Edgar Filing: OCCIDENTAL PETROLEUM CORP /DE/

Document

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K



þ Annual Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934		¨ Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
For the fiscal year ended	December 31, 2018	For the transition period from to

Commission File Number 1-9210

Occidental Petroleum Corporation

(Exact name of registrant as specified in its charter)



State or other jurisdiction of incorporation or organization		Delaware
I.R.S. Employer Identification No.		95-4035997
Address of principal executive offices		5 Greenway Plaza, Suite 110, Houston, Texas
Zip Code		77046
Registrant's telephone number, including area code		(713) 215-7000

Securities registered pursuant to Section 12(b) of the Act:



Title of Each Class		Name of Each Exchange on Which Registered
9 1/4% Senior Debentures due 2019		New York Stock Exchange
Common Stock, $0.20 par value		New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes þ No ¨

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act: (Note: Checking the box will not relieve any registrant required to file reports pursuant to Section 13 or 15(d) of the Exchange Act from their obligations under those Sections). Yes ¨ No þ

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. Yes þ No ¨

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

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. þ

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 "large accelerated filer," "accelerated filer" and "smaller reporting company" in Rule 12b-2 of the Exchange Act).



Large Accelerated Filer	þ	Accelerated Filer	¨	Emerging Growth Company	¨
Non-Accelerated Filer	¨	Smaller Reporting Company	¨

If an Emerging Growth Company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

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

The aggregate market value of the registrant's Common Stock held by nonaffiliates of the registrant was approximately $64.0 billion, computed by reference to the closing price on the New York Stock Exchange composite tape of $83.68 per share of Common Stock on June 30, 2018.

At January 31, 2019, there were 749,546,443 shares of Common Stock outstanding, par value $0.20 per share.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the registrant’s definitive Proxy Statement, relating to its May 10, 2019 Annual Meeting of Stockholders, are incorporated by reference into Part III.



	TABLE OF CONTENTS	Page
Part I
Items 1 and 2	Business and Properties.........................................................................................................................................................	3
	General.............................................................................................................................................................................	3
	Oil and Gas Operations....................................................................................................................................................	3
	Chemical Operations........................................................................................................................................................	4
	Midstream and Marketing Operations...............................................................................................................................	5
	Capital Expenditures.........................................................................................................................................................	5
	Employees........................................................................................................................................................................	5
	Environmental Regulation.................................................................................................................................................	5
	Available Information.........................................................................................................................................................	5
Item 1A	Risk Factors............................................................................................................................................................................	6
Item 1B	Unresolved Staff Comments...................................................................................................................................................	9
Item 3	Legal Proceedings..................................................................................................................................................................	9
Item 4	Mine Safety Disclosures.........................................................................................................................................................	9
	Executive Officers...................................................................................................................................................................	10
Part II
Item 5	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities..............	10
Item 6	Selected Financial Data..........................................................................................................................................................	12
Item 7	Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A).....................................	13
	Strategy.............................................................................................................................................................................	13
	Oil and Gas Segment........................................................................................................................................................	14
	Chemical Segment............................................................................................................................................................	20
	Midstream and Marketing Segment..................................................................................................................................	21
	Segment Results of Operations and Significant Items Affecting Earnings........................................................................	22
	Taxes.................................................................................................................................................................................	24
	Consolidated Results of Operations.................................................................................................................................	24
	Consolidated Analysis of Financial Position......................................................................................................................	26
	Liquidity and Capital Resources.......................................................................................................................................	26
	Off-Balance-Sheet Arrangements.....................................................................................................................................	28
	Contractual Obligations.....................................................................................................................................................	28
	Lawsuits, Claims and Contingencies................................................................................................................................	28
	Environmental Liabilities and Expenditures......................................................................................................................	29
	International Investments..................................................................................................................................................	31
	Critical Accounting Policies and Estimates.......................................................................................................................	31
	Significant Accounting and Disclosure Changes...............................................................................................................	34
	Safe Harbor Discussion Regarding Outlook and Other Forward-Looking Data................................................................	34
Item 7A	Quantitative and Qualitative Disclosures About Market Risk..................................................................................................	34
Item 8	Financial Statements and Supplementary Data.....................................................................................................................	36
	Report of Independent Registered Public Accounting Firm on Consolidated Financial Statements.................................	36
	Report of Independent Registered Public Accounting Firm on Internal Control Over Financial Reporting.......................	37
	Consolidated Balance Sheets...........................................................................................................................................	38
	Consolidated Statements of Operations...........................................................................................................................	40
	Consolidated Statements of Comprehensive Income.......................................................................................................	41
	Consolidated Statements of Stockholders' Equity.............................................................................................................	42
	Consolidated Statements of Cash Flows..........................................................................................................................	43
	Notes to Consolidated Financial Statements....................................................................................................................	44
	Quarterly Financial Data (Unaudited)................................................................................................................................	74
	Supplemental Oil and Gas Information (Unaudited).........................................................................................................	76
	Schedule II – Valuation and Qualifying Accounts..............................................................................................................	92
Item 9	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.................................................	93
Item 9A	Controls and Procedures........................................................................................................................................................	93
	Management's Annual Assessment of and Report on Internal Control Over Financial Reporting....................................	93
	Disclosure Controls and Procedures.................................................................................................................................	93
Item 9B	Other Information....................................................................................................................................................................	93
Part III
Item 10	Directors, Executive Officers and Corporate Governance......................................................................................................	93
Item 11	Executive Compensation........................................................................................................................................................	94
Item 12	Security Ownership of Certain Beneficial Owners and Management ....................................................................................	94
Item 13	Certain Relationships and Related Transactions and Director Independence.......................................................................	94
Item 14	Principal Accounting Fees and Services................................................................................................................................	94
Part IV
Item 15	Exhibits and Financial Statement Schedules.........................................................................................................................	94
Item 16	Form 10-K Summary..............................................................................................................................................................	96

Part I

ITEMS 1 AND 2 BUSINESS AND PROPERTIES

In this report, "Occidental" means Occidental Petroleum Corporation, a Delaware corporation (OPC) incorporated in 1986, or OPC and one or more entities in which it owns a controlling interest (subsidiaries). Occidental conducts its operations through various subsidiaries and affiliates. Occidental’s executive offices are located at 5 Greenway Plaza, Suite 110, Houston, Texas 77046; telephone (713) 215-7000.

GENERAL

Occidental’s principal businesses consist of three segments. The oil and gas segment explores for, develops and produces oil and condensate, natural gas liquids (NGL) and natural gas. The chemical segment (OxyChem) mainly manufactures and markets basic chemicals and vinyls. The midstream and marketing segment purchases, markets, gathers, processes, transports and stores oil, condensate, NGL, natural gas, carbon dioxide (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.

For information regarding Occidental's segments, geographic areas of operation and current developments, including strategies and actions related thereto, see the information in the "Management’s Discussion and Analysis of Financial Condition and Results of Operations" (MD&A) section of this report and Note 17 to the Consolidated Financial Statements.

OIL AND GAS OPERATIONS

General

Occidental’s domestic upstream oil and gas operations are located in Texas and New Mexico. International operations are located in Colombia, Oman, United Arab Emirates (UAE) and Qatar.

Proved Reserves and Sales Volumes

The table below shows Occidental’s total oil, NGL and natural gas proved reserves and sales volumes in 2018, 2017 and 2016. See "MD&A — Oil and Gas Segment," and the information under the caption "Supplemental Oil and Gas Information" for certain details regarding Occidental’s proved reserves, the reserves estimation process, sales and production volumes, production costs and other reserves-related data.

Competition

As a producer of oil, condensate, NGL and natural gas, Occidental competes with numerous other domestic and international public, private, and government producers. Oil, NGL and natural gas are commodities that are sensitive to prevailing global and local, current and anticipated market conditions. Occidental competes for transportation capacity and infrastructure for the delivery of its products, which are sold at current market prices or on a forward basis to refiners and other market participants. Occidental’s competitive strategy relies on increasing production through developing conventional and unconventional fields, utilizing primary and enhanced oil recovery (EOR) techniques and strategic acquisitions in areas where Occidental has a competitive advantage as a result of its current successful operations or investments in shared infrastructure. Occidental also competes to develop and produce its worldwide oil and gas reserves safely and cost-effectively, maintain a skilled workforce and obtain quality services.

Comparative Oil and Gas Proved Reserves and Sales Volumes

Oil (which includes condensate) and NGL are in millions of barrels; natural gas is in billions of cubic feet (Bcf); barrels of oil equivalent (BOE) are in millions.



	2018					2017					2016
Proved Reserves	Oil	NGL	Gas	BOE	^(a)	Oil	NGL	Gas	BOE	^(a)	Oil	NGL	Gas	BOE	^(a)
United States	1,186	284	1,445	1,711		1,107	247	1,205	1,555		960	219	1,045	1,353
International	397	202	2,650	1,041		408	198	2,626	1,043		397	201	2,729	1,053
Total	1,583	486	4,095	2,752		1,515	445	3,831	2,598		1,357	420	3,774	2,406
Sales Volumes
United States	91	25	119	136		73	20	108	111		69	19	132	110
International	62	11	189	104		66	11	188	109		74	11	217	121
Total	153	36	308	240		139	31	296	220		143	30	349	231

Note: The detailed proved reserves information presented in accordance with Item 1202(a)(2) to Regulation S-K under the Securities Exchange Act of 1934 (Exchange Act) is provided under the heading "Supplemental Oil and Gas Information". Proved reserves are stated on a net basis after applicable royalties.

(a)

Natural gas volumes are converted to barrels of oil equivalence (BOE) at six thousand cubic feet (Mcf) of gas per 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, in 2018, the average daily prices of West Texas Intermediate (WTI) oil and New York Mercantile Exchange (NYMEX) natural gas were $64.77 per barrel and $2.97 per Mcf, respectively, resulting in an oil to gas ratio of over 20 to 1.

CHEMICAL OPERATIONS

General

OxyChem owns and operates manufacturing plants at 22 domestic sites in Alabama, Georgia, Illinois, Kansas, Louisiana, Michigan, New Jersey, New York, Ohio, Tennessee and Texas and at two international sites in Canada and Chile. In 2018, OxyChem achieved a full year of operations at the 1.2 billion pound-per-year ethylene cracker at the OxyChem Ingleside, Texas facility as well as the 4CPe unit at OxyChem’s Geismar, Louisiana site. The ethylene cracker, a 50/50 joint venture with Mexichem S.A.B. de C.V., began commercial operations in the first quarter of 2017.

Competition

OxyChem competes with numerous other domestic and international chemical producers. OxyChem’s market position was first or second in the United States in 2018 for the principal basic chemicals products it manufactures and markets as well as for vinyl chloride monomer (VCM). OxyChem ranks in the top three producers of polyvinyl chloride (PVC) in the United States. OxyChem’s competitive strategy is to be a low-cost producer of its products in order to compete on price.

OxyChem produces the following products:




Principal Products	Major Uses	Annual Capacity
Basic Chemicals
Chlorine	Raw material for ethylene dichloride (EDC), water treatment and pharmaceuticals	3.4 million tons
Caustic soda	Pulp, paper and aluminum production	3.5 million tons
Chlorinated organics	Refrigerants, silicones and pharmaceuticals	1.0 billion pounds
Potassium chemicals	Fertilizers, batteries, soaps, detergents and specialty glass	0.4 million tons
EDC	Raw material for vinyl chloride monomer (VCM)	2.1 billion pounds
Chlorinated isocyanurates	Swimming pool sanitation and disinfecting products	131 million pounds
Sodium silicates	Catalysts, soaps, detergents and paint pigments	0.6 million tons
Calcium chloride	Ice melting, dust control, road stabilization and oil field services	0.7 million tons
Vinyls
VCM	Precursor for polyvinyl chloride (PVC)	6.2 billion pounds
PVC	Piping, building materials and automotive and medical products	3.7 billion pounds
Ethylene	Raw material for VCM	1.2 billion pounds ^(a)

(a) Amount is gross production capacity for 50/50 joint venture with Mexichem.

MIDSTREAM AND MARKETING OPERATIONS

General

Occidental's midstream and marketing operations primarily support and enhance its oil and gas and chemical businesses and also provide similar services for third parties.

In 2018, Occidental sold several non-core assets, including the Centurion common carrier oil pipeline and storage system, Southeast New Mexico oil gathering system and Ingleside Crude Terminal. Following the transactions, Occidental retained its long-term flow assurance, pipeline takeaway and export capacity through its retained marketing business.

Also within the midstream and marketing segment is Oxy Low Carbon Ventures (OLCV). OLCV seeks to capitalize on Occidental’s EOR leadership by developing carbon capture, utilization and storage projects that source anthropogenic carbon dioxide and promote innovative technologies that drive cost efficiencies and economically grow Occidental’s business while reducing emissions.

Competition

Occidental's midstream and marketing businesses operate in competitive and highly regulated markets. Occidental's marketing business competes with other market participants on exchange platforms and through other bilateral transactions with direct counterparties.

