related to Bahrain, Iraq and Yemen. Excludes 13 MBBL and 228 MMCF of oil and gas for the six months ended June 30, 2016, and 35 MMBL and 242 MMCF of oil and gas for the six months ended June 30, 2015, related to Bahrain, Iraq and Yemen.

(d) Excludes 6 MBBL and 227 MMCF of oil and gas for the three months ended June 30, 2016 and 35 MMBL and 240 MMCF of oil and gas for the three months ended June 30, 2015, related to Bahrain, Iraq and Yemen. Excludes 13 MBBL and 228 MMCF of oil and gas for the six months ended June 30, 2016, and 32 MMBL and 242 MMCF of oil and gas for the six months ended June 30, 2015, related to Bahrain, Iraq and Yemen.

The following tables present information about Occidental's average realized prices and index prices for the three and six months ended June 30, 2016 and 2015:



	Three months ended June 30				Six months ended June 30
Average Realized Prices	2016		2015		2016		2015
Oil ($/BBL)
United States	$	41.43	$	52.64	$	35.33	$	48.25
Middle East/North Africa	$	37.80	$	56.48	$	33.66	$	55.27
Latin America	$	39.26	$	55.19	$	33.72	$	51.43
Total Worldwide	$	39.66	$	54.55	$	34.46	$	51.60
NGLs ($/BBL)
United States	$	14.25	$	17.32	$	12.04	$	17.32
Middle East/North Africa	$	15.21	$	21.38	$	14.38	$	21.46
Total Worldwide	$	14.59	$	18.06	$	12.80	$	18.01
Natural Gas ($/MCF)
United States	$	1.46	$	2.09	$	1.48	$	2.29
Latin America	$	3.36	$	5.49	$	3.76	$	4.98
Total Worldwide	$	1.26	$	1.48	$	1.26	$	1.57



	Three months ended June 30				Six months ended June 30
Average Index Prices	2016		2015		2016		2015
WTI oil ($/BBL)	$	45.59	$	57.94	$	39.52	$	53.29
Brent oil ($/BBL)	$	46.97	$	63.50	$	41.03	$	59.33
NYMEX gas ($/MCF)	$	1.97	$	2.73	$	2.02	$	2.90



Average Realized Prices as Percentage of Average Index Prices	Three months ended June 30				Six months ended June 30
	2016		2015		2016		2015
Worldwide oil as a percentage of average WTI	87	%	94	%	87	%	97	%
Worldwide oil as a percentage of average Brent	84	%	86	%	84	%	87	%
Worldwide NGLs as a percentage of average WTI	32	%	31	%	32	%	34	%
Domestic natural gas as a percentage of average NYMEX	74	%	77	%	73	%	79	%

Oil and gas segment losses were $117 million for the second quarter of 2016, compared with segment earnings of $355 million for the second quarter of 2015. The decrease in earnings was mainly due to lower commodity prices for all products, partially offset by lower operating costs.

Total average daily production volumes were 653,000 BOE for the second quarter of 2016 compared to 658,000 BOE for the second quarter of 2015. Occidental completed the sale of the Piceance Basin assets on March 1, 2016, and continues to reduce its exposure to non-core operations in the Middle East/North Africa, including Bahrain, Iraq and Yemen. These domestic and international operations produced average daily volumes of 44,000 BOE and 106,000 BOE in the second quarters of 2016 and 2015, respectively. For the second quarter of 2016, total company average daily oil and gas production volumes for ongoing operations increased by 57,000 barrels of oil equivalent (BOE) to 609,000 BOE from 552,000 BOE in the second quarter of 2015. Compared to the second quarter of 2015, domestic average daily production for ongoing operations increased by 4,000 BOE to 302,000 BOE in the second quarter of 2016 with Permian Resources increasing by 17,000 BOE, which was partially offset by lower natural gas and NGL production in South Texas. International average daily production for ongoing operations increased to 307,000 BOE in the second quarter of 2016 from 254,000 BOE in the second quarter of 2015. The increase in international production is primarily attributable to Al Hosn, which was not fully operational in the second quarter of 2015, in addition to Oman's Block 62 production which commenced in 2016.

Worldwide commodity prices for the second quarter of 2016 were lower than the second quarter of 2015. The average quarterly WTI and Brent prices decreased to $45.59 per barrel and $46.97 per barrel, respectively, for the second

quarter of 2016, compared to $57.94 per barrel and $63.50 per barrel, respectively, for the second quarter of 2015. Worldwide realized crude oil prices declined by 27 percent to $39.66 per barrel for the second quarter of 2016, compared to $54.55 per barrel in the second quarter of 2015. Worldwide realized NGL prices decreased by 19 percent to $14.59 per barrel in the second quarter of 2016, compared to $18.06 per barrel in the second quarter of 2015. Domestic realized natural gas prices decreased by 30 percent in the second quarter of 2016 to $1.46 per MCF, compared to $2.09 per MCF in the second quarter of 2015.

Oil and gas segment losses were $602 million for the first six months of 2016, compared with segment earnings of $89 million for the same period of 2015. The decrease in earnings was mainly due to lower commodity prices, partially offset by lower operating costs.

