Attached files

file filename
EX-12.1 - EXHIBIT 12.1 RATIO OF EARNINGS TO FIXED CHARGES - Weatherford International plcex121-ratioofearningstofix.htm
EX-23.1 - EXHIBIT 23.1 KPMG CONSENT - Weatherford International plcex231-kpmgconsentwft123115.htm
EX-21.1 - EXHIBIT 21.1 SIGNIFICANT SUBSIDIARIES - Weatherford International plcex211-significantsubswft12.htm
EX-31.2 - EXHIBIT 31.2 CFO 302 CERTIFICATION - Weatherford International plcex312cfo302certwft123115.htm
EX-32.2 - EXHIBIT 32.2 CFO 906 CERTIFICATION - Weatherford International plcex322cfo906certwft123115.htm
EX-32.1 - EXHIBIT 32.1 CEO 906 CERTIFICATION - Weatherford International plcex321ceo906certwft123115.htm
EX-31.1 - EXHIBIT 31.1 CEO 302 CERTIFICATION - Weatherford International plcex311ceo302certwft123115.htm
EX-10.21 - EXHIBIT 10.21 2010 OMNIBUS INCENTIVE PLAN RSU AWARD AGREEMENT - Weatherford International plcex1021wft2010omnibusincent.htm
EX-10.28 - EXHIBIT 10.28 2010 OMNIBUS INCENTIVE PLAN PERFORMANCE UNITS AWARD AGREEMENT - Weatherford International plcex1028wft2010omnibusincent.htm
EX-10.33 - EXHIBIT 10.33 AMENDED AND RESTATED EXECUTIVE EMPLOYMENT AGREEMENT - Weatherford International plcex1033amendedandrestatedex.htm


 
UNITED STATES
 
 
SECURITIES AND EXCHANGE COMMISSION
 
 
Washington, D.C. 20549
 
(Mark One)
 
Form 10-K
 
 
þ
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
 
For the fiscal year ended December 31, 2015
 
 
or
 
¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
 
For the transition period from __________________________________to __________________________________
 
 
Commission file number 001-36504
 
Weatherford International public limited company
(Exact name of registrant as specified in its charter)
Ireland
 
98-0606750
(State or other jurisdiction of incorporation or organization)
 
(I.R.S. Employer Identification No.)
Bahnhofstrasse 1, 6340 Baar, Switzerland
 
CH 6340
(Address of principal executive offices)
 
(Zip Code)
Registrant’s telephone number, including area code: +41.22.816.1500
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
 
Name of each exchange on which registered
Ordinary Shares, par value $0.001 per share
 
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. Yes o 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 o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o
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. o
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 the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer þ
Accelerated filer o
Non-accelerated filer o
Smaller reporting company o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes o No þ
The aggregate market value of the voting stock held by non-affiliates of the registrant as of June 30, 2015 was approximately $7.5 billion based upon the closing price on the New York Stock Exchange as of such date.
The registrant had 779,491,546 ordinary shares outstanding as of February 9, 2016.

DOCUMENTS INCORPORATED BY REFERENCE
Portions of the registrant’s proxy statement for the 2016 Annual General Meeting of Shareholders to be held on June 15, 2016 are incorporated into Part III of this Form 10-K.



Weatherford International plc
Form 10-K for the Year Ended December 31, 2015
Table of Contents

 
PAGE
Item 1
Item 1A
Item 1B
Item 2
Item 3
Item 4
 
 
 
 
 
Item 5
Item 6
Item 7
Item 7A
Item 8
Item 9
Item 9A
Item 9B
 
 
 
 
 
Item 10
Item 11
Item 12
Item 13
Item 14
 
 
 
 
 
Item 15
 
 
 
 


1


Forward-Looking Statements
 
This report contains various statements relating to future financial performance and results, including certain projections, business trends and other statements that are not historical facts. These statements constitute “Forward-Looking Statements” as defined in the Securities Act of 1933, as amended (the “Securities Act”) and the Private Securities Litigation Reform Act of 1995. These forward-looking statements generally are identified by the words “believe,” “project,” “expect,” “anticipate,” “estimate,” “intend,” “budget,” “strategy,” “plan,” “guidance,” “outlook,” “may,” “should,” “could,” “will,” “would,” “will be,” “will continue,” “will likely result,” and similar expressions, although not all forward-looking statements contain these identifying words.

Forward-looking statements reflect our beliefs and expectations based on current estimates and projections. While we believe these expectations, and the estimates and projections on which they are based, are reasonable and were made in good faith, these statements are subject to numerous risks and uncertainties. Accordingly, our actual outcomes and results may differ materially from what we have expressed or forecasted in the forward-looking statements. Furthermore, from time to time, we update the various factors we consider in making our forward-looking statements and the assumptions we use in those statements. However, we undertake no obligation to correct, update or revise any forward-looking statement, whether as a result of new information, future events, or otherwise, except to the extent required under federal securities laws. The following sets forth various risks and uncertainties relating to those statements. Certain of these risks and uncertainties may cause actual results to be materially different from projected results contained in forward-looking statements in this report and in our other disclosures. These risks and uncertainties include, but are not limited to, those described below under “Item 1A. – Risk Factors” and the following:

the price volatility of oil, natural gas and natural gas liquids, including the impact of the significant prolonged decline in the price of these commodities on our financial condition and results of operations;
our ability to realize expected revenues and profitability levels from current and future contracts;
our high level of indebtedness and our ability to service our indebtedness;
global political, economic and market conditions, political disturbances, war, terrorist attacks, changes in global trade policies, and international currency fluctuations;
nonrealization of expected benefits from our acquisitions or business dispositions and our ability to execute such acquisitions and dispositions;
our ability to manage our workforce, supply chain and business processes, information technology systems and technological innovation and commercialization, including the impact of our 2014, 2015 and 2016 cost reduction plans;
increases in the prices and availability of our raw materials;
potential non-cash asset impairment charges for long-lived assets, goodwill, intangible assets or other assets;
changes to our effective tax rate;
potential charges arising out of the U.S. Securities and Exchange Commission (“SEC”) and Department of Justice (“DOJ”) investigation into the circumstances surrounding the prior material weakness in our internal controls over financial reporting for income taxes and the restatements of our historical financial statements in 2011 and 2012;
downturns in our industry which could further affect the carrying value of our goodwill;
member-country quota compliance within the Organization of Petroleum Exporting Countries (“OPEC”);
adverse weather conditions in certain regions of our operations;
our ability to realize the expected benefits from our 2014 redomestication from Switzerland to Ireland and to maintain our Swiss tax residency;
failure to ensure on-going compliance with current and future laws and government regulations, including but not limited to environmental, tax and accounting laws, rules and regulations; and
limited access to capital, significantly higher cost of capital, or difficulty raising additional funds in the equity or debt capital markets.

Finally, our future results will depend upon various other risks and uncertainties, including, but not limited to, those detailed in our other filings with the SEC under the Securities Exchange Act of 1934, as amended (the “Exchange Act”) and the Securities Act. For additional information regarding risks and uncertainties, see our other filings with the SEC.


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PART I
Item 1. Business
 
Weatherford International plc, an Irish public limited company, together with its subsidiaries (“Weatherford,” the “Company,” “we,” “us” and “our”), is a multinational oilfield service company. Weatherford is one of the world’s leading providers of equipment and services used in the drilling, evaluation, completion, production and intervention of oil and natural gas wells. Many of our businesses, including those of our predecessor companies, have been operating for more than 50 years.
 
We conduct operations in over 100 countries and have service and sales locations in nearly all of the oil and natural gas producing regions in the world. Our operational performance is reviewed on a geographic basis and we report the following regions as separate, distinct reporting segments: North America, Latin America, Europe/Sub-Sahara Africa (“SSA”)/Russia, Middle East/North Africa (“MENA”)/Asia Pacific and Land Drilling Rigs.

Our headquarters are located at Bahnhofstrasse 1, 6340 Baar, Switzerland and our telephone number at that location is +41.22.816.1500. Our internet address is www.weatherford.com. General information about us, including our corporate governance policies, code of business conduct and charters for the committees of our Board of Directors, can be found on our web site under the “Investor Relations” section. On our web site we make available, free of charge, our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act as soon as reasonably practicable after we electronically file or furnish them to the SEC. The public may read and copy any materials we have filed with the SEC at the SEC’s Public Reference Room at 100 F Street, NE, Washington, DC 20549. Information on the operation of the Public Reference Room may be obtained by calling the SEC at 1-800-SEC-0330. The SEC maintains a web site that contains our reports, proxy and information statements, and our other SEC filings. The address of that site is www.sec.gov. Our ordinary shares are listed on the NYSE under the symbol “WFT”.

 Strategy
 
Our primary objective is to build stakeholder value through profitable growth in our core product lines with disciplined use of capital and a strong customer focus.
 
Principal components of our strategy include:
Continuously improving the efficiency, productivity and quality of our products and services and their respective delivery to our customers, in order to grow revenues and operating margins and generate free cash flow from our core operations (Formation Evaluation and Well Construction and Completion and Production) and Land Drilling Rigs operations in all of our geographic markets at a rate exceeding underlying market activity;

A commitment to the innovation, invention and integration, development and commercialization of new products and services that meet the evolving needs of our customers across the reservoir lifecycle; and

Further extending the process, productivity, quality, safety and competency across our global infrastructure to meet client demands for our core products and services in an operationally efficient manner.

Markets
 
We are a leading provider of equipment and services to the oil and natural gas exploration and production industry. Demand for our industry’s services and products depends upon commodity prices for oil and gas, the number of oil and natural gas wells drilled, the depth and drilling conditions of wells, the number of well completions, the depletion and age of existing wells and the level of workover activity worldwide.

Technology has become increasingly critical to the oil and natural gas marketplace as a result of the maturity of the world’s oil and natural gas reservoirs, accelerating production decline rates and the focus on complex well designs, including deep-water prospects. Clients continue to seek, test and use production-enabling technologies at an increasing rate. We have invested a substantial amount of our time and resources into building our technology offerings, which help us provide our clients with more efficient tools to find and produce oil and natural gas. We believe our products and services enable our clients to reduce their costs of drilling and production and/or increase production rates. Furthermore, these offerings afford us additional opportunities to sell our core products and services to our clients.
 

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Product Offerings

Our principal business is to provide equipment and services to the oil and natural gas exploration and production industry, both on land and offshore, through our three business groups: (1) Formation Evaluation and Well Construction, (2) Completion and Production and (3) Land Drilling Rigs, which together include 14 product lines.