The midstream and marketing operations are conducted in the locations described below as of December 31, 2018:



Location	Description	Capacity
Gas Plants
Texas, New Mexico and Colorado	Occidental and third-party-operated natural gas gathering, compression and processing systems, and CO2 processing and capturing	2.8 Bcf per day
United Arab Emirates	Natural gas processing facilities for Al Hosn Gas	1.3 Bcf of natural gas per day
Pipelines and Gathering Systems
Texas, New Mexico and Colorado	CO2 fields and pipeline systems transporting CO2 to oil and gas producing locations	2.8 Bcf per day
Dolphin Pipeline - Qatar and United Arab Emirates and Oman	Equity investment in a natural gas pipeline	3.2 Bcf of natural gas per day
Western and Southern United States and Canada	Equity investment in entity involved in pipeline transportation, storage, terminalling and marketing of oil, gas and related petroleum products	17,965 miles of active crude oil and NGL pipelines and gathering systems. ^(a) 108 million barrels of crude oil, refined products and NGL storage capacity and 65 Bcf of natural gas storage working capacity^(a)
Power Generation
Texas and Louisiana	Occidental-operated power and steam generation facilities	1,200 megawatts of electricity and 1.6 million pounds of steam per hour


(a)	Amounts are gross, including interests held by third parties.

CAPITAL EXPENDITURES

For information on capital expenditures, see the information under the heading "Liquidity and Capital Resources” in the MD&A section of this report.

EMPLOYEES

Occidental employed approximately 11,000 people at December 31, 2018, 7,000 of whom were located in the U.S. Occidental employed approximately 7,000 people in the oil and gas and midstream and marketing segments and 3,000 people in the chemical segment. An additional 1,000 people were employed in administrative and headquarters functions. Approximately 500 U.S.-based employees and 900 international-based employees are represented by labor unions.

ENVIRONMENTAL REGULATION

For environmental regulation information, including associated costs, see the information under the heading "Environmental Liabilities and Expenditures" in the MD&A section of this report and "Risk Factors."

AVAILABLE INFORMATION

Occidental’s annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any amendments to those reports, are available free of charge on its website, www.oxy.com, as soon as reasonably practicable after Occidental electronically files the material with, or furnishes it to, the Securities and Exchange Commission (SEC). In addition, copies of our annual report will be made available, free of charge, upon written request.

Information contained on Occidental's website is not part of this report.

ITEM 1A RISK FACTORS

Volatile global and local commodity pricing strongly affect Occidental’s results of operations.

Occidental's financial results correlate closely to the prices it obtains for its products, particularly oil and, to a lesser extent, natural gas and NGL, and its chemical products.

Prices for crude oil, natural gas and NGL fluctuate widely. Historically, the markets for crude oil, natural gas and NGL have been volatile and may continue to be volatile in the future. If the prices of oil, natural gas, or NGL continue to be volatile or decline, Occidental's operations, financial condition, cash flows, level of expenditures and the quantity of estimated proved reserves that may be attributed to our properties may be materially and adversely affected. Prices are set by global and local market forces which are not in Occidental's control. These factors include, among others:


Ø	Worldwide and domestic supplies of, and demand for, crude oil, natural gas, NGL and refined products;


Ø	The cost of exploring for, developing, producing, refining and marketing crude oil, natural gas, NGL and refined products;


Ø	Operational impacts such as production disruptions, technological advances and regional market conditions, including available transportation capacity and infrastructure constraints in producing areas;


Ø	Changes in weather patterns and climate;


Ø	The impacts of the members of OPEC and other non-OPEC member-producing nations that may agree to and maintain production levels;


Ø	The worldwide military and political environment, uncertainty or instability resulting from an escalation or outbreak of armed hostilities or acts of terrorism in the United States, or elsewhere;


Ø	The price and availability of alternative and competing fuels;


Ø	Technological advances affecting energy consumption and supply;


Ø	Domestic and foreign governmental regulations and taxes, or changes in regulation and taxes;


Ø	Shareholder activism or activities by non-governmental organizations to restrict the exploration, development and production of oil, natural gas and NGL;


Ø	Additional or increased nationalization and expropriation activities by foreign governments;


Ø	General economic conditions worldwide;


Ø	Volatility in commodity futures markets; and


Ø	The effect of energy conservation efforts.

The long-term effects of these and other conditions on the prices of crude oil, natural gas, NGL and refined products are uncertain. Generally, Occidental's practice is to remain exposed to market prices of commodities. Management may elect to hedge the price risk of crude oil, natural gas and NGL in the future, and commodity price risk management and hedging activities may prevent us from fully benefiting from price increases and may expose us to regulatory and other risks.

The prices obtained for Occidental’s chemical products correlate strongly to the health of the United States and

global economies, as well as chemical industry expansion and contraction cycles. Occidental also depends on feedstocks and energy to produce chemicals, which are commodities subject to significant price fluctuations.

Occidental may experience delays, cost overruns, losses or other unrealized expectations in development efforts and exploration activities.

Oil, natural gas and NGL exploration and production activities are subject to numerous risks beyond our control, including the risk that drilling will not result in commercially viable oil, natural gas and NGL production. In its development and exploration activities, Occidental bears the risks of:


Ø	Equipment failures;


Ø	Construction delays;


Ø	Escalating costs or competition for services, materials, supplies or labor;


Ø	Property or border disputes;


Ø	Disappointing drilling results or reservoir performance;


Ø	Title problems and other associated risks that may affect its ability to profitably grow production, replace reserves and achieve its targeted returns;


Ø	Actions by third-party operators of our properties;


Ø	Delays and costs of drilling wells on lands subject to complex development terms and circumstances; and


Ø	Oil, natural gas or NGL gathering, transportation and processing availability, restrictions or limitations.

Exploration is inherently risky and is subject to delays, misinterpretation of geologic or engineering data, unexpected geologic conditions or finding reserves of disappointing quality or quantity, which may result in significant losses.

Governmental actions and political instability may affect Occidental’s results of operations.

Occidental’s businesses are subject to the actions and decisions of many federal, state, local and foreign governments and political interests. As a result, Occidental faces risks of:

New or amended laws and regulations, or new or different applications or interpretations of existing laws and regulations, including those related to drilling, manufacturing or production processes (including well stimulation techniques such as hydraulic fracturing and acidization), labor and employment, taxes, royalty rates, permitted production rates, entitlements, import, export and use of raw materials, equipment or products, use or increased use of land, water and other natural resources, safety, the manufacturing of chemicals, asset integrity management, the marketing or export of commodities, security and environmental protection, all of which may restrict or prohibit activities of Occidental or its contractors, increase Occidental's costs or reduce demand for Occidental's products. In addition, violation of certain governmental laws and regulations may result in strict, joint and several liability and the imposition of significant civil and criminal fines and penalties.


Ø	Refusal of, or delay in, the extension or grant of exploration, development or production contracts.


Ø	Development delays and cost overruns due to approval delays for, or denial of, drilling, construction, environmental and other regulatory approvals, permits and authorizations.

In addition, Occidental has and may continue to experience adverse consequences, such as risk of loss or production limitations, because certain of its international operations are located in countries affected by political instability, nationalizations, corruption, armed conflict, terrorism, insurgency, civil unrest, security problems, labor unrest, OPEC production restrictions, equipment import restrictions and sanctions. Exposure to such risks may increase if a greater percentage of Occidental’s future oil and gas production or revenue comes from international sources.

Occidental's oil and gas business operates in highly competitive environments, which affect, among other things, its ability to make acquisitions to grow production and replace reserves.

Results of operations, reserves replacement and growth in oil and gas production depend, in part, on Occidental’s ability to profitably acquire additional reserves. Occidental has many competitors (including national oil companies), some of which: (i) are larger and better funded; (ii) may be willing to accept greater risks; (iii) have greater access to capital; (iv) have substantially larger staffs; or (v) have special competencies. Competition for reserves may make it more difficult to find attractive investment opportunities or require delay of reserve replacement efforts. Further, during periods of low product prices, any cash conservation efforts may delay production growth and reserve replacement efforts. Also, there is substantial competition for capital available for investment in the oil and natural gas industry. Our failure to acquire properties, grow production, replace reserves and attract and retain qualified personnel could have a material adverse effect on our cash flows and results of operations.

In addition, Occidental’s acquisition activities carry risks that it may: (i) not fully realize anticipated benefits due to less-than-expected reserves or production or changed circumstances, such as declines in crude oil, NGL, and gas prices; (ii) bear unexpected integration costs or experience other integration difficulties; (iii) experience share price declines based on the market’s evaluation of the activity; or (iv) assume liabilities that are greater than anticipated.

Occidental’s oil and gas reserves are estimates based on professional judgments and may be subject to revision.

Reported oil and gas reserves are an estimate based on periodic review of reservoir characteristics and recoverability, including production decline rates, operating performance and economic feasibility at the prevailing commodity prices, assumptions concerning future crude oil and natural gas prices, future operating costs and capital expenditures, workover and remedial costs, assumed effects of regulation by governmental agencies, the quantity, quality and interpretation of relevant data, taxes

and availability of funds. The procedures and methods for estimating the reserves by our internal engineers were reviewed by independent petroleum consultants; however, there are inherent uncertainties in estimating reserves. Actual production, revenues, expenditures, crude oil, natural gas and NGL prices and taxes with respect to our reserves may vary from estimates, and the variance may be material. If Occidental were required to make significant negative reserve revisions, its results of operations and stock price could be adversely affected.

In addition, the discounted cash flows included in this Form 10-K should not be construed as the fair value of the reserves attributable to our properties. The estimated discounted future net cash flows from proved reserves are based on an unweighted 12-month average first-day-of-the-month prices in accordance with SEC regulations. Actual future prices and costs may differ materially from SEC regulation-compliant prices and costs used for purposes of estimating future discounted net cash flows from proved reserves. Also, actual future net cash flows may differ from these discounted net cash flows due to the amount and timing of actual production, availability of financing for capital expenditures necessary to develop our undeveloped reserves, supply and demand for oil, natural gas and NGL, increases or decreases in consumption of oil, natural gas and NGL and changes in governmental regulations or taxation.

Concerns about climate change and further regulation of greenhouse gas emissions may adversely affect Occidental’s operations or results.

Continuing political and social attention to the issue of climate change has resulted in both existing and pending international agreements and national, regional and local legislation and regulatory programs to reduce greenhouse gas emissions. In December 2009, the EPA determined that emissions of carbon dioxide, methane and other greenhouse gases endanger public health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the Earth’s atmosphere and other climatic changes. Based on these findings, the EPA began adopting and implementing regulations to restrict emissions of greenhouse gases under existing provisions of the Clean Air Act. For example, the EPA issued rules restricting methane emissions from hydraulically fractured and refractured gas wells, compressors, pneumatic controls, storage vessels, and natural gas processing plants.

In the absence of federal legislation to significantly reduce emissions of greenhouse gases to date, many state governments have have established rules aimed at reducing greenhouse gas emissions, including greenhouse gas cap and trade programs. Most of these cap and trade programs work by requiring major sources of emissions, such as electric power plants, or major producers of fuels, such as refineries and natural gas processing plants, to acquire and surrender emission allowances. In the future, the United States may also choose to adhere to international agreements targeting greenhouse gas reductions. These and other government actions relating to greenhouse gas emissions could require Occidental to incur increased operating and maintenance costs, such as costs to

purchase and operate emissions control systems, to acquire emissions allowances, pay carbon taxes, or comply with new regulatory or reporting requirements, or they could promote the use of alternative sources of energy and thereby decrease demand for oil, natural gas and other products that Occidental’s businesses produce. Any such legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for, oil, natural gas and other products produced by Occidental’s businesses and lower the value of its reserves. Consequently, government actions designed to reduce emissions of greenhouse gases could have an adverse effect on Occidental’s business, financial condition, results of operations, cash flows and reserves.

There also have been efforts in recent years to influence the investment community, including investment advisers and certain sovereign wealth, pension and endowment funds promoting divestment of fossil fuel equities and pressuring lenders to limit funding to companies engaged in the extraction of fossil fuel reserves. Such environmental activism and initiatives aimed at limiting climate change and reducing air pollution could interfere with our business activities, operations and ability to access capital. Finally, increasing attention to climate change risks has resulted in an increased possibility of governmental investigations and additional private litigation against Occidental without regard to causation or our contribution to the asserted damage, which could increase our costs or otherwise adversely affect our business. We have been named in certain private litigation relating to these matters.

It is difficult to predict the timing and certainty of such government actions and the ultimate effect on Occidental, which could depend on, among other things, the type and extent of greenhouse gas reductions required, the availability and price of emissions allowances or credits, the availability and price of alternative fuel sources, the energy sectors covered, and Occidental’s ability to recover the costs incurred through its operating agreements or the pricing of the company’s oil, NGL, natural gas and other products.

Occidental’s businesses may experience catastrophic events.