Total average daily production volumes for the first six months of 2016 and 2015 were 655,000 BOE and 652,000 BOE, respectively. For the first six months of 2016 and 2015, non-core operations produced average daily volumes of 56,000 BOE and 110,000 BOE, respectively. For the first six months of 2016, total company average daily oil and gas production volumes for ongoing operations increased by 57,000 barrels of oil equivalent (BOE) to 599,000 BOE from 542,000 BOE for the first six months of 2015. Domestic average daily production for ongoing operations increased by 9,000 BOE for the first six months of 2016 as compared to the first six months of 2015 with Permian Resources increasing by 23,000 BOE, which was partially offset by lower natural gas and NGL production in South Texas. International average daily production increased to 295,000 BOE for the first six months of 2016 from 247,000 BOE for the first six months 2015. The increase in international production mainly comes from Al Hosn, which was not fully operational in the first half of 2015.

Worldwide commodity prices for the first six months of 2016 were lower than the same period of 2015. Worldwide realized crude oil prices declined by 33 percent to $34.46 per barrel for the first six months of 2016, compared to $51.60 per barrel for the same period of 2015. Worldwide realized NGL prices decreased by 29 percent to $12.80 per barrel for the first six months of 2016, compared to $18.01 per barrel for the same period of 2015. Domestic realized natural gas prices decreased by 35 percent for the first six months of 2016 to $1.48 per MCF, compared to $2.29 per MCF for the same period of 2015.

Occidental’s financial results correlate closely to the prices it obtains for its products. The weak price environment continues to significantly impact earnings as compared to the same period in 2015. Further declines in these commodity prices may result in additional impairments to reduce the carrying value of Occidental’s oil and gas properties as well as reducing the amount of these commodities that can be produced economically and the quantity and present value of proved reserves.

The calculated average first-day-of-the-month West Texas Intermediate oil price and Henry Hub natural gas price were $40.54 per barrel and $2.25 per MMBtu, respectively, for the first seven months of 2016 as compared to $50.28 per barrel and $2.66 per MMBtu for the twelve months of 2015. To the extent that commodity prices remain at current or lower levels throughout 2016, a portion of proved reserves could be deemed uneconomic and no longer classified as proved.

Chemical Segment

Chemical segment earnings for the three and six months ended June 30, 2016, were $88 million and $302 million, respectively, compared to $136 million and $275 million for the same period of 2015. Excluding gains of $88 million for the sale of chemical assets in the first six months of 2016, the lower earnings in 2016 compared to the same period in 2015 reflected lower average sales prices for most product lines and lower demand for calcium chloride, partially offset with lower ethylene and energy costs.

Midstream and Marketing Segment

Midstream and marketing losses were $58 million and $153 million for the three and six months ended June 30, 2016, respectively, compared to segment earnings of $87 million and $72 million for the same periods of 2015. The lower results reflected lower marketing margins due to unfavorable Permian to Gulf Coast differentials.

Liquidity and Capital Resources

At June 30, 2016, Occidental had $3.8 billion in cash. Income and cash flows are largely dependent on the oil and gas segment's realized prices, sales volumes and operating costs. In the first six months of 2016, Occidental significantly reduced its capital expenditures compared to the prior year period. With a continued reduction in capital expenditures and forecasted operational improvements, Occidental expects to fund its liquidity needs, including future dividend payments, through cash on hand, cash generated from operations, monetization of non-core assets or investments and, if necessary, through future borrowings or proceeds from other forms of capital issuance.

Net cash provided by operating activities was $1.8 billion and $1.4 billion for the six months ended June 30, 2016 and 2015, respectively. The 2016 amount includes $0.9 billion in operating cash flows from discontinued operations related to the Ecuador settlement. Cash flows were negatively impacted by significantly lower realized prices for all oil and natural gas commodities in the first half of 2016 as compared to the same period in 2015; however, operating cost reductions as well as cash receipts of $882 million for the Ecuador settlement and $302 million of federal income tax refunds more than offset the effect of lower commodity prices. 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. The $0.5 billion decrease of working capital was related to the cyclical payments of property taxes and employee costs, payment of liabilities accrued at year-end related to exited or exiting international operations, and decreases in inventory and receivables.

Occidental’s net cash used by investing activities was $1.3 billion for the first six months of 2016, compared to $3.9 billion for the same period of 2015. Capital expenditures for the first six months of 2016 were $1.2 billion of which $0.9 billion was for the oil and gas segment, compared to $3.1 billion for the first six months of 2015 of which $2.7 billion was for the oil and gas segment. The change in capital accrual for both periods reflected amounts paid in the first half of the current year related to capital expenditures incurred and accrued in the fourth quarter of the preceding year. Capital expenditures have been significantly reduced in response to the current commodity price environment.

Occidental’s net cash provided by financing activities was $66 million for the first six months of 2016, compared to $1.5 billion for the same period of 2015. Restricted cash of $1.2 billion and $1.6 billion was used to pay dividends and repay debt in the first six months of 2016 and 2015, respectively. In the first six months of 2016 and 2015, Occidental issued $2.75 billion and $1.5 billion of senior notes, respectively. In the first six months of 2016, Occidental repaid $700 million of 2.5-percent senior notes due February 2016 and $750 million of 4.125-percent senior notes due June 2016, and early redeemed $1.25 billion of 1.75-percent senior notes due February 2017.