Formation Evaluation and Well Construction includes Managed-Pressure Drilling, Drilling Services, Tubular Running Services, Drilling Tools, Wireline Services, Testing and Production Services, Re-entry and Fishing Services, Cementing, Liner Systems, Integrated Laboratory Services and Surface Logging Systems.

Completion and Production includes Artificial Lift Systems, Stimulation and Completion Systems.

Land Drilling Rigs encompasses our land drilling rigs business, including the products and services ancillary thereto.

Formation Evaluation and Well Construction

Within the Formation Evaluation and Well Construction business group we provide formation evaluation services from early well planning to reservoir management services, including core analysis, surface logging, well site geochemistry, logging while drilling and wireline services. Our full suite of formation evaluation services has broad applications across all types of reservoirs. We also provide well construction services to help clients ensure well integrity for the full life cycle of the well using reliable casing and tubing strings, cementation design, reliable liner top isolation and methods that ensure the well reaches total depth in the best condition possible. Further descriptions of our product lines are as follows:

Managed-Pressure Drilling consists of several drilling techniques including closed-loop drilling, air drilling, managed-pressure drilling and underbalanced drilling.

Drilling Services includes directional drilling, logging while drilling, measurement while drilling and rotary steerable systems. This service line also includes our full range of downhole equipment including high temperature motors, wireline steering tools, air rotary hammer drills, casing exit systems, downhole deployment valves and downhole data acquisition equipment.

Tubular Running Services consists of a wide variety of tubular connection and installation services for the drilling, completion and workover of an oil or natural gas well, including liner systems, solid expandable systems, zonal isolation products and swellable well-construction technologies. We also specialize in critical-service installations.

Drilling Tools includes our patented drilling jars, underreamers, rotating control devices, downhole tools, drillpipe and related tools, tubular handling equipment and other pressure-control equipment used in drilling oil and natural gas wells. We also offer wellhead systems to reduce time in changing wellhead sizes while increasing safety procedures, production monitoring and optimization, and flow measurement which measures how much oil, water and gas is flowing in a well.

Wireline Services includes open hole and cased-hole logging services to measure the physical properties of underground formations and help determine the location and potential deliverability of oil and gas from a reservoir. It also includes production and produced water systems for fracturing, production disposal and enhanced oil recovery operations. We also offer global petroleum consulting services in the geoscience and engineering domain.

Testing and Production Services include drillstem test tools, early production facilities, life-of-field production facilities, produced-water systems, tubing conveyed perforating systems and well testing systems.

Re-entry and Fishing Services provides re-entry services, fishing services, thru-tubing services, well abandonment services and wellbore cleaning services.

Cementing operations comprise one of the most expensive phases of well completion. We produce specialized equipment that allows operators to centralize the casing throughout the wellbore and control the displacement of cement and other fluids for proper zonal isolation. Our cementing engineers also analyze complex wells and provide all job requirements from pre-job planning to installation.

Liner Systems includes liner hangers, which allow suspension of strings of casing within a wellbore without the need to extend the casing to the surface. Most directional wells include one or more liners to optimize casing programs. Drilling liners are used

4


to isolate areas within the well during drilling operations. Production liners are used in the producing area of the well to support the wellbore and to isolate various sections of the well.

Integrated Laboratory Services provides support for fluid reservoir characterization, specialized core and fluid testing, enhanced oil recovery, rock strength and characterization, sour richness and maturity, sorption properties assessment and reservoir flow studies.

Surface Logging Systems provide advanced gas analysis, drilling instrumentation, mud logging services and wellsite consultants.

Completion and Production

The Completion and Production business group provides a comprehensive line of products and services, plus specialized technologies, for stimulating and completing wells effectively in all types of reservoirs. Our completion products, reservoir stimulation design and engineering capabilities are delivered to unlock reserves in deepwater, unconventional and aging reservoirs. Our suite of production optimization services boosts field productivity and profitability through our artificial lift portfolio as well as production workflows and optimization software. Further descriptions are as follows:

Artificial Lift Systems are installed in oil and gas wells without sufficient reservoir pressure to produce oil or natural gas from the well. We provide most forms of lift, including reciprocating rod lift systems which create a pumping action via a downhole rod pump, progressing cavity pumping for predominantly heavy oil, coal-bed methane and medium crude oil applications, gas lift systems for producing reservoirs or in wells that have stopped working, hydraulic lift systems to operate a downhole hydraulic pump (jet or piston), plunger lift systems primarily for dewatering liquid loaded gas wells and hybrid lift systems for special applications.

Stimulation offers clients advanced chemical technology and services for safer and more effective production enhancement. These products and services include: a full fleet of pressure pumping services, which include cementing services, coiled tubing services equipment designed to ensure effective results during operations that require coiled tubing intervention, and reservoir stimulation hydraulic fracturing services for oil and natural gas wells in low-permeability reservoirs.

Completion Systems offers clients a comprehensive line of completion tools such as cased hole and flow control systems, well screens, industrial screens and sand screens. We also offer a full range of completion services including upper completions, lower completions and reservoir monitoring.