The occurrence of events such as hurricanes, floods, droughts, earthquakes or other acts of nature, well blowouts, fires, explosions, pipeline ruptures, chemical releases, crude oil releases, including maritime releases, releases into navigable waters, and groundwater contamination, material or mechanical failure, industrial accidents, physical attacks, abnormally pressured or structured formations and other events that cause operations to cease or be curtailed may negatively affect Occidental’s businesses and the communities in which it operates. Coastal operations are particularly susceptible to disruption from extreme weather events. Any of these risks could adversely affect our ability to conduct operations or result in substantial losses to us as a result of:


Ø	Damage to and destruction of property and equipment;


Ø	Damage to natural resources;


Ø	Pollution and other environmental damage, including spillage or mishandling of recovered chemicals or fluids;


Ø	Regulatory investigations and penalties;


Ø	Loss of well location, acreage, expected production and related reserves;


Ø	Suspension or delay of our operations;


Ø	Substantial liability claims; and


Ø	Repair and remediation costs.

Third-party insurance may not provide adequate coverage or Occidental may be self-insured with respect to the related losses. In addition, under certain circumstances, we may be liable for environmental damage caused by previous owners or operators of properties that we own, lease or operate. As a result, we may incur substantial liabilities to third parties or governmental entities for environmental matters for which we do not have insurance coverage, which could reduce or eliminate funds available for exploration, development or acquisitions or cause us to incur losses.

Cyber-attacks could negatively affect Occidental.

The oil and gas industry is increasingly dependent on digital and industrial control technologies to conduct certain exploration, development and production activities. Occidental relies on digital and industrial control systems, related infrastructure, technologies and networks to run its business and to control and manage its oil and gas, chemicals, marketing and pipeline operations. Use of the internet, cloud services, mobile communication systems and other public networks exposes Occidental’s business and that of other third parties with whom Occidental does business to cyber-attacks. Cyber-attacks on businesses have escalated in recent years.

Information and industrial control technology system failures, network disruptions and breaches of data security could disrupt our operations by causing delays, impeding processing of transactions and reporting financial results, resulting in the unintentional disclosure of company, partner, customer, employee information, or damage to our reputation. A cyber-attack involving our information or industrial control systems and related infrastructure, or that of our business associates, could negatively impact our operations in a variety of ways, including but not limited to, the following:


Ø	Unauthorized access to seismic data, reserves information, strategic information, or other sensitive or proprietary information could have a negative impact on our ability to compete for oil and natural gas resources;


Ø	Data corruption, communication or systems interruption or other operational disruption during drilling activities could result in delays and failure to reach the intended target or cause a drilling incident;


Ø	Data corruption, communication or systems interruption, or operational disruptions of production-related infrastructure could result in a loss of production, or accidental discharge;


Ø	A cyber-attack on our chemical operations could result in a disruption of the manufacturing and marketing of

our products or a potential environmental hazard and ultimately loss of revenue;


Ø	A cyber-attack on a vendor or service provider could result in supply chain disruptions, which could delay or halt our construction and development projects;


Ø	A cyber-attack on third-party gathering, pipeline, or other transportation systems could delay or prevent us from transporting and marketing our production, resulting in loss of revenue;


Ø	A cyber-attack involving commodities exchanges or financial institutions could slow or halt commodities trading, thus preventing us from marketing our production or engaging in hedging activities, resulting in loss of revenue;


Ø	A cyber-attack that halts activities at a power generation facility or refinery using natural gas as feed stock could have a significant impact on the natural gas market;


Ø	A cyber-attack on a communications network or power grid could cause operational disruption resulting in loss of revenue;


Ø	A cyber-attack on our automated and surveillance systems could cause a loss in production and potential environmental hazards;


Ø	A deliberate corruption of our financial or operating data could result in events of non-compliance which could then lead to regulatory fines or penalties; and


Ø	A cyber-attack resulting in the loss or disclosure of, or damage to, our or any of our customer’s or supplier’s data or confidential information could harm our business by damaging our reputation, subjecting us to potential financial or legal liability, and requiring us to incur significant costs, including costs to repair or restore our systems and data or to take other remedial steps.

Even though Occidental has implemented controls and multiple layers of security to mitigate the risks of a cyber-attack that it believes are reasonable, there can be no assurance that such cyber security measures will be sufficient to prevent security breaches of its systems from occurring, and if a breach occurs, it may remain undetected for an extended period of time. Further, Occidental has no control over the comparable systems of the third parties with whom it does business. While Occidental has experienced cyber-attacks in the past, Occidental has not suffered any material losses. However, if in the future Occidental's cyber security measures are compromised or prove insufficient, the potential consequences to Occidental’s businesses and the communities in which it operates could be significant. As cyber-attacks continue to evolve in magnitude and sophistication, Occidental may be required to expend additional resources in order to continue to enhance Occidental's cyber security measures and to investigate and remediate any digital and operational systems, related infrastructure, technologies and network security vulnerabilities, which would increase our costs. A system failure or data security breach, or a series of such failures or breaches, could have a material adverse effect on our financial condition, results of operations or cash flows.

Occidental's oil and gas reserve additions may not continue at the same rate and a failure to replace reserves may negatively affect Occidental's business.

Producing oil and natural gas reservoirs generally are characterized by declining production rates that vary depending upon reservoir characteristics and other factors. Unless Occidental conducts successful exploration or development activities, acquires properties containing proved reserves, or both, proved reserves will generally decline and negatively impact our business. The value of our securities and our ability to raise capital will be adversely impacted if we are not able to replace reserves that are depleted by production or replace our declining production with new production. Management expects improved recovery, extensions and discoveries to continueas main sources for reserve additions but factors such as geology, government regulations and permits, the effectiveness of development plans and the ability to make the necessary capital investments or acquire capital are partially or fully outside management's control and could cause results to differ materially from expectations.

Other risk factors.

Additional discussion of risks and uncertainties related to price and demand, litigation, environmental matters, oil, natural gas and NGL reserves estimation processes, impairments, derivatives, market risks and internal controls appears under the headings: "Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities — Market Information, Holders and Dividend Policy,” “MD&A — Oil and Gas Segment — Business Environment,” “— Proved Reserves" and "— Industry Outlook," "— Chemical Segment — Industry Outlook," "— Midstream and Marketing Segment — Industry Outlook," "— Lawsuits, Claims and Contingencies," "— Environmental Liabilities and Expenditures," "— Critical Accounting Policies and Estimates," "— Quantitative and Qualitative Disclosures About Market Risk," and "Management's Annual Assessment of and Report on Internal Control Over Financial Reporting."

The risks described in this report are not the only risks facing Occidental and other risks, including risks deemed immaterial, may have material adverse effects.


ITEM 1B	UNRESOLVED STAFF COMMENTS

None.

ITEM 3 LEGAL PROCEEDINGS

For information regarding legal proceedings, see the information under the caption "Lawsuits, Claims, Commitments and Contingencies" in the MD&A section of this report and in Note 10 to the Consolidated Financial Statements.

ITEM 4 MINE SAFETY DISCLOSURES

Not applicable.

EXECUTIVE OFFICERS

Each executive officer holds his or her office from the date of election by the Board of Directors until the first board meeting held after the Annual Meeting of Stockholders or until a successor is duly elected. The next Annual Meeting of Stockholders is May 10, 2019.

The following table sets forth the executive officers of Occidental:



Name Current Title	Age at February 21, 2019	Positions with Occidental and Subsidiaries and Employment History
Vicki Hollub Chief Executive Officer and President	59	President, Chief Executive Officer and Director since April 2016; President, Chief Operating Officer and Director, 2015-2016; Senior Executive Vice President and President, Oxy Oil and Gas, 2015; Executive Vice President and President Oxy Oil and Gas - Americas, 2014-2015; Vice President and Executive Vice President, U.S. Operations, Oxy Oil and Gas, 2013-2014.
Cedric W. Burgher Chief Financial Officer and Senior Vice President	58	Senior Vice President and Chief Financial Officer since May 2017; EOG Resources: Senior Vice President, Investor and Public Relations, 2014-2017, QR Energy L.P.; Chief Financial Officer, 2010-2014.
Edward A. “Sandy” Lowe Executive Vice President	67	Executive Vice President since 2015; Group Chairman - Middle East since 2016; Senior Vice President, 2008-2015; President - Oxy Oil & Gas International, 2009-2016.
Marcia E. Backus Senior Vice President	64	Senior Vice President, General Counsel and Chief Compliance Officer since December 2016; Senior Vice President, General Counsel, Chief Compliance Officer and Corporate Secretary, 2015-2016; Vice President, General Counsel and Corporate Secretary, 2014-2015; Vice President and General Counsel, 2013-2014; Vinson & Elkins: Partner, 1990-2013.
Glenn M. Vangolen Senior Vice President	59	Senior Vice President, Business Support since February 2015; Executive Vice President, Business Support, 2014-2015; Senior Vice President - Oxy Oil & Gas Middle East, 2010-2014.
Jennifer M. Kirk Vice President	44	Vice President, Controller and Principal Accounting Officer since 2014; Controller, Occidental Oil and Gas Corporation, 2012-2014.

Part II


ITEM 5	MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES

MARKET INFORMATION, HOLDERS AND DIVIDEND POLICY

Occidental's common stock is listed and traded on the New York Stock Exchange under the ticker symbol "OXY". The common stock was held by approximately 23,300 stockholders of record at January 31, 2019, which does not include beneficial owners for whom Cede and Co. or others act as nominees.

Occidental's current annual dividend rate of $3.12 per share has increased by over 500 percent since 2002. The declaration of future dividends is a business decision made by the Board of Directors from time to time, and will depend on Occidental’s financial condition and other factors deemed relevant by the Board.

SHARE REPURCHASE ACTIVITIES

Occidental’s share repurchase activities for the year ended December 31, 2018, 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 2018		—			$	—		—
Second Quarter 2018		1,197,973	^(a)		$	83.46		872,000
Third Quarter 2018		11,324,665	^(a)		$	78.93		11,236,540
October 1 - 31, 2018		88,001	^(a)		$	82.18		—
November 1 - 30, 2018		1,424,000			$	73.12		1,424,000
December 1 - 31, 2018		3,327,217			$	59.96		3,327,217
Fourth Quarter 2018		4,839,218	^(a)		$	64.23		4,751,217
Total 2018		17,361,856	^(a)		$	75.15		16,859,757		46,896,787	^(b)


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


(b)	Represents the total number of shares remaining at year end 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.

PERFORMANCE GRAPH

The following graph compares the yearly percentage change in Occidental’s cumulative total return on its common stock with the cumulative total return of the Standard & Poor's 500 Stock Index (S&P 500), which Occidental is included in, and with that of Occidental’s peer group over the five-year period ended on December 31, 2018. The graph assumes that $100 was invested at the beginning of the five-year period shown in the graph below in: (i) Occidental common stock, (ii) the stock of the companies in the S&P 500, and (iii) each of the peer group companies' common stock weighted by their relative market values within the peer group, and that all dividends were reinvested.

Occidental's peer group consists of Anadarko Petroleum Corporation, Apache Corporation, Canadian Natural Resources Limited, Chevron Corporation, ConocoPhillips, Devon Energy Corporation, EOG Resources Inc., ExxonMobil Corporation, Hess Corporation, Marathon Oil Corporation, Total S.A. and Occidental.



	12/31/2013			12/31/2014			12/31/2015			12/31/2016			12/31/2017			12/31/2018
Occidental		$	100		$	91		$	80		$	88		$	95		$	83
Peer Group		100			94			77			96			99			87
S&P 500		100			114			115			129			157			150

The information provided in this Performance Graph shall not be deemed "soliciting material" or "filed" with the SEC or subject to Regulation 14A or 14C under the Exchange Act, other than as provided in Item 201 to Regulation S-K under the Exchange Act, or subject to the liabilities of Section 18 of the Exchange Act and shall not be deemed incorporated by reference into any filing under the Securities Act of 1933 or the Exchange Act except to the extent Occidental specifically requests that it be treated as soliciting material or specifically incorporates it by reference.

________________________________________________


(1)	The cumulative total return of the peer group companies' common stock includes the cumulative total return of Occidental's common stock.