As of June 30, 2016, Occidental was in compliance with all covenants of its financing agreements and had substantial capacity for additional unsecured borrowings, the payment of cash dividends and other distributions on, or acquisitions of, Occidental stock.

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.

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 of hazardous substances; or operation and maintenance of remedial systems. These 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.

Refer to Note 6, Environmental Liabilities and Expenditures, in the Notes to the Consolidated Condensed Financial Statements in Part I Item 1 of this Form 10-Q and to the Environmental Liabilities and Expenditures section of

Management’s Discussion and Analysis of Financial Condition and Results of Operations in the 2015 Form 10-K for additional information regarding Occidental’s environmental expenditures.

Lawsuits, Claims, Commitments and Contingencies

Occidental accrues reserves for outstanding lawsuits, claims and proceedings when it is probable that a liability has been incurred and the liability can be reasonably estimated. Occidental has disclosed its reserve balances for environmental matters. Reserve balances for other matters as of June 30, 2016, and December 31, 2015, 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 which 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. For further information, see Note 7, Lawsuits, Claims, Commitments and Contingencies, in the Notes to Consolidated Condensed Financial Statements in Part I Item 1 of this Form 10-Q.

Recently Adopted Accounting and Disclosure Changes

See Note 3, Accounting and Disclosure Changes, in the Notes to Condensed Consolidated Financial Statements in Part I Item 1 of this Form 10-Q.

Item 3.Quantitative and Qualitative Disclosures About Market Risk

For the three and six months ended June 30, 2016, there were no material changes in the information required to be provided under Item 305 of Regulation S-K included under Item 7A, "Quantitative and Qualitative Disclosures About Market Risk" in the 2015 Form 10-K.

Item 4.Controls and Procedures

Occidental's President and Chief Executive Officer and its Senior 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 Senior Vice President and Chief Financial Officer concluded that Occidental's disclosure controls and procedures were effective as of June 30, 2016.

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 first six months of 2016 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 other legal proceedings, see Note 7, Lawsuits, Claims, Commitments and Contingencies in the Notes to Condensed Consolidated Financial Statements, in Part I Item 1 of this Form 10-Q, and Part I Item 3, “Legal Proceedings” in the 2015 Form 10-K.

Item 2.Unregistered Sales of Equity Securities and Use of Proceeds

Share Repurchase Activities

Occidental's share repurchase activities for the six months ended June 30, 2016, 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 ^(a)

First Quarter 2016	103,371	^(b)	$	70.63	—
April 1 - 30, 2016	—		$	—	—
May 1 - 31, 2016	96,449	^(b)	$	76.06	—
June 1 - 30, 2016	—		$	—	—
Second quarter 2016	96,449		76.06		—
Total	199,820		$	73.25	—	63,756,544


(a)	Represents the total number of shares remaining at June 30, 2016, under Occidental's share repurchase program of 185 million shares. The program was initially announced in 2005. The program does not obligate Occidental to acquire any specific number of shares and may be discontinued at any time.


(b)	Includes purchases from the trustee of Occidental's defined contribution savings plan that are not part of publicly announced plans or programs.

Item 5. Other Information

None.

Item 6. Exhibits



10.1	Form of 2016 Occidental Petroleum Corporation 2015 Long-Term Incentive Plan Common Stock Unit Award For Non-Employee Directors.

10.2	Form of 2016 Occidental Petroleum Corporation 2015 Long-Term Incentive Plan Common Stock Award For Non-Employee Directors.

10.3	Form of 2016 Occidental Petroleum Corporation 2015 Long-Term Incentive Plan Restricted Stock Unit Incentive Award.

10.4	Form of 2016 Occidental Petroleum Corporation 2015 Long-Term Incentive Plan Total Shareholder Return Incentive Award.

12	Statement regarding the computation of total enterprise ratios of earnings to fixed charges for the three months ended June 30, 2016 and 2015, and for each of the five years in the period ended December 31, 2015.

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 3, 2016	/s/ Jennifer M. Kirk
		Jennifer M. Kirk
		Vice President, Controller and
		Principal Accounting Officer

EXHIBIT INDEX

EXHIBITS



10.1	Form of 2016 Occidental Petroleum Corporation 2015 Long-Term Incentive Plan Common Stock Unit Award For Non-Employee Directors.

10.2	Form of 2016 Occidental Petroleum Corporation 2015 Long-Term Incentive Plan Common Stock Award For Non-Employee Directors.

10.3	Form of 2016 Occidental Petroleum Corporation 2015 Long-Term Incentive Plan Restricted Stock Unit Incentive Award.

10.4	Form of 2016 Occidental Petroleum Corporation 2015 Long-Term Incentive Plan Total Shareholder Return Incentive Award.

12	Statement regarding the computation of total enterprise ratios of earnings to fixed charges for the three months ended June 30, 2016 and 2015, and for each of the five years in the period ended December 31, 2015.

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.