Land Drilling Rigs

The Land Drilling Rigs business group provides onshore contract drilling services and related operations globally for the oil and gas industry. We operate a fleet of land drilling and workover rigs in most major oil and gas producing regions with the concentration in the Middle East and North Africa. With our technologically diverse fleet, we have the capabilities to perform a broad range of advanced drilling projects that include multi-well pad drilling, high pressure high temperature drilling, deep gas drilling, special well design and other unconventional drilling methods in various climatic conditions.

Other Business Data
 
Competition

We provide our products and services worldwide and compete in a variety of distinct segments with a number of competitors. Our principal competitors include Schlumberger, Halliburton, Baker Hughes, National Oilwell Varco, Cameron International, Noble Energy, Nabors Industries and Frank’s International. We also compete with various other regional suppliers that provide a limited range of equipment and services tailored for local markets. Competition is based on a number of factors, including performance, safety, quality, reliability, service, price, response time and, in some cases, breadth of products. See “Item 1A. – Risk Factors – The oilfield services business is highly competitive, which may adversely affect our ability to succeed. Additionally, the impact of consolidation and acquisitions of our competitors is difficult to predict and may harm our business.”


5


Raw Materials
 
We purchase a wide variety of raw materials as well as parts and components made by other manufacturers and suppliers for use in our manufacturing. Many of the products or components of products sold by us are manufactured by other parties. We are not dependent in any material respect on any single supplier for our raw materials or purchased components.

Customers
 
Substantially all of our customers are engaged in the energy industry. Most of our international sales are to large international or national oil companies and these sales have resulted in a concentration of receivables from certain national oil companies worldwide, especially in Latin America. As of December 31, 2015, our receivables from Latin America customers accounted for 38% of our net outstanding accounts receivable balance with $205 million due from Petroleos de Venezuela, S.A. (“PDVSA”) and $47 million from Petroleos Mexicanos (“Pemex”). During 2015, 2014 and 2013, no individual customer accounted for 10% or more of our consolidated revenues.
 
Backlog

Our services are usually short-term in nature, day-rate based and cancellable should our customer wish to alter the scope of work. Consequently, our backlog of firm orders is not material to the Company.

Research, Development and Patents
 
We maintain world-class technology and training centers throughout the world. Additionally, we have research, development and engineering facilities that are focused on improving existing products and services and developing new technologies to meet customer demands for improved drilling performance and enhanced reservoir productivity. Our expenditures for research and development totaled $231 million in 2015, $290 million in 2014 and $265 million in 2013.
 
As many areas of our business rely on patents and proprietary technology, we seek patent protection both inside and outside the U.S. for products and methods that appear to have commercial significance. We amortize patents over the years that we expect to benefit from their existence, which is limited by the life of the patent, and ranges from three to 20 years.
 
Although in the aggregate our patents are important to the manufacturing and marketing of many of our products and services, we do not believe that the loss of any one of our patents would have a material adverse effect on our business.
 
Seasonality
 
Weather and natural phenomena can temporarily affect the level of demand for our products and services. Spring months in Canada and winter months in the North Sea and Russia can affect our operations negatively. Additionally, heavy rains or an exceedingly cold winter in a given region or climate changes may impact our results. The unpredictable impact of climate changes or unusually harsh weather conditions could lengthen the periods of reduced activity and have a detrimental impact to our results of operations. The widespread geographical locations of our operations serve to mitigate the overall impact of the seasonal nature of our business.

Federal Regulation and Environmental Matters
 
Our operations are subject to federal, state and local laws and regulations relating to the energy industry in general and the environment in particular. Our 2015 expenditures to comply with environmental laws and regulations were not material, and we currently do not expect the cost of compliance with environmental laws and regulations for 2016 to be material.
 

6


Employees
 
At December 31, 2015, we employed approximately 39,500 employees. Certain of our operations are subject to union contracts. These contracts cover approximately 17% of our employees. We believe that our relationship with our employees is generally satisfactory.

In response to the significant decline in the price of crude oil and a lower level of exploration and production spending, starting in 2014 and throughout 2015, we reduced our overall costs and workforce to better align with anticipated activity levels. The workforce reductions in 2014 and throughout 2015 totaled approximately 20,300 employees. In response to continued decline and lower prices of crude oil and natural gas and the continued decline in the anticipated level of exploration and production spending in 2016, we initiated a reduction in force plan to reduce our overall costs and workforce to align with the anticipated activity levels and expect to complete a further workforce reduction of 6,000 employees in the first half of 2016.
 
Item 1A. Risk Factors

An investment in our securities involves various risks. You should consider carefully all of the risk factors described below, the matters discussed herein under “Forward-Looking Statements” and other information included and incorporated by reference in this Form 10-K, as well as in other reports and materials that we file with the SEC. If any of the risks described below or elsewhere in this Form 10-K were to materialize, our business, financial condition, results of operations, cash flows or prospects could be materially adversely affected. In such case, the trading price of our common stock could decline and you could lose part or all of your investment. Additional risks and uncertainties not currently known to us or that we currently deem immaterial may also materially adversely affect our financial condition, results of operations and cash flows.

Demand for our services and products is affected by fluctuations in oil and natural gas prices, especially a substantial or extended decline, which, in turn, affect the level of exploration, development and production activity of our customers and could have a material adverse effect on our business, financial condition, results of operations and impede our growth.