ITEM 6	SELECTED FINANCIAL DATA

FIVE-YEAR SUMMARY OF SELECTED FINANCIAL DATA

(in millions, except per-share amounts)



As of and for the years ended December 31,	2018			2017			2016			2015			2014
RESULTS OF OPERATIONS ^(a)
Net sales	$	17,824		$	12,508		$	10,090		$	12,480		$	19,312
Income (loss) from continuing operations	$	4,131		$	1,311		$	(1,002	)	$	(8,146	)	$	(130	)
Net income (loss) attributable to common stock	$	4,131		$	1,311		$	(574	)	$	(7,829	)	$	616
Basic earnings (loss) per common share from continuing operations	$	5.40		$	1.71		$	(1.31	)	$	(10.64	)	$	(0.18	)
Basic earnings (loss) per common share	$	5.40		$	1.71		$	(0.75	)	$	(10.23	)	$	0.79
Diluted earnings (loss) per common share	$	5.39		$	1.70		$	(0.75	)	$	(10.23	)	$	0.79

FINANCIAL POSITION ^(a)
Total assets	$	43,854		$	42,026		$	43,109		$	43,409		$	56,237
Long-term debt, net	$	10,201		$	9,328		$	9,819		$	6,855		$	6,816
Stockholders’ equity	$	21,330		$	20,572		$	21,497		$	24,350		$	34,959

MARKET CAPITALIZATION ^(b)	$	45,998		$	56,357		$	54,437		$	51,632		$	62,119

CASH FLOW FROM CONTINUING OPERATIONS
Operating:
Cash flow from continuing operations	$	7,669		$	4,861		$	2,520		$	3,251		$	8,879
Investing:
Capital expenditures	$	(4,975	)	$	(3,599	)	$	(2,717	)	$	(5,272	)	$	(8,930	)
Cash provided (used) by all other investing activities, net	$	1,769		$	520		$	(2,026	)	$	(148	)	$	2,678
Financing:
Cash dividends paid	$	(2,374	)	$	(2,346	)	$	(2,309	)	$	(2,264	)	$	(2,210	)
Purchases of treasury stock	$	(1,248	)	$	(25	)	$	(22	)	$	(593	)	$	(2,500	)
Cash provided by all other financing activities, net	$	520		$	28		$	1,529		$	1,515		$	6,403

DIVIDENDS PER COMMON SHARE	$	3.10		$	3.06		$	3.02		$	2.97		$	2.88

WEIGHTED AVERAGE BASIC SHARES OUTSTANDING (millions)	762			765			764			766			781

Note: The statements of income and cash flows related to California Resources have been treated as discontinued operations for all periods presented. The assets and liabilities of California Resources were removed from Occidental's consolidated balance sheet as of November 30, 2014.


(a)	See the MD&A section of this report and the Notes to Consolidated Financial Statements for information regarding acquisitions and dispositions, discontinued operations and other items affecting comparability.


(b)	Market capitalization is calculated by multiplying the year-end total shares of common stock outstanding, net of shares held as treasury stock, by the year-end closing stock price.


ITEM 7	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (MD&A)

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's principal businesses consist of three segments. The oil and gas segment explores for, develops and produces oil, condensate, natural gas liquids (NGL) and natural gas. The chemical segment (OxyChem) mainly manufactures and markets basic chemicals and vinyls. The midstream and marketing segment purchases, markets, gathers, processes, transports and stores oil, condensate, NGL, natural gas, carbon dioxide (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.

Occidental's oil and gas assets are located in some of the world’s highest-margin basins and are characterized by an advantaged mix of short- and long-cycle, high-return development opportunities. In the United States, Occidental continues to hold a leading position in the Permian Basin. Other core operations are in the Middle East (Oman, UAE and Qatar) and Latin America (Colombia). Occidental's midstream and marketing business provides flow assurance and access to domestic and international markets. OxyChem is a world-class chemical business that generates high financial returns.

STRATEGY

General

Occidental is focused on delivering a unique shareholder value proposition through continual enhancements to its asset quality, organizational capability and innovative technical applications that provide competitive advantages. Occidental’s integrated business provides conventional and unconventional opportunities through which to grow value. Occidental aims to maximize shareholder returns through a combination of:


Ø	Consistent dividend growth;


Ø	Allocating capital to high-return opportunities across the integrated business;


Ø	Production growth rates of 5 to 8+ percent average per year over the long-term; and


Ø	Maintenance of a strong balance sheet to secure business and enhance shareholder value.

Occidental conducts its operations with a focus on sustainability, health, safety and environmental and social responsibility. Capital is employed to operate all assets in a safe and environmentally sound manner. Occidental accepts commodity, engineering and limited exploration risks. Occidental seeks to limit its financial and political risks.

Price volatility is inherent in the oil and gas business and Occidental’s strategy is to position the business to thrive in an up- or down-cycle commodity price environment. In 2018, Occidental continued to build upon its integrated portfolio of high-value investment options, focusing on value growth and high-quality assets that deliver industry-leading returns. During the year,

Occidental completed its short-term strategic plan to maintain production and sustain the dividend at a West Texas Intermediate (WTI) oil price of $40 per barrel and grow production at 5 to 8+ percent at $50 per barrel. Achieving these goals in the short-term strengthens Occidental's ability to provide a meaningful dividend with growth and maintain a strong balance sheet at low oil prices. Occidental's Board of Directors and management are committed to allocating free cash flow toward investments that generate the highest returns, along with returning cash to shareholders through dividends and share repurchases.

The following describes the application of Occidental’s overall strategy for each of its operating segments:

Oil and Gas

Occidental’s oil and gas segment focuses on long-term value creation and leadership in sustainability, health, safety and the environment. In each core operating area, Occidental's operations benefit from scale, technical expertise, environmental and safety leadership, and commercial and governmental collaboration. These attributes allow Occidental to bring additional production quickly to market, extend the life of older fields at lower costs, and provide low-cost returns driven growth opportunities with advanced technology.

As a result of Occidental's strategic positioning, Occidental's assets provide current production and a future portfolio of projects that are flexible and have short-cycle investment paybacks. Together with Occidental's technical capabilities, the oil and gas segment is able to achieve low development and operating costs to obtain full-cycle value while promoting innovative ideas that differentiate Occidental's approach and provide future opportunities.

The oil and gas business implements Occidental's strategy primarily by:


Ø	Operating and developing areas where reserves are known to exist and to increase production from core areas, primarily in the Permian Basin, Colombia, Oman, and UAE;


Ø	Maintaining a disciplined and prudent approach to capital expenditures with a focus on returns and an emphasis on creating value and further enhancing Occidental's existing positions;


Ø	Focusing Occidental's subsurface characterization and technical activities on unconventional opportunities, primarily in the Permian Basin;


Ø	Using enhanced oil recovery techniques, such as CO₂, water and steam floods, in mature fields; and


Ø	Focusing on cost-reduction efficiencies, improvement in new well productivity and better base management to reduce full cycle costs.

In 2018, oil and gas capital expenditures were approximately $4.4 billion, and were primarily focused on

Occidental's high-return assets in the Permian Basin, Oman and Colombia.

Chemical

The primary objective of OxyChem is to generate cash flow in excess of its normal capital expenditure requirements and achieve above-cost-of-capital returns. The chemical segment's strategy is to be a low-cost producer in order to maximize cash flow generation. OxyChem concentrates on the chlorovinyls chain beginning with the co-production of caustic soda and chlorine. Caustic soda and chlorine are marketed to external customers. In addition, chlorine, together with ethylene, is converted through a series of intermediate products into polyvinyl chloride (PVC). OxyChem's focus on chlorovinyls allows it to maximize the benefits of integration and take advantage of economies of scale. Capital is employed to sustain production capacity and to focus on projects and developments designed to improve the competitiveness of segment assets. Acquisitions and plant development opportunities may be pursued when they are expected to enhance the existing core chlor-alkali and PVC businesses or take advantage of other specific opportunities. In 2018, OxyChem, through a 50/50 joint venture with Mexichem S.A.B. de C.V., achieved a full year of commercial operations of its 1.2 billion pound-per-year ethylene cracker at the OxyChem Ingleside facility. The joint venture provides an opportunity to capitalize on the advantage that U.S. shale gas development has presented to U.S. chemical producers by providing low-cost ethane as a raw material. The joint venture provides OxyChem with an ongoing source of ethylene, significantly reducing OxyChem's reliance on third-party ethylene suppliers. OxyChem also achieved a full year of operations of its expansion at Geismar, Louisiana, following plant startup late in the fourth quarter of 2017. Using an OxyChem patented process, the new facility produces 4CPe, a new raw material used in making next-generation, climate-friendly refrigerants with a low global warming and ozone depletion potential. In 2018, capital expenditures for OxyChem totaled $271 million.

Midstream and Marketing

The midstream and marketing segment strives to maximize realized value by optimizing the use of its committed pipeline and export capacities and by providing access to domestic and international markets. To generate returns, the segment evaluates opportunities across the value chain and uses its assets to provide services to Occidental subsidiaries, as well as third parties. The midstream and marketing segment operates gathering systems, gas plants, co-generation facilities and storage facilities and invests in entities that conduct similar activities. Also within the midstream and marketing segment is Oxy Low Carbon Ventures (OLCV). OLCV seeks to capitalize on Occidental’s EOR leadership by developing carbon capture, utilization and storage projects that source anthropogenic carbon dioxide and promote innovative technologies that drive cost efficiencies and economically grow Occidental’s business while reducing emissions.

This segment also seeks to minimize the costs of gas, power and other commodities used in Occidental's various businesses. Capital is employed to sustain or expand assets to improve the competitiveness of Occidental's businesses. In 2018, capital expenditures related to the midstream business totaled $216 million primarily related to Permian Basin gas processing and the Ingleside Crude Terminal, prior to its sale.

In 2018, Occidental sold several assets, including the Centurion common carrier oil pipeline and storage system, Southeast New Mexico oil gathering system, and Ingleside Crude Terminal. Following the transactions, Occidental retained its long-term flow assurance, pipeline takeaway and export capacity through its retained marketing business.

Key Performance Indicators

Occidental seeks to meet its strategic goals by continually measuring its success in its key performance metrics that drive total stockholder return. In addition to production growth and capital allocation and deployment discussed above, Occidental believes the following are its most significant metrics:


Ø	Sustainability, health, environmental and safety performance measures;


Ø	Total shareholder return, including funding the dividend;


Ø	Return on capital employed (ROCE) and cash return on capital employed (CROCE); and


Ø	Specific measures such as earnings per share, per-unit profit, production cost, cash flow, finding-and-development costs and reserves replacement percentages.

OIL AND GAS SEGMENT

Business Environment

Oil and gas prices are the major variables that drive the industry’s financial performance. The following table presents the average daily West Texas Intermediate (WTI), Brent and New York Mercantile Exchange (NYMEX) prices for 2018 and 2017:



	2018		2017
WTI oil ($/barrel)	$	64.77	$	50.95
Brent oil ($/barrel)	$	71.53	$	54.82
NYMEX gas ($/Mcf)	$	2.97	$	3.09

The following table presents Occidental's average realized prices as a percentage of WTI, Brent and NYMEX for 2018 and 2017:



	2018		2017
Worldwide oil as a percentage of average WTI	94	%	96	%
Worldwide oil as a percentage of average Brent	85	%	89	%
Worldwide NGL as a percentage of average WTI	41	%	42	%
Worldwide NGL as a percentage of average Brent	37	%	39	%
Domestic natural gas as a percentage of NYMEX	54	%	75	%

Average WTI and Brent oil price indexes increased 27 percent and 30 percent, from $50.95 and $54.82 in 2017 to $64.77 and $71.53 in 2018, respectively. Average worldwide realized oil prices rose $11.71, or 24 percent, in 2018 compared to 2017. WTI and Brent oil price indexes decreased in the fourth quarter of 2018, closing at $45.41 per barrel and $53.80 per barrel, respectively, which is lower than 2017 year-end prices, which closed at $60.42 per barrel and $66.87 per barrel, respectively. The average realized domestic natural gas price in 2018 decreased 31 percent from 2017. Average NYMEX natural gas prices decreased 4 percent, from $3.09 in 2017 to $2.97 in 2018.

Prices and differentials can vary significantly, even on a short-term basis, making it difficult to predict realized prices with a reliable degree of certainty.

Business Review

Domestic Interests

Occidental conducts its domestic operations through land leases, subsurface mineral rights it owns, or a combination of both surface land and subsurface mineral rights it owns. Occidental's domestic oil and gas leases have a primary term ranging from one to ten years, which is extended through the end of production once it commences. Of the total 3.6 million net acres in which Occidental has interests, approximately 82 percent is leased, 17 percent is owned subsurface mineral rights and 1 percent is owned land with mineral rights.

The following charts show Occidental’s domestic total production volumes for the last five years:

Domestic Production Volumes

(thousands BOE/day)

Notes:


•	Excludes volumes from California Resources, which was separated on November 30, 2014, and included as discontinued operations for all applicable periods.


•	Operations sold include South Texas (sold in April 2017), Piceance (sold in March 2016), Williston (sold in November 2015) and Hugoton (sold in April 2014)

United States Assets


1.	Delaware Basin


2.	Midland Basin


3.	Central Basin Platform

Permian Basin

The Permian Basin extends throughout West Texas and southeast New Mexico and is one of the largest and most active oil basins in the United States, accounting for more than 30 percent of the total United States oil production.

Occidental manages its Permian Basin operations through two business units: Permian Resources, which includes growth-oriented unconventional opportunities, and Permian EOR, which utilizes enhanced oil recovery techniques such as CO₂ floods and waterfloods. Occidental has a leading position in the Permian Basin, producing approximately 10 percent of the total oil in the basin. By exploiting the natural synergies between Permian Resources and Permian EOR, Occidental is able to deliver unique short- and long-term advantages, efficiencies and expertise across its Permian Basin operations. Occidental expects to decrease its Permian Basin full-cycle breakeven costs, while continuing to expand its high-quality, low-cost breakeven inventory. Occidental expects the combined technical advancements, infrastructure utilization opportunities and operations across over 2.7 million net acres will provide sustainability of Occidental's low cost position in the Permian Basin.

In the next few years, growth within Occidental’s Permian Basin portfolio will be focused in the Permian Resources unconventional assets. In 2018, Occidental spent approximately $3.5 billion of capital in the Permian Basin, of which over 85 percent was spent on Permian Resources assets. In 2019, Occidental expects to allocate approximately 56 percent of its worldwide 2019 capital budget to Permian Resources for development and approximately 12 percent to Permian EOR for the expansion of existing facilities to increase CO₂ production and injection capacity.

Permian Resources

Permian Resources' unconventional oil development projects provide very short-cycle investment payback,

averaging less than two years, providing some of the highest margin and returns of any oil and gas projects in the world. These investments provide better cash-flow and production growth, while increasing long-term value and sustainability through higher return on capital employed.

Occidental's Permian Resources inventory includes over 10,400 horizontal drilling locations in the Midland and Delaware sub-basins. As of December 31, 2018, approximately 1,000 of these drilling locations represented proved undeveloped reserves. In 2018, Permian Resources produced approximately 214,000 net BOE per day from approximately 5,280 net wells, of which 18 percent are operated by other companies.

Permian EOR

The Permian Basin’s concentration of large conventional reservoirs, favorable CO₂ flooding performance and the proximity to naturally occurring CO₂ supply has resulted in decades of steady growth in enhanced oil production. With 34 active floods and over 40 years of experience, Occidental is the industry leader in Permian Basin CO₂flooding, which can increase ultimate oil recovery by 10 to 25 percent. Technology improvements, such as the recent trend toward vertical expansion of the CO₂ flooded interval into residual oil zone targets, continue to yield more recovery from existing projects. Occidental utilizes workover rigs to drill extra depth into additional CO₂ floodable sections of the reservoir, and completed 118 well workovers in 2018 and has plans to complete 104 well workovers in 2019. In 2018, Permian EOR added 26 million BOE to Occidental’s proved reserves for improved recovery additions, primarily as a result of executing CO₂ flood development projects and expansions. Occidental's share of production from Permian EOR was approximately 154,000 BOE per day in 2018.

Significant opportunities also remain to gain additional recovery by expanding Occidental's existing CO₂ projects into new portions of reservoirs that have only been water-flooded. Permian EOR has a large inventory of future CO₂ projects, which could be developed over the next 20 years or accelerated, depending on market conditions.

International Interests

Production-Sharing Contracts

Occidental's interests in Oman and Qatar are subject to production sharing contracts (PSC). Under such contracts, Occidental records a share of production and reserves to recover certain development and production costs and an additional share for profit. In addition, certain contracts in Colombia are subject to contractual arrangements similar to a PSC. These contracts do not transfer any right of ownership to Occidental and reserves reported from these arrangements are based on Occidental’s economic interest as defined in the contracts. Occidental’s share of production and reserves from these contracts decreases when product prices rise and increases when prices decline. Overall, Occidental’s net economic benefit from these contracts is greater when product prices are higher.

The following charts show Occidental’s international production volumes for the last five years:

International Production Volumes

(thousands BOE/day)

Notes:


•	Operations sold or exited include Bahrain, Iraq, Libya and Yemen.

Middle East Assets


1.	Oman


2.	United Arab Emirates


3.	Qatar

Oman

In Oman, Occidental is the operator of Block 9 (Safah Field) with a 50-percent working interest, Block 27 with a 65-percent working interest, Block 53 with a 45-percent working interest and Block 62 with an 80-percent working interest. Occidental also has exploration contracts and memorandums of understanding for Blocks 30, 51, 65 and 72 which increased the acreage from 2.3 million to 6.0 million gross acres and the potential well inventory locations to approximately 10,000. In 2018, Occidental’s share of production was 86,000 BOE per day.

Block 9 expires in 2030 and Block 27 expires in 2035. Occidental's share of production for Blocks 9 and 27 was 24,000 BOE per day and 8,000 BOE per day in 2018, respectively. Block 53 (Mukhaizna Field) expires in 2035 and is a major pattern steam flood project for enhanced oil recovery that utilizes some of the largest mechanical vapor compressors ever built. Since assuming operations in Mukhaizna, Occidental has drilled over 3,280 new wells and Occidental's share of production was 32,000 BOE per day in 2018. Block 62, which expires in 2028, is subject to declaration of commerciality. In addition a non-associated gas area (natural gas not in contact with crude oil in a reservoir) expires in 2019. Occidental's share of production for Block 62 was 22,000 BOE per day in 2018.

United Arab Emirates

In 2011, Occidental acquired a 40-percent participating interest in Al Hosn Gas, joining with the Abu Dhabi National Oil Company (ADNOC) in a 30-year joint venture agreement. In 2018, Occidental’s share of production from Al Hosn Gas was 220 MMcf per day of natural gas and 36,000 barrels per day of NGL and condensate. Al Hosn Gas includes gas processing facilities which are discussed further in "Midstream and Marketing Segment - Gas Processing Plants and CO₂Fields and Facilities".

In 2019, Occidental received a 35-year concession for onshore Block 3 which covers an area of approximately 1.5 million acres and is adjacent to Al Hosn Gas.

Occidental conducts a majority of its Middle East business development activities through its office in Abu Dhabi, which also provides various support functions for Occidental’s Middle East oil and gas operations.

Qatar

In Qatar, Occidental partners in the Dolphin Energy project, an investment that is comprised of two separate economic interests. Occidental has a 24.5-percent interest in the upstream operations to develop and produce natural gas, NGL and condensate from Qatar’s North Field through mid-2032. Occidental also has a 24.5-percent interest in Dolphin Energy Limited which operates a pipeline and is discussed further in "Midstream and Marketing Segment – Pipeline. Occidental's net share of production from the Dolphin upstream operations was 40,000 BOE per day in 2018.

Occidental is also the operator of the offshore fields Idd El Shargi North Dome (ISND) and Idd El Shargi South Dome (ISSD), with a 100-percent working interest in each. The terms for ISND will expire in October 2019 and the ISSD terms expire in December 2022. Occidental's net share of production from ISND and ISSD was 50,000 barrels per day and 5,000 barrels per day in 2018, respectively.

Latin America Assets


1.	Teca Heavy Oil Area


2.	La Cira-Infantas Waterflood Area


3.	Llanos Norte Basin


4.	Putumayo Basin

Colombia

Occidental has working interests in the La Cira-Infantas and Teca areas and has operations within the Llanos Norte Basin. Occidental's interests range from 39 to 61 percent and certain interests expire between 2023 and 2038, while others extend through the economic limit of the areas.

In June 2018, Occidental and Ecopetrol agreed to enter into the second phase of development of the Teca heavy oil field, based on the positive results of the Teca steam flood pilot, which began in early 2016. Phase II drilling is expected to start in 2019.

Occidental also entered into agreements to develop Blocks 39 and 52 in the Llanos Norte Basin and farmed into an additional four blocks in the Putumayo Basin; these blocks increased Occidental’s net acreage in Colombia to approximately 1 million acres.

Occidental's net share of production from Colombia was 31,000 BOE per day in 2018.

Proved Reserves

Proved oil, NGL and gas reserves were estimated using the unweighted arithmetic average of the first-day-of-the-month price for each month within the year, unless prices were defined by contractual arrangements. Oil, NGL and natural gas prices used for this purpose were based on posted benchmark prices and adjusted for price differentials including gravity, quality and transportation costs. For the 2018, 2017 and 2016 disclosures, the calculated average West Texas Intermediate oil prices were $65.56, $51.34 and $42.75 per barrel, respectively. The calculated average Brent oil prices for 2018, 2017 and 2016 disclosures were $72.20, $54.93 and $44.49, per barrel, respectively. The calculated average Henry Hub gas prices for 2018, 2017 and 2016 were $3.10, $3.08 and $2.55 per MMBtu, respectively.

Occidental had proved reserves at year-end 2018 of 2,752 million BOE, compared to the year-end 2017 amount of 2,598 million BOE. Proved reserves at year-end 2018 and 2017 consisted of, respectively, 57 percent and 58

percent oil, 18 percent and 17 percent NGL and 25 percent and 25 percent natural gas. Proved developed reserves represented approximately 73 percent and 74 percent, respectively, of Occidental’s total proved reserves at year-end 2018 and 2017.

Occidental does not have any reserves from non-traditional sources. For further information regarding Occidental's proved reserves, see "Supplemental Oil and Gas Information" following the "Financial Statements."

Changes in Proved Reserves

Occidental's total proved reserves increased 154 million BOE in 2018, which included additions of 301 million BOE from Occidental's development program.

Changes in reserves were as follows:



(in millions of BOE)	2018
Revisions of previous estimates	56
Improved recovery	294
Extensions and discoveries	7
Purchases	54
Sales	(17	)
Production	(240	)
Total	154

Occidental's ability to add reserves, other than through purchases, depends on the success of improved recovery, extension and discovery projects, each of which depends on reservoir characteristics, technology improvements and oil and natural gas prices, as well as capital and operating costs. Many of these factors are outside management’s control, and may negatively or positively affect Occidental's reserves.

Revisions of Previous Estimates

Revisions can include upward or downward changes to previous proved reserve estimates for existing fields due to the evaluation or interpretation of geologic, production decline or operating performance data. In addition, product price changes affect proved reserves recorded by Occidental. For example, lower prices may decrease the economically recoverable reserves, particularly for domestic properties, because the reduced margin limits the expected life of the operations. Offsetting this effect, lower prices increase Occidental's share of proved reserves under PSCs because more oil is required to recover costs. Conversely, when prices rise, Occidental's share of proved reserves decreases for PSCs and economically recoverable reserves may increase for other operations. In 2018, Occidental had positive revisions of 56 million BOE, mainly in the Permian Basin and Al Hosn Gas.

Reserve estimation rules require that estimated ultimate recoveries be much more likely to increase or remain constant than to decrease, as changes are made due to increased availability of technical data.

Improved Recovery

In 2018, Occidental added proved reserves of 294 million BOE mainly associated with the Permian Basin. These properties comprise both conventional projects, which are characterized by the deployment of EOR

development methods, largely employing application of CO₂flood, waterflood or steam flood, and unconventional projects. These types of conventional EOR development methods can be applied through existing wells, though additional drilling is frequently required to fully optimize the development configuration. Waterflooding is the technique of injecting water into the formation to displace the oil to the offsetting oil production wells. The use of either CO₂ or steam flooding depends on the geology of the formation, the evaluation of engineering data, availability and cost of either CO₂ or steam and other economic factors. Both techniques work similarly to lower viscosity causing the oil to move more easily to the producing wells. Many of Occidental's projects, including unconventional projects, rely on improving permeability to increase flow in the wells. In addition, some improved recovery comes from drilling infill wells that allow recovery of reserves that would not be recoverable from existing wells.

Extensions and Discoveries

Occidental also added proved reserves from extensions and discoveries, which are dependent on successful exploration and exploitation programs. In 2018, extensions and discoveries added 7 million BOE related primarily to the recognition of proved developed reserves in Colombia and Oman.

Purchases of Proved Reserves

Occidental continues to seek opportunities to add reserves through acquisitions when properties are available at prices it deems reasonable. As market conditions change, the available supply of properties may increase or decrease accordingly.

In 2018, Occidental purchased 54 million BOE of proved reserves in the Permian Basin, which mainly came from acquisitions made in the third quarter of 2018.

Sales of Proved Reserves

In 2018, Occidental sold 17 million BOE in proved reserves mainly related to non-core Permian acreage.

Proved Undeveloped Reserves

Occidental had proved undeveloped reserves at year-end 2018 of 750 million BOE, compared to the year-end 2017 amount of 670 million BOE.

Changes in proved undeveloped reserves were as follows:



(in millions of BOE)	2018
Revisions of previous estimates	8
Improved recovery	158
Extensions and discoveries	3
Purchases	48
Sales	(16	)
Transfer to proved developed reserves	(121	)
Total	80

Occidental incurred approximately $1.1 billion in 2018 to convert proved undeveloped reserves to proved developed reserves. Permian Basin added approximately

146 million BOE through improved recovery, purchases and revisions.

The 2018 additions to proved undeveloped reserves were partially offset by 121 million BOE of transfers to proved developed reserves, mainly from the Permian Basin, and sales of proved undeveloped reserves related to non-core Permian acreage.

Occidental’s highest-return projects and most active development areas are located in the Permian Basin, which represented 68 percent of the proved undeveloped reserves as of December 31, 2018. The majority of Occidental’s 2019 capital program of $4.5 billion is allocated to the development program in the Permian Basin. Overall, Occidental plans to spend approximately $9.5 billion over the next five years to develop its proved undeveloped reserves in the Permian Basin.

Occidental’s proved undeveloped reserves in international locations are associated with approved long-term international development projects.