Demand for our services and products is tied to the level of exploration, development and production activity and the corresponding capital expenditures by oil and natural gas companies, including national oil companies. The level of exploration, development and production activity is directly affected by fluctuations in oil and natural gas prices, which historically have been volatile and are likely to continue to be volatile in the future, especially given current geopolitical and economic conditions. Therefore, declines in oil and natural gas prices (as has occurred since late 2014) or customer perceptions that oil and natural gas prices will remain depressed or further decrease in the future could result in a reduction in the demand and pricing for our equipment and will likely result in lower rates for our services.

Prices for oil and natural gas are highly volatile and are subject to large fluctuations in response to relatively minor changes in the supply of and demand for oil and natural gas. For example, during 2015 oil prices fluctuated from a high of $61.82 per barrel in mid-June to a low of $35.81 per barrel in late December for West Texas Intermediate (“WTI”) crude. As recently as February 2016, a barrel of WTI crude traded below $27.00 per barrel on the New York Mercantile Exchange. Factors that can or could cause these price fluctuations include: excess supply of crude oil relative to demand; domestic and international drilling activity; global market uncertainty; the risk of slowing economic growth or recession in the United States, China, Europe or emerging markets; the ability of OPEC to set and maintain production levels for oil; the decision of OPEC to abandon production quotas and/or member-country quota compliance within OPEC; oil and gas production levels by non-OPEC countries; the nature and extent of governmental regulation, including environmental regulation; technological advances affecting energy consumption; adverse weather conditions and a variety of other economic factors that are beyond our control. Any perceived or actual further reduction in oil and natural gas prices will depress the immediate levels of exploration, development and production activity and decrease spending by our customers, which could have a material adverse effect on our business, financial condition and results of operations.

The substantial decline in oil and natural gas prices has led to a significant decrease in spending by our customers, and further decreases in oil and natural gas prices could lead to further cuts in spending. Our customers also take into account the volatility of energy prices and other risk factors when determining whether to pursue capital projects and higher perceived risks generally mandate higher required returns. Any of these factors could affect the demand for oil and natural gas and could have a material adverse effect on our business, financial condition, results of operations and cash flow.


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Our business is dependent on capital spending by our customers, and reductions in capital spending by our customers has had and could continue to have an adverse effect on our business, financial condition and results of operations.

The substantial decline in oil and natural gas prices has led to a significant decrease in capital expenditures by our customers. Most of our contracts can be cancelled by our customer at any time. The declines in commodity prices, the short-term tenor of most of our contracts and the extreme financial stress experienced by our customers (some of whom may have to seek bankruptcy protection) have combined to generate demands by many of our customers for significant reductions in the prices of our products and services. Further reductions in capital spending or requests for further cost reductions by our customers could directly impact our business by reducing demand for our services and products and have a material adverse effect on our business, financial condition, results of operations and prospects. Spending by exploration and production companies can also be impacted by conditions in the capital markets, which have been highly volatile in recent months. Limitations on the availability of capital or higher costs of capital may cause exploration and production companies to make additional reductions to capital budgets even if oil and natural gas prices increase from current levels. Any such cuts in spending will curtail drilling programs as well as discretionary spending on well services, which may result in a reduction in the demand for our services, the rates we can charge and the utilization of our assets. Moreover, reduced discovery rates of new oil and natural gas reserves or a decrease in the development rate of reserves in our market areas, whether due to increased governmental regulation, limitations on exploration and drilling activity or other factors, could also have a material adverse impact on our business, even in a stronger oil and natural gas price environment. With respect to national oil company customers, we are also subject to risk of policy, regime, currency and budgetary changes all of which may affect their capital expenditures.

The credit risks of our concentrated customer base in the energy industry could result in losses.

The concentration of our customer base in the energy industry may impact our overall exposure to credit risk as our customers may be similarly affected by prolonged changes in economic and industry conditions. Some of our customers are experiencing extreme financial distress as a result of falling commodity prices and may be forced to seek protection under applicable bankruptcy laws. Furthermore, countries that rely heavily upon income from hydrocarbon exports have been negatively and significantly affected by the drop in oil prices, which could affect our ability to collect from our customers in these countries, particularly national oil companies. Laws in some jurisdictions in which we operate could make collection difficult or time consuming. We perform on-going credit evaluations of our customers and do not generally require collateral in support of our trade receivables. While we maintain reserves for potential credit losses, we cannot assure such reserves will be sufficient to meet write-offs of uncollectible receivables or that our losses from such receivables will be consistent with our expectations. Additionally, in the event of a bankruptcy of any of our customers, we may be treated as an unsecured creditor and may collect substantially less, or none, of the amounts owed to us by such customer.

Seasonal and weather conditions could adversely affect demand for our services and operations.

Variation from normal weather patterns, such as cooler or warmer summers and winters, can have a significant impact on demand. Adverse weather conditions, such as hurricanes in the Gulf of Mexico or extreme winter conditions in Canada, Russia and the North Sea, may interrupt or curtail our operations, or our customers’ operations, cause supply disruptions or loss of productivity or result in a loss of revenue or damage to our equipment and facilities, which may or may not be insured. Any of these outcomes could have a material adverse effect on our business, financial condition and results of operations.

The oilfield services business is highly competitive, which may adversely affect our ability to succeed. Additionally, the impact of consolidation and acquisitions of our competitors is difficult to predict and may harm our business.

Our business is highly competitive, particularly with respect to marketing our products and services to our customers and securing equipment and trained personnel. Currently the oilfield service industry has significant excess capacity relative to customer demand, and, in most cases, multiple sources of comparable oilfield services are available from a number of different competitors. This competitive environment could impact our ability to maintain market share, defend, maintain or increase pricing for our products and services and negotiate acceptable contract terms with our customers and suppliers. In order to remain competitive, we must continue to add value for our customers by providing, relative to our peers, new technologies, reliable products and services and competent personnel. The anticipated timing and cost of the development of competitive technology and new product introductions can impact our financial results, particularly if one of our competitors were to develop competing technology that accelerates the obsolescence of any of our products or services. Additionally, we may be disadvantaged competitively and financially by a significant movement of exploration and production operations to areas of the world in which we are not currently active, particularly if one or more of our competitors is already operating in that area of the world.


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Furthermore, several of our largest competitors have announced a plan to combine including a merger between Halliburton and Baker Hughes as well as between Schlumberger and Cameron International. Mergers, combinations and consolidations in our industry could result in existing competitors increasing their market share and may result in stronger competitors, which in turn, could have a material adverse effect on our business, financial condition and results of operations. We may not be able to compete successfully in an increasingly consolidated industry and cannot predict with certainty how industry consolidation will affect our other competitors or us.

Physical dangers are inherent in our operations and may expose us to significant potential losses. Personnel and property may be harmed during the process of drilling for oil and natural gas.

Drilling for and producing hydrocarbons, and the associated products and services that we provide, include inherent dangers that may lead to property damage, personal injury, death or the discharge of hazardous materials into the environment. Many of these events are outside our control. Typically, we provide products and services at a well site where our personnel and equipment are located together with personnel and equipment of our customer and third parties, such as other service providers. At many sites, we depend on other companies and personnel to conduct drilling operations in accordance with appropriate safety standards. From time to time, personnel are injured or equipment or property is damaged or destroyed as a result of accidents, failed equipment, faulty products or services, failure of safety measures, uncontained formation pressures or other dangers inherent in drilling for oil and natural gas. Any of these events can be the result of human error. With increasing frequency, our products and services are deployed on more challenging prospects both onshore and offshore, where the occurrence of the types of events mentioned above can have an even more catastrophic impact on people, equipment and the environment. Such events may expose us to significant potential losses.

We may not be fully indemnified against financial losses in all circumstances where damage to or loss of property, personal injury, death or environmental harm occur.

As is customary in our industry, our contracts typically require that our customers indemnify us for claims arising from the injury or death of their employees (and those of their other contractors), the loss or damage of their equipment (and that of their other contractors), damage to the well or reservoir and pollution originating from the customer’s equipment or from the reservoir (including uncontained oil flow from a reservoir) and claims arising from catastrophic events, such as a well blowout, fire, explosion and from pollution below the surface. Conversely, we typically indemnify our customers for claims arising from the injury or death of our employees, the loss or damage of our equipment (other than equipment lost in the hole) or pollution originating from our equipment above the surface of the earth or water.

Our indemnification arrangements may not protect us in every case. For example, from time to time we may enter into contracts with less favorable indemnities or perform work without a contract that protects us. Our indemnity arrangements may also be held to be overly broad in some courts and/or contrary to public policy in some jurisdictions, and to that extent unenforceable. Additionally, some jurisdictions which permit indemnification nonetheless limit its scope by statute. We may be subject to claims brought by third parties or government agencies with respect to which we are not indemnified. Furthermore, the parties from which we seek indemnity may not be solvent, may become bankrupt, may lack resources or insurance to honor their indemnities or may not otherwise be able to satisfy their indemnity obligations to us. The lack of enforceable indemnification could expose us to significant potential losses.

Further, our assets generally are not insured against loss from political violence such as war, terrorism or civil commotion. If any of our assets are damaged or destroyed as a result of an uninsured cause, we could recognize a loss of those assets.

Our business may be exposed to uninsured claims and, as a result, litigation might result in significant potential losses. The cost of our insured risk management program may increase.

In the ordinary course of business, we become the subject of various claims and litigation. We maintain liability insurance, which includes insurance against damage to people, property and the environment, up to maximum limits of $600 million, subject to self-insured retentions and deductibles.

Our insurance policies are subject to exclusions, limitations and other conditions and may not apply in all cases, for example where willful wrongdoing on our part is alleged. It is possible an unexpected judgment could be rendered against us in cases in which we could be uninsured and beyond the amounts we currently have reserved or anticipate incurring, and in some cases those potential losses could be material.


9


Our insurance may not be sufficient to cover any particular loss or our insurance may not cover all losses. For example, although we maintain product liability insurance, this type of insurance is limited in coverage and it is possible an adverse claim could arise in excess of our coverage. Additionally, insurance rates have in the past been subject to wide fluctuation and may be unavailable on terms that we or our customers believe are economically acceptable. Reductions in coverage, changes in the insurance markets and accidents affecting our industry may result in further increases in our cost and higher deductibles and retentions in future years and may also result in reduced activity levels in certain markets. Any of these events would have an adverse impact on our financial performance.

Our operations are subject to environmental and other laws and regulations that may expose us to significant liabilities and could reduce our business opportunities and revenues.