Reserves Evaluation and Review Process

Occidental's estimates of proved reserves and associated future net cash flows as of December 31, 2018, were made by Occidental’s technical personnel and are the responsibility of management. The estimation of proved reserves is based on the requirement of reasonable certainty of economic producibility and funding commitments by Occidental to develop the reserves. This process involves reservoir engineers, geoscientists, planning engineers and financial analysts. As part of the proved reserves estimation process, all reserve volumes are estimated by a forecast of production rates, operating costs and capital expenditures. Price differentials between benchmark prices (the unweighted arithmetic average of the first-day-of-the-month price for each month within the year) and realized prices and specifics of each operating agreement are then used to estimate the net reserves. Production rate forecasts are derived by a number of methods, including estimates from decline curve analysis, type curve analysis, material balance calculations that take into account the volumes of substances replacing the volumes produced, and associated reservoir pressure changes, seismic analysis and computer simulation of the reservoir performance. These reliable field-tested technologies have demonstrated reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation. Operating and capital costs are forecast using the current cost environment applied to expectations of future operating and development activities.

Net proved developed reserves are those volumes that are expected to be recovered through existing wells with existing equipment and operating methods for which the incremental cost of any additional required investment is relatively minor.

Net proved undeveloped reserves are those volumes that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. Proved undeveloped reserves are supported by a five-year, detailed, field-level development plan, which includes the timing, location and capital commitment of the wells to be

drilled. The development plan is reviewed and approved annually by senior management and technical personnel. Annually a detailed review is performed by Occidental’s Worldwide Reserves Group and its technical personnel on a lease-by-lease basis to assess whether proved undeveloped reserves are being converted on a timely basis within five years from the initial disclosure date. Any leases not showing timely transfers from proved undeveloped reserves to proved developed reserves are reviewed by senior management to determine if the remaining reserves will be developed in a timely manner and have sufficient capital committed in the development plan. Only proved undeveloped reserves that are reasonably certain to be drilled within five years of booking and are supported by a final investment decision to drill them are included in the development plan. A portion of the proved developed reserves associated with international operations are expected to be developed beyond the five years and are tied to approved long-term development plans.

The current Senior Vice President, Reserves for Oxy Oil and Gas is responsible for overseeing the preparation of reserve estimates, in compliance with U.S. Securities and Exchange Commission (SEC) rules and regulations, including the internal audit and review of Occidental's oil and gas reserves data. He has over 35 years of experience in the upstream sector of the exploration and production business, and has held various assignments in North America, Asia and Europe. He is a three-time past Chair of the Society of Petroleum Engineers Oil and Gas Reserves Committee. He is an American Association of Petroleum Geologists (AAPG) Certified Petroleum Geologist and currently serves on the AAPG Committee on Resource Evaluation. He is a member of the Society of Petroleum Evaluation Engineers, the Colorado School of Mines Potential Gas Committee and the UNECE Expert Group on Resource Classification. He has Bachelor of Science and Master of Science degrees in geology from Emory University in Atlanta.

Occidental has a Corporate Reserves Review Committee (Reserves Committee), consisting of senior corporate officers, to review and approve Occidental's oil and gas reserves. The Reserves Committee reports to the Audit Committee of Occidental's Board of Directors during the year. Since 2003, Occidental has retained Ryder Scott Company, L.P. (Ryder Scott), independent petroleum engineering consultants, to review its annual oil and gas reserve estimation processes.

In 2018, Ryder Scott conducted a process review of the methods and analytical procedures utilized by Occidental’s engineering and geological staff for estimating the proved reserves volumes, preparing the economic evaluations and determining the reserves classifications as of December 31, 2018, in accordance with the SEC regulatory standards. Ryder Scott reviewed the specific application of such methods and procedures for selected oil and gas properties considered to be a valid representation of Occidental’s 2018 year-end total proved reserves portfolio. In 2018, Ryder Scott reviewed approximately 20 percent of Occidental’s proved oil and gas reserves. Since being engaged in 2003, Ryder Scott has reviewed the specific application of Occidental’s

reserve estimation methods and procedures for approximately 80 percent of Occidental’s existing proved oil and gas reserves. Management retains Ryder Scott to provide objective third-party input on its methods and procedures and to gather industry information applicable to Occidental’s reserve estimation and reporting process. Ryder Scott has not been engaged to render an opinion as to the reasonableness of reserves quantities reported by Occidental. Occidental has filed Ryder Scott's independent report as an exhibit to this Form 10-K.

Based on its reviews, including the data, technical processes and interpretations presented by Occidental, Ryder Scott has concluded that the overall procedures and methodologies Occidental utilized in estimating the proved reserves volumes, documenting the changes in reserves from prior estimates, preparing the economic evaluations and determining the reserves classifications for the reviewed properties are appropriate for the purpose thereof and comply with current SEC regulations.

Industry Outlook

The petroleum industry is highly competitive and subject to significant volatility due to various market conditions. WTI and Brent oil price indexes increased throughout a majority of 2018 relative to 2017 but decreased significantly in the fourth quarter of 2018 closing at $45.41 per barrel and $53.80 per barrel, respectively, as of December 31, 2018.

Oil prices will continue to be affected by: (i) global supply and demand, which are generally a function of global economic conditions, inventory levels, production disruptions, technological advances, regional market conditions and the actions of OPEC, other significant producers and governments; (ii) transportation capacity, infrastructure constraints, and costs in producing areas; (iii) currency exchange rates; and (iv) the effect of changes in these variables on market perceptions.

NGL prices are related to the supply and demand for the components of products making up these liquids. Some of them more typically correlate to the price of oil while others are affected by natural gas prices as well as the demand for certain chemical products for which they are used as feedstock. In addition, infrastructure constraints magnify the pricing volatility from region to region.

Domestic natural gas prices and local differentials are strongly affected by local supply and demand fundamentals, as well as government regulations and availability of transportation capacity from producing areas.

These and other factors make it difficult to predict the future direction of oil, NGL and domestic gas prices reliably. For purposes of the current capital plan, Occidental will continue to focus on allocating capital to its highest-return assets with the flexibility to adjust based on fluctuations in commodity prices. International gas prices are generally fixed under long-term contracts. Occidental continues to adjust capital expenditures in line with current economic conditions with the goal of keeping returns well above its cost of capital.

CHEMICAL SEGMENT

Business Environment

In 2018, United States economic growth surpassed that of 2017 and was supported by flat to marginally lower natural gas pricing and lower ethylene costs as compared to the prior year. Although the average cost of natural gas in 2018 was essentially flat with 2017, prices did escalate in December 2018. Ethylene prices trended downward in the first half of 2018 before increasing in the second half with the total year average coming below that of 2017. The impact of lower to flat energy and feedstock costs, along with continued strong demand for caustic and PVC, resulted in higher margins for both products in 2018.

Business Review

Basic Chemicals

In 2018, the United States economic growth rate, estimated to be 2.9 percent, exceeded the 2.2 percent experienced in 2017. The higher U.S. growth rate supported domestic demand, as the 2018 industry chlorine operating rate increased slightly to 89 percent, resulting in an improvement in chlorine pricing in the second quarter of 2018 which was sustained throughout the second half of 2018. Exports of downstream chlorine derivatives into the vinyls chain improved in 2018 as United States ethylene and energy costs remained advantaged over global pricing. Liquid caustic soda prices improved both domestically and globally in 2018 as stable demand and tighter supply supported the higher pricing.

Vinyls

Demand for PVC in 2018 improved year-over-year in total as domestic demand remained flat with 2017 while export demand increased by 10 percent. Domestic demand was supported by construction as housing starts continued to moderately improve year-over-year. Export demand growth was driven by emerging economy growth and competitive North American feedstock costs. Export volume remains a significant portion of PVC sales representing over 30 percent of total North American producer’s production. PVC industry operating rates increased over 2 percent compared to 2017. Industry PVC margins improved in 2018 due to lower ethylene prices.

Industry Outlook

Industry performance will depend on the health of the global economy, specifically in the housing, construction, automotive and durable goods markets. Margins also depend on market supply and demand balances and feedstock and energy prices. Strengthening in the petroleum industry may positively affect the demand and pricing of a number of Occidental’s products that are consumed by industry participants. U.S. commodity export markets will continue to be impacted by the relative strength of the U.S. dollar.

Basic Chemicals

Continued improvement in the United States housing, automotive and durable goods markets should drive a moderate increase in domestic demand for basic chemical products in 2019. Export demand for caustic is also

expected to remain firm, if not improved, in 2019. Chlor-alkali operating rates should improve moderately with higher demand and continued competitive energy and raw material pricing as compared to global feedstock costs. Businesses such as calcium chloride and muriatic acid should improve as oil and gas drilling activity increases in the U.S.

Vinyls

North American demand should show moderate improvement in 2019 over 2018 levels as growth in construction spending continues with further upside potential driven by new infrastructure projects. North American operating rates are expected to remain relatively flat with 2018 and margins should maintain current levels based on strong overall demand and favorable ethylene costs.

MIDSTREAM AND MARKETING SEGMENT

Business Environment

Midstream and marketing segment earnings are affected by the performance of its various businesses, including its marketing, gathering and transportation, gas processing and power-generation assets. The marketing business aggregates, markets and stores Occidental's and third-party volumes. Marketing performance is affected primarily by commodity price changes and margins in oil and gas transportation and storage programs. Gas processing and transportation results are affected by the volumes that are processed and transported through the segment's plants and pipelines, as well as the margins obtained on related services.

In September 2018, Occidental divested non-core midstream assets for total consideration of $2.6 billion, of which approximately $2.4 billion was received at closing, resulting in a pre-tax net gain of $907 million. These assets included the Centurion common carrier oil pipeline and storage system, Southeast New Mexico oil gathering system and Ingleside Crude Terminal. Excluding the gain, the midstream and marketing earnings in 2018 were significantly higher than those in 2017 due to the improvement in the Midland-to-Gulf-Coast spreads, as well as higher gas plant income due to higher domestic NGL prices and higher sulfur prices at Al Hosn Gas.

Business Review

Marketing

The marketing group markets substantially all of Occidental’s oil, NGL and gas production, as well as trades around its assets, including contracted transportation and storage capacity. Occidental’s third-party marketing activities focus on purchasing oil, NGL and gas for resale from parties whose oil and gas supply is located near its transportation and storage assets. These purchases allow Occidental to aggregate volumes to better utilize and optimize its assets. Marketing performance in 2018 improved compared to 2017 as a result of higher marketing margins from improved crude oil price spreads.

Pipeline

Subsequent to the sale of the Centurion common carrier oil pipeline and storage system, Occidental's pipeline business mainly consists of an 11 percent interest in the general partner which owns approximately 40 percent of Plains All American Pipeline, LP, and Dolphin Energy. Dolphin Energy owns and operates a 230-mile-long, 48-inch-diameter natural gas pipeline (Dolphin Pipeline), which transports dry natural gas from Qatar to the UAE and Oman. The Dolphin Pipeline contributes significantly to Occidental's pipeline transportation results through Occidental's 24.5-percent interest in Dolphin Energy. The Dolphin Pipeline has capacity to transport up to 3.2 Bcf of natural gas per day and currently transports approximately 2.2 Bcf per day, and up to 2.5 Bcf per day in the summer.

Gas Processing Plants and CO₂ Fields and Facilities

Occidental processes its and third-party domestic wet gas to extract NGL and other gas byproducts, including CO₂, and delivers dry gas to pipelines. Margins primarily result from the difference between inlet costs of wet gas and market prices for NGL.

Occidental also has a 40-percent participating interest in Al Hosn Gas which is designed to process 1.3 Bcf per day of natural gas and separate it into sales gas, condensate, NGL and sulfur. In 2018, the facilities produced approximately 11,500 metric tons per day of sulfur, of which approximately 4,600 metric tons was Occidental's share. Al Hosn Gas facilities generate revenues from gas processing fees and the sale of sulfur. The increase in 2018 earnings compared to 2017 was primarily due to higher domestic NGL prices and volumes and higher sulfur prices in connection with Al Hosn Gas sulfur sales.

Power Generation Facilities

Earnings from power and steam generation facilities are derived from sales to affiliates and third parties.

Low Carbon Ventures

Also within the midstream and marketing segment is OLCV. OLCV seeks to capitalize on Occidental’s EOR leadership by developing carbon capture, utilization and storage projects that source anthropogenic carbon dioxide and promote innovative technologies that drive cost efficiencies and economically grow Occidental’s business while reducing emissions.

Industry Outlook

Marketing results can experience significant volatility depending on commodity price changes and the Midland-to-Gulf-Coast spreads. Permian takeaway capacity is expected to increase as a result of several new third-party pipelines which are expected to be completed in 2019 and in subsequent years, which will reduce the Midland-to-Gulf-

Coast spreads. The power generation business is expected to remain relatively stable. Gas processing plant operations depend primarily on NGL prices. Generally, higher NGL prices result in higher profitability.

SEGMENT RESULTS OF OPERATIONS AND SIGNIFICANT ITEMS AFFECTING EARNINGS

Segment earnings 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 segments' equity investments. Seasonality is not a primary driver of changes in Occidental's consolidated quarterly earnings during the year.

The following table sets forth the sales and earnings of each operating segment and corporate items:



(in millions, except per share amounts)
For the years ended December 31,	2018			2017			2016
NET SALES ^(a)
Oil and Gas	$	10,441		$	7,870		$	6,377
Chemical	4,657			4,355			3,756
Midstream and Marketing	3,656			1,157			684
Eliminations	(930		)	(874		)	(727		)
	$	17,824		$	12,508		$	10,090
SEGMENT RESULTS AND EARNINGS
Domestic	$	621		$	(589	)	$	(1,552	)
International	1,896			1,767			965
Exploration	(75		)	(67		)	(49		)
Oil and Gas	2,442			1,111			(636		)
Chemical	1,159			822			571
Midstream and Marketing	2,802			85			(381		)
	6,403			2,018			(446		)
Unallocated corporate items
Interest expense, net	(356		)	(324		)	(275		)
Income taxes	(1,477		)	(17		)	662
Other	(439		)	(366		)	(943		)
Income (loss) from continuing operations	4,131			1,311			(1,002		)
Discontinued operations, net	—			—			428
Net income (loss)	$	4,131		$	1,311		$	(574	)
Basic Earnings (loss) per Common Share	$	5.40		$	1.71		$	(0.75	)


(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.

Oil and Gas



(in millions)
For the years ended December 31,	2018			2017			2016
Segment Sales	$	10,441		$	7,870		$	6,377
Segment Results ^(a)
Domestic	$	621		$	(589	)	$	(1,552	)
International	1,896			1,767			965
Exploration	(75		)	(67		)	(49		)
	$	2,442		$	1,111		$	(636	)

Significant items affecting results
Asset sale gains ^(b)	$	—		$	655		$	107
Asset impairments and related items domestic ^(c)	$	—		$	(397	)	$	(1	)
Asset impairments and related items international ^(d)	$	(416	)	$	(4	)	$	(70	)
Total Significant Items	$	(416	)	$	254		$	36


(a)	Results include significant items listed below.


(b)	The 2017 gain on sale of assets included the sale of South Texas and non-core acreage in the Permian Basin. The 2016 gain on sale of assets included the sale of Piceance and South Texas oil and gas properties.


(c)	The 2017 amount included $397 million of impairment and related charges associated with non-core proved and unproved Permian acreage.


(d)	The 2018 amount included $416 million of impairment and related charges associated with Qatar ISND and ISSD. The 2016 amount included a net charge of $61 million related to the sale of Libya and exit from Iraq.



(in millions)
For the years ended December 31,	2018		2017		2016
Average Realized Prices
Oil Prices ($ per bbl)
United States	$	56.30	$	47.91	$	39.38
Latin America	$	64.32	$	48.50	$	37.48
Middle East	$	67.69	$	50.38	$	38.25
Total worldwide	$	60.64	$	48.93	$	38.73
NGL Prices ($ per bbl)
United States	$	27.64	$	23.67	$	14.72
Middle East	$	23.20	$	18.05	$	15.01
Total worldwide	$	26.25	$	21.63	$	14.82
Gas Prices ($ per Mcf)
United States	$	1.59	$	2.31	$	1.90
Latin America	$	6.43	$	5.08	$	3.78
Total worldwide	$	1.62	$	1.84	$	1.53

Domestic oil and gas results were earnings of $621 million in 2018 and losses of $589 million and $1.6 billion in 2017 and 2016, respectively. Excluding significant items affecting results, domestic oil and gas results in 2018 increased from 2017, due to an 18 percent increase in average domestic realized oil prices, 22 percent higher volumes and lower DD&A rates.

Excluding significant items affecting results, domestic oil and gas results in 2017 increased from 2016, due to a 22 percent increase in average domestic realized oil prices, and lower DD&A rates.

International oil and gas earnings were $1.9 billion, $1.8 billion and $965 million in 2018, 2017 and 2016, respectively. Excluding significant items affecting results, the improved international oil and gas earnings in 2018, compared to 2017, reflected a 34 and 33 percent increase in realized crude oil prices in the Middle East and Colombia, respectively. The improved 2017 earnings, excluding significant items, reflected a 32 and 20 percent increase in realized crude oil and NGL prices in the Middle East, respectively.

Average production costs for 2018, excluding taxes other than on income, were $11.98 per BOE, compared to $11.73 per BOE for 2017. The increase in average production costs per BOE reflected increased surface operations and maintenance costs. Permian Resources production costs per BOE for 2018 decreased by 10 percent from the prior year, and the fourth quarter of 2018 costs were below $7.00 per BOE, due to continued improved operational efficiencies.

Average production costs for 2017, excluding taxes other than on income, were $11.73 per BOE, compared to $10.76 per BOE for 2016. The increase in average production costs per BOE reflected the sales of low margin non-core gas assets, which had low operating costs, including South Texas and Piceance Basin.

The following table sets forth the production volumes of oil, NGL and natural gas per day from ongoing operations for each of the three years in the period ended December 31, 2018.



Production per Day from Ongoing Operations (MBOE)	2018	2017	2016
United States
Permian Resources	214	141	124
Permian EOR	154	150	145
Other Domestic	4	5	4
Total	372	296	273
Latin America	32	32	34
Middle East
Al Hosn Gas	73	71	64
Dolphin	40	42	43
Oman	86	95	96
Qatar	55	58	65
Total	254	266	268
Total Production Ongoing Operations	658	594	575
Sold domestic operations	—	8	29
Sold or Exited MENA operations	—	—	26
Total Production (MBOE) ^(a)	658	602	630


(a)	Natural gas volumes have been converted to BOE based on energy content of six Mcf of gas to one barrel of oil. Barrels of oil equivalence does not necessarily result in price equivalence. Please refer to "Supplemental Oil and Gas Information (unaudited)" for additional information on oil and gas production and sales.

Average daily production volumes were 658,000 BOE and 602,000 BOE for 2018 and 2017, respectively, and included production from assets sold or exited of 8,000 BOE for 2017. The increase in production for ongoing operations mainly reflected higher Permian Resources production which increased by 52 percent from the prior year, due to developmental drilling activity and improved well performance.

Average daily production volumes were 602,000 BOE and 630,000 BOE for 2017 and 2016, respectively, and included production from assets sold or exited of 8,000 BOE and 55,000 BOE for 2017 and 2016, respectively. Excluding production for assets sold or exited, average daily production volumes were 594,000 BOE and 575,000 BOE for 2017 and 2016, respectively. The increase in production mainly reflected higher Permian Resources production which increased by 14 percent from 2016 to 2017.

Chemical



(in millions)
For the years ended December 31,	2018		2017		2016
Segment Sales	$	4,657	$	4,355	$	3,756
Segment Results ^(a)	$	1,159	$	822	$	571

Significant items affecting results
Asset sale gains ^(b)	$	—	$	5	$	88
Total Significant Items	$	—	$	5	$	88


(a)	Results include significant items listed below.


(b)	The 2016 amount included the $57 million gain on sale of the Occidental Tower in Dallas and a $31 million gain on the sale of a non-core specialty chemicals business.

Chemical segment earnings were $1.2 billion, $822 million and $571 million for 2018, 2017 and 2016, respectively. Excluding significant items affecting results, the year-over-year increase in 2018 earnings was due to significant improvements in realized caustic soda pricing, strong margins and demand across many product lines and lower ethylene costs, slightly offset by decreased caustic soda export volumes. The 2018 earnings also benefited from the full-year equity contributions from the joint venture ethylene cracker in Ingleside, Texas and additional earning contributions from the Geismar, Louisiana, plant expansion to produce 4CPe.

Excluding significant items affecting results, the year-over-year increase in 2017 earnings compared to 2016, was the result of higher realized pricing for caustic soda, improved vinyl margins, higher sales volumes across most product lines, and the addition of equity income from the joint venture ethylene cracker in Ingleside, Texas.

Midstream and Marketing



(in millions)
For the years ended December 31,	2018		2017			2016
Segment Sales	$	3,656	$	1,157		$	684
Segment Results ^(a)	$	2,802	$	85		$	(381	)

Significant items affecting results
Asset and equity investment gains ^(b)	$	907	$	94		$	—
Asset impairments and related items^(c)	—		(120		)	(160		)
Total Significant Items	$	907	$	(26	)	$	(160	)


(a)	Results include significant items listed below.


(b)	The 2018 amount included a $907 million gain on sale of non-core domestic midstream assets. The 2017 amount included a $94 million non-cash fair value gain on the Plains equity investment.


(c)	The 2017 amount included $120 million of impairment and related charges related to idled midstream facilities. The 2016 amount included charges related to the termination of crude oil supply contracts.

Midstream and marketing segment results were earnings of $2.8 billion and $85 million and a loss of $381 million in 2018, 2017 and 2016, respectively. Excluding significant items affecting results, approximately 85 percent of the increase in 2018 results compared to 2017 reflected higher marketing margins due to improved Midland-to-Gulf-Coast spreads. Approximately 10 percent of the increase reflected higher gas plant income due to higher domestic NGL prices and higher sulfur prices in connection with Al Hosn Gas sulfur sales.

Excluding significant items affecting results, the increase in 2017 results compared to 2016 reflected higher marketing margins due to improved spreads, higher plant income due to higher NGL prices and higher income from a full year of operating the Ingleside Crude Terminal.

Corporate

There were no significant corporate transactions and events affecting 2018 and 2017 results. Significant corporate transactions and events affecting 2016 earnings included charges of $541 million related to a reserve for doubtful accounts, $78 million loss on the distribution of the remaining CRC stock and gains related to the Ecuador settlement. See Note 2 of the consolidated financial statements.

TAXES

Tax Cuts and Jobs Act (Tax Reform) was enacted in December 2017 and made significant changes to the U.S. federal income tax law. In accordance with guidance from the SEC, Occidental recorded provisional estimates with regards to federal and state taxes associated with the mandatory deemed repatriation and resulting impact on the net federal deferred tax liability. With regards to the Global Intangible Low-Tax Income (GILTI) and Base Erosion Anti-Abuse Tax (BEAT) provisions of the new law, Occidental recorded no tax liability on a provisional basis. During 2018, further analysis was completed and additional regulatory guidance was published which led Occidental to revise its initial provisional estimates resulting in a $25 million tax benefit being recorded in 2018. Specifically, the regulatory

guidance related to the allocation of expenses between the net operating losses generated in 2017 and the mandatory deemed repatriation of accumulated earnings from certain U.S.-owned international corporations that was included in 2017 taxable income. Tax Reform also included new limitations on the ability of corporations to deduct interest expense. While these limitations did not adversely impact Occidental in 2018, under proposed regulations the limitations could significantly impact Occidental's ability to deduct interest expense in future years.

Deferred tax liabilities, net of deferred tax assets of $1.3 billion, were $907 million at December 31, 2018. The deferred tax assets, net of allowances, are expected to be realized through future operating income and reversal of temporary differences.

Worldwide Effective Tax Rate

The following table sets forth the calculation of the worldwide effective tax rate for income from continuing operations:



(in millions)	2018			2017			2016
SEGMENT RESULTS
Oil and Gas	$	2,442		$	1,111		$	(636	)
Chemical	1,159			822			571
Midstream and Marketing	2,802			85			(381		)
Unallocated Corporate Items	(795		)	(690		)	(1,218		)
Pre-tax (loss) income	5,608			1,328			(1,664		)
Income tax (benefit) expense
Federal and State	463			(903		)	(1,298		)
Foreign	1,014			920			636
Total income tax (benefit) expense	1,477			17			(662		)
Income (loss) from continuing operations	$	4,131		$	1,311		$	(1,002	)
Worldwide effective tax rate	26		%	1		%	40		%

In 2018, Occidental's worldwide effective tax rate was 26 percent, which is higher than the 2017 rate mainly due to the 2017 remeasurement of net deferred tax liabilities to the new federal corporate income tax rate. Excluding the impact of impairments, asset sales and other nonrecurring items, Occidental's worldwide effective tax rate for 2018 would be 25 percent.

The decrease in worldwide effective tax rate from 2016 to 2017 was due primarily to the remeasurement of net deferred tax liabilities to the new federal corporate income tax rate in 2017.

CONSOLIDATED RESULTS OF OPERATIONS

Changes in components of Occidental's results of continuing operations are discussed below:

Revenue and Other Income Items



(in millions)	2018		2017		2016
Net sales	$	17,824	$	12,508	$	10,090
Interest, dividends and other income	$	136	$	99	$	106
Gain on sale of equity investments and other assets	$	974	$	667	$	202

Price and volume changes generally represent the majority of the change in the oil and gas and chemical segments sales. Midstream and marketing sales are mainly impacted by the change in the Midland-to-Gulf-Coast spread for the marketing business and, to a lesser extent, the change in NGL and sulfur prices for the gas processing business.

The increase in net sales in 2018, compared to 2017, was mainly due to higher crude oil prices and higher domestic crude oil volumes, as well as higher marketing margins in the midstream and marketing segment due to improved Midland-to-Gulf-Coast spreads and higher realized caustic soda prices in the chemical segment. Average worldwide realized oil prices rose approximately 24 percent from 2017 to 2018.