We are subject to various laws and regulations relating to the energy industry in general and the environment in particular. An environmental claim could arise with respect to one or more of our current businesses, products or services, or a business or property that one of our predecessors owned or used, and such claims could involve material expenditures. Generally, environmental laws have in recent years become more stringent and have sought to impose greater liability on a larger number of potentially responsible parties. The scope of regulation of our industry and our products and services may increase further, including possible increases in liabilities or funding requirements imposed by governmental agencies. We also cannot ensure that our future business in the deepwater Gulf of Mexico, if any, will be profitable in light of new regulations that have been, and may continue to be, promulgated and in light of the current risk environment and insurance markets. Further, additional regulations on deepwater drilling elsewhere in the world could be imposed, and those regulations could limit our business where they are imposed.

In addition, members of the U.S. Congress, the U.S. Environmental Protection Agency and various agencies of several states within the U.S. frequently review, consider and propose more stringent regulation of hydraulic fracturing, a service we provide to clients and regulators are investigating whether any chemicals used in the fracturing process might adversely affect groundwater or whether the fracturing processes could lead to other unintended effects or damages. In recent years, several cities and states within the U.S. passed new laws and regulations concerning or banning hydraulic fracturing. A significant portion of North American service activity today is directed at prospects that require hydraulic fracturing in order to produce hydrocarbons. Therefore, additional regulation could increase the costs of conducting our business by subjecting fracturing to more stringent regulation. Such regulation, among other things, may change construction standards for wells intended for hydraulic fracturing, require additional certifications concerning the conduct of hydraulic fracturing operations, change requirements pertaining to the management of water used in hydraulic fracturing operations, require other measures intended to prevent operational hazards or ban hydraulic fracturing completely. Any such federal, state, local or foreign legislation could increase our costs of providing services or could materially reduce our business opportunities and revenues if our customers decrease their levels of activity in response to such regulation or if we are not able to pass along any cost increases to our customers. We are unable to predict whether changes in laws or regulations or any other governmental proposals or responses will ultimately occur, and accordingly, we are unable to assess the potential financial or operational impact they may have on our business.

We conduct some of our business using fixed-fee or turn-key contracts, which subject us to risks associated with cost over-runs, operating cost inflation and potential claims for liquidated damages.

We conduct our business under various types of contracts, including in some cases fixed-fee or turn-key contracts where we estimate costs in advance of our performance. We price these types of contracts based in part on assumptions including prices and availability of labor, equipment and materials as well as productivity, performance and future economic conditions. If our cost estimates prove inaccurate, there are errors or ambiguities as to contract specifications or if circumstances change due to, among other things, unanticipated technical problems, difficulties in obtaining permits or approvals, changes in local laws or labor conditions, weather delays, changes in the costs of equipment and materials or our suppliers’ or subcontractors’ inability to perform, then cost over-runs may occur. We may not be able to obtain compensation for additional work performed or expenses incurred in all cases. Additionally, in some contracts we may be required to pay liquidated damages if we do not achieve schedule or performance requirements of our contracts. Our failure to accurately estimate the resources and time required for fixed-fee contracts or our failure to complete our contractual obligations within the time frame and costs committed could result in reduced profits or a loss for that contract. If the contract is significant, or we encounter issues that impact multiple contracts, cost over-runs could have a material adverse effect on our business, financial condition and results of operations. For example, during 2015 and 2014, we recognized estimated project losses of $153 million and $72 million, respectively, related to our long-term early production facility construction contracts in Iraq that are accounted for under the percentage-of-completion method. Total estimated losses on these two projects were $532 million at December 31, 2015.


10


If our long-lived assets, goodwill, other intangible assets and other assets are further impaired, we may be required to record significant non-cash charges to our earnings.

We recognize impairments of goodwill to its implied fair value when the fair value of any of our reporting units becomes less than its carrying value. Our estimates of fair value are based on assumptions about future cash flows of each reporting unit, discount rates applied to these cash flows and current market estimates of value. Based on the uncertainty of future revenue growth rates, gross profit performance, and other assumptions used to estimate our reporting units’ fair value, future reductions in our expected cash flows could cause a material non-cash impairment charge of goodwill, which could have a material adverse effect on our results of operations and financial condition. Based on the results of our impairment tests we recognized impairments to goodwill of $161 million in 2014.

We also have certain long-lived assets, other intangible assets and other assets which could be at risk of impairment or may require reserves based upon anticipated future benefits to be derived from such assets. Any change in the valuation of such assets could have a material effect on our profitability. Based on our impairment tests in 2015, we recognized total long-lived impairment charges of $638 million and $25 million related to our equity method investments. In 2014 we recognized total long-lived and other asset impairments of $495 million.

We have significant operations that would be adversely impacted in the event of war, political disruption, civil disturbance, economic and legal sanctions or changes in global trade policies.

Like most multinational oilfield service companies, we have operations in certain international areas, including parts of the Middle East, Africa, Latin America, the Asia Pacific, Europe and Russia regions that are subject to risks of war, political disruption, civil disturbance, economic and legal sanctions (such as restrictions against countries that the U.S. government may deem to sponsor terrorism) and changes in global trade policies. Our operations may be restricted or prohibited in any country in which the foregoing risks occur.

In particular, the occurrence of any of these risks could result in the following events, which in turn, could materially and adversely impact our results of operations:

disruption of oil and natural gas exploration and production activities;
restriction of the movement and exchange of funds;
our inability to collect receivables;
loss of or nationalization of assets in affected jurisdictions;
enactment of additional or stricter U.S. government or international sanctions; and
limitation of our access to markets for periods of time.