The increase in net sales in 2017, compared to 2016, was mainly due to the increase in average worldwide realized oil and NGL prices, as well as higher realized prices for caustic soda in the chemical business. Average worldwide realized oil prices rose approximately 26 percent from 2016 to 2017.

The 2018 gain on sale included the sale of non-core domestic midstream assets including the Centurion common carrier pipeline and storage system, Southeast New Mexico oil gathering system, and Ingleside Crude Terminal of $907 million.

The 2017 gain on sale included the sale of South Texas and non-core proved and unproved Permian acreage. The 2016 gain on sale included the sales of Piceance and South Texas oil and gas properties, the Occidental Tower building in Dallas, and a non-core specialty chemicals business.

Expense Items



(in millions)	2018		2017		2016
Cost of sales	$	6,568	$	5,594	$	5,189
Selling, general and administrative and other operating expenses	$	1,613	$	1,424	$	1,330
Taxes other than on income	$	439	$	311	$	277
Depreciation, depletion and amortization	$	3,977	$	4,002	$	4,268
Asset impairments and related items	$	561	$	545	$	825
Exploration expense	$	110	$	82	$	62
Interest and debt expense, net	$	389	$	345	$	292

Cost of sales increased in 2018 from the prior year primarily due to higher oil and gas production costs for surface operations and maintenance due to increased activity in the Permian Basin and third-party crude purchases used to fill committed transportation capacity in the marketing business. Cost of sales increased in 2017 from 2016 primarily due to increases in chemical feedstock and energy costs and higher oil and gas purchase injectants.

Selling, general and administrative and other operating expenses increased in 2018 compared to 2017, due to higher environmental remediation costs and higher compensation costs. Selling, general and administrative and other operating expenses increased in 2017 compared to 2016, due to the change in timing of incentive compensation awards.

Taxes other than on income increased in 2018 from 2017 due primarily to higher production taxes, which are directly tied to higher commodity prices. Taxes other than on income in 2017 increased from 2016 due primarily to higher oil, NGL and natural gas prices, which resulted in higher production taxes.

DD&A expense decreased in 2018, compared to 2017, due to lower domestic DD&A rates due to higher reserves partially offset by higher production volumes and higher DD&A rates in the Middle East. DD&A expense decreased in 2017, compared to 2016, due to lower volumes and lower DD&A rates.

In 2018, Occidental incurred impairment and related charges of approximately $416 million on proved oil and gas properties and inventory in Qatar due to the decline in crude oil prices. In 2017, Occidental incurred impairment and related items charges of $545 million, of which $397 million related to proved and unproved non-core Permian acreage and $120 million for idled midstream assets. In 2016, Occidental incurred impairment and related items charges of $825 million, of which $541 million related to a reserve for doubtful accounts and $160 million related to the termination of crude oil supply contracts, $78 million related to the disposal of CRC stock and $61 million related to exits from Libya and Iraq. The allowance for doubtful accounts recorded during 2016 includes a reserve against the long-term receivable related to environmental sites indemnified by Maxus described in Note 9, Environmental Liabilities and Expenditures. Occidental recorded a reserve against this receivable due to the uncertainty of collection as a result of the Maxus bankruptcy.

Other Items



Income/(expense) (in millions)	2018			2017			2016
(Provision for) benefit from income taxes	$	(1,477	)	$	(17	)	$	662
Income from equity investments	$	331		$	357		$	181
Discontinued operations, net	$	—		$	—		$	428

Provision for income taxes increased in 2018 from 2017, due to Tax Reform in 2017 and a higher pre-tax income in 2018. Occidental recorded an income tax expense in 2017 as opposed to an income tax benefit recorded in 2016, due to higher pre-tax operating income as a result of a recovery in commodity prices, partially offset by the deferred tax benefit from Tax Reform.

Excluding the 2017 non-cash fair value gain, income from equity investments increased in 2018, compared to 2017, due to a full year of operations from the OxyChem Ingleside facility. Income from equity investments in 2017 reflected a $94 million non-cash fair value gain on the Plains equity investment. The increase in income from equity investments in 2017 from 2016 is the result of the OxyChem Ingleside facility beginning operations in the first quarter of 2017 and a non-cash fair value gain on the Plains equity investment.

There were no charges for discontinued operations in 2018 and 2017. Discontinued operations, net in 2016 of $428 million, primarily include settlement payments by the Republic of Ecuador. See Note 2 of the Consolidated Financial Statements.

CONSOLIDATED ANALYSIS OF FINANCIAL POSITION

The changes in select components of Occidental’s balance sheet are discussed below:



(in millions)	2018		2017
CURRENT ASSETS
Cash and cash equivalents	$	3,033	$	1,672
Trade receivables, net	4,893		4,145
Inventories	1,260		1,246
Assets held for sale	—		474
Other current assets	746		733
Total current assets	$	9,932	$	8,270

Investments in unconsolidated entities	$	1,680	$	1,515
Property, plant and equipment, net	$	31,437	$	31,174
Long-term receivables and other assets, net	$	805	$	1,067

CURRENT LIABILITIES
Current maturities of long-term debt	$	116	$	500
Accounts payable	4,885		4,408
Accrued liabilities	2,411		2,492
Total current liabilities	$	7,412	$	7,400

Long-term debt, net	$	10,201	$	9,328
DEFERRED CREDITS AND OTHER LIABILITIES
Deferred domestic and foreign income taxes, net	$	907	$	581
Asset retirement obligations	$	1,424	$	1,241
Pension and postretirement obligations	$	809	$	1,005
Environmental remediation reserves	$	762	$	728
Other	$	1,009	$	1,171
Total deferred credits and other liabilities	$	4,911	$	4,726

TOTAL STOCKHOLDERS' EQUITY	$	21,330	$	20,572

Assets

See "Liquidity and Capital Resources — Cash Flow Analysis" for discussion of the change in cash and cash equivalents and restricted cash.

The increase in trade receivables, net, was primarily due to higher crude oil sales volumes at the end of 2018, compared to the end of 2017. The increase in inventories in 2018 primarily reflected higher international crude inventories. The increase in investments in unconsolidated entities is primarily due to capital contributions to the Cactus II Pipeline. The increase in property, plant and equipment, net (PP&E), was primarily due to oil and gas capital additions and acquisitions, which were partially offset by depletion and the sales of non-core domestic midstream assets. The decrease in long-term receivables and other assets, net is primarily due to a $153 million reduction of the alternative minimum tax receivable.

Liabilities

Current maturities of long-term debt represented the $116 million of 9.25-percent senior notes due 2019.

The increase in accounts payable reflected higher oil and gas capital spending compared to the prior year due to increased activity in the Permian Basin and higher marketing payables as a result of higher crude oil prices and third-party purchases. The decrease in accrued liabilities reflected lower mark-to-market derivative liabilities due to lower commodity prices at year end.

The increase in long-term debt, net is a result of the issuance of $1.0 billion of 4.2-percent senior notes due 2048.

The increase in deferred domestic and foreign income tax liabilities, net was primarily due to the utilization of net operating losses and tax credit carry-forwards. The decrease in pension and postretirement obligations was primarily due to the adoption a postretirement benefit plan design change, which decreased the obligation by $178 million, with a corresponding offset to accumulated other comprehensive income.

Stockholders' Equity

The increase in treasury stock reflected the purchase of $1.3 billion of treasury stock in 2018. The increase in retained earnings reflected net income of $4.1 billion, partially offset by the distribution of $2.4 billion of cash dividends. Dividends per share were $3.10 for the year ended December 31, 2018. The increase in additional paid in capital is the result of share issuances resulting from Occidental's long-term incentive programs. The decrease in accumulated other comprehensive loss reflected the postretirement benefit plan design change, partially offset by the reclassification of accumulated other comprehensive income to retained earnings of stranded tax effects resulting from the changes to the U.S. federal tax law from the Tax Reform.

LIQUIDITY AND CAPITAL RESOURCES

At December 31, 2018, Occidental had approximately $3.0 billion in cash and cash equivalents. A substantial majority of this cash is held and available for use in the United States.

Occidental utilized the remaining restricted cash balance resulting from the spin-off of California Resources in the first quarter of 2016 to retire debt and pay dividends.

In March 2018, Occidental issued $1.0 billion of 4.2-percent senior notes due 2048. Occidental received net proceeds of approximately $985 million. Interest on the notes is payable semi-annually in arrears in March and September of each year, beginning on September 15, 2018. The proceeds were used to refinance the repayment of the $500 million aggregate principal amount of Occidental's 1.5-percent senior notes due in February 2018, with the remainder used for general corporate purposes.

In November 2016, Occidental issued $1.5 billion of senior notes, comprised of $750 million of 3.0-percent senior notes due 2027 and $750 million of 4.1-percent senior notes due 2047. Occidental received net proceeds of $1.49 billion. Interest on the senior notes is payable semi-annually in arrears in February and August each year for each series of senior notes. Occidental used the proceeds for general corporate purposes.

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 $400 million 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 is payable semi-annually in arrears in April and October of each year for each series of senior notes. Occidental used a portion of the proceeds to retire debt in May and June 2016, and used the remaining proceeds for general corporate purposes.

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

In January 2018, Occidental entered into a $3.0 billion revolving credit facility (2018 Credit Facility) which matures in January 2023, to replace the previously undrawn $2.0 billion revolving credit facility (2014 Credit Facility), which was scheduled to expire in August 2019. Borrowings under the 2018 Credit Facility bear interest at various benchmark rates, including LIBOR, plus a margin based on Occidental's senior debt ratings. Both credit facilities have similar terms and along with other debt agreements do not contain material adverse change clauses or debt ratings triggers that could restrict Occidental's ability to borrow or that would permit lenders to terminate their commitments or accelerate debt repayment. The 2018 Credit Facility provides for the termination of loan commitments and requires immediate repayment of any outstanding amounts if certain events of default occur.

Occidental paid average annual facility fees of 0.08 percent in 2018 on the total commitment amounts of the 2018 Credit Facility. Occidental did not draw down any amounts under the 2018 Credit Facility during 2018. Occidental did not draw down any amounts under the 2014 Credit Facility during 2017 or 2016.

As of December 31, 2018, 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 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 through future borrowings, and if necessary, proceeds from other forms of capital issuance.

Cash Flow Analysis



Cash provided by operating activities
(in millions)	2018		2017		2016
Operating cash flow from continuing operations	$	7,669	$	4,861	$	2,520
Operating cash flow from discontinued operations, net of taxes	—		—		864
Net cash provided by operating activities	$	7,669	$	4,861	$	3,384

Cash provided by operating activities of $7.7 billion in 2018 increased $2.8 billion from $4.9 billion in 2017. The increase in operating cash flows reflected higher realized worldwide oil and NGL prices, which increased by 24 percent and 21 percent, respectively, as well as a 25 percent increase in domestic oil volumes. Operating cash flows in 2018 also benefited from higher marketing margins in the midstream and marketing segment due to improved Midland-to-Gulf-Coast spreads and higher chemical margins from significant improvements in caustic soda prices.

Cash provided by operating activities from continuing operations in 2017 increased $2.4 billion to $4.9 billion, from $2.5 billion in 2016. Operating cash flows were positively impacted by higher worldwide oil and NGL prices and higher domestic volumes in the oil and gas business and improved margins in the midstream and marketing and chemicals businesses. Cash flows from continuing operations in 2017 also included $761 million of federal tax refunds.

Other cost elements, such as labor costs and overhead, are not significant drivers of changes in cash flow because they are relatively stable within a narrow range over the short to intermediate term. Changes in these costs had a much smaller effect on cash flows than changes in oil and gas product prices, sales volumes and operating costs.



Cash used by investing activities
(in millions)	2018			2017			2016
Capital expenditures
Oil and Gas	$	(4,413	)	$	(2,945	)	$	(1,978	)
Chemical	(271		)	(308		)	(324		)
Midstream and Marketing	(216		)	(284		)	(358		)
Corporate	(75		)	(62		)	(57		)
Total	(4,975		)	(3,599		)	(2,717		)
Other investing activities, net	1,769			520			(2,026		)
Net cash used by investing activities	$	(3,206	)	$	(3,079	)	$	(4,743	)

Occidental’s capital expenditures increased by $1.4 billion in 2018 to $5.0 billion. The increase was a result of additional capital spending, primarily in the Permian Basin due to its high returns. Occidental’s capital expenditures increased by approximately $900 million in 2017 to $3.6 billion. Occidental's 2019 capital spending is expected to be $4.5 billion.

In 2018, cash flows provided by other investing activities of $1.8 billion was comprised primarily of proceeds from the sale of non-core domestic midstream assets, partially offset by asset purchases primarily related to the acquisition of a previously leased power and steam cogeneration facility.

In 2017, cash flows provided by other investing activities of $520 million includes proceeds of $1.4 billion, which were primarily related to the sale of non-core Permian acreage and Occidental's South Texas operations, partially offset by $1.1 billion of acquisition costs primarily related to Permian properties.

In 2016, cash flows used in other investing activities of $2.0 billion was comprised primarily of the acquisition of acreage in the Permian in October 2016.

Cash used by financing activities

(in millions)

2018