In the third quarter of 2014, geopolitical issues and disruptions in North Africa, primarily Libya, resulted in the decisions to exit product lines in selected markets, which had a negative impact on our 2014 results. We recognized a restructuring and long-lived asset impairment of $81 million related to these markets. We risk loss of assets in any location where hostilities arise and persist. In these areas we also may not be able to perform the work we are contracted to perform, which could lead to forfeiture of performance bonds.

Continuing political instability in Ukraine, sanctions against Russia, and Russia’s response to those sanctions could materially adversely affect our business, results of operations and financial condition.

Due to Russia’s annexation of the Crimean region of Ukraine in March 2014, economic sanctions against Russia remain in place, which have, and may continue to adversely impact our business, results of operations and financial condition of our Russia operations. Additionally, in the event of further sanctions or changes to existing sanctions our ability to do business in Russia may be further reduced or impacted.

The divestiture of our land drilling rigs business may not be completed on the currently contemplated timeline, or at all, and we may not achieve the intended benefits of our 2014 divestitures.

In 2014, we divested certain of our non-core businesses (land drilling rigs in Russia and Venezuela, engineered chemistry and Integrity drilling fluids, pipeline and specialty services and production services). We have not yet completed the divestiture of the remaining portion of our land drilling rigs, which we may accomplish through an initial public offering, a spin-off, an asset sale,

11


or some combination of the foregoing.  Any such divestiture would be complex in nature and may be affected by unanticipated developments, such as unfavorable market conditions, including as a result of the recent and significant decrease in the price of crude oil, delays in obtaining regulatory or governmental approvals and challenges in establishing processes and infrastructure for both the underlying business and for potential investors or buyers of the business, which may result in such divestiture being delayed, or not being completed at all. There is no guarantee that we will fully realize the intended benefits of consummating such divestiture transactions.

We have been the subject of governmental and internal investigations related to alleged corrupt conduct and violations of U.S. sanctioned country laws, which were costly to conduct, resulted in a loss of revenue and substantial financial penalties and created other disruptions for the business. If we are the subject of such investigations in the future, it could have a material adverse effect on our business, financial condition and results of operations.

In 2013 and 2014, we settled investigations of prior alleged violations by us and certain of our subsidiaries related to certain trade sanctions laws, participation in the United Nations oil-for-food program governing sales of goods into Iraq and non-compliance with the Foreign Corrupt Practices Act (“FCPA”). These settlement agreements required us to pay $253 million and to retain, for a period of 18 months, an independent monitor responsible for assessing our compliance with the terms of the settlement agreements so as to address and reduce the risk of recurrence of alleged misconduct, after which will continue to evaluate our own compliance program and make periodic reports to the Department of Justice (“DOJ”) and SEC and to maintain agreed compliance monitoring and reporting systems, all of which was and is costly to us. These settlement agreements also required us to retain an independent third party to retroactively audit our compliance with U.S. export control laws during the years 2012, 2013 and 2014.

Failure to comply with the terms of the settlement agreements could have serious consequences. Breach of the settlement agreements with the DOJ could subject us and certain of our subsidiaries to prosecution for the FCPA criminal violations that were resolved in the settlement. Under such circumstances, the DOJ would be permitted to rely upon the admissions we and certain of our subsidiaries made in the settlement, and would benefit from our waiver of certain procedural and evidentiary defenses. Moreover, failure to abide by the terms of the settlement agreement with the SEC could result in rescission of the settlement agreement, exposing us and certain of our subsidiaries to civil enforcement proceedings in connection with the conduct that had previously been resolved in those settlement agreements.

To the extent we violate trade sanctions laws, the FCPA or other laws or regulations in the future, additional fines and other penalties may be imposed and there would be uncertainty as to the ultimate amount of any penalties we could pay and there can be no assurance that actual fines or penalties, if any, will not have a material adverse effect on our business, financial condition and results of operations.

For additional information about these actions and claims, you should refer to the section entitled “Item 8. – Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 21 – Disputes, Litigation and Contingencies.”

Our significant international operations subject us to economic risks and we may be adversely affected by changes in foreign currency including devaluation and changes in local banking and currency regulations and exchange controls.

We operate in virtually every oil and natural gas exploration and production region in the world. In some parts of the world, such as Latin America, the Middle East and Southeast Asia, the currency of our primary economic environment is generally the U.S. dollar, and we use the U.S. dollar as our functional currency. In other parts of the world, we conduct our business in currencies other than the U.S. dollar, and the functional currency is generally the applicable local currency. As such, we are exposed to significant currency exchange risk and devaluation risk. For example, in 2015, 2014 and 2013, we recognized pre-tax currency-related charges of $85 million, $245 million and $100 million, respectively. In 2015, currency devaluation and related charges reflect the impacts of the continued devaluation of the Angolan kwanza and Argentine peso and the recognized remeasurement charges related to the Venezuelan bolivar and the Kazakhstani tenge. The charges in 2014 and 2013 were related to the devaluation of the Venezuelan bolivar. For information about the currency devaluations, refer to the section entitled “Item 8. – Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 1 – Summary of Significant Accounting Policies.” Any future change in the exchange rates in these countries could cause us to take additional charges on the foreign denominated assets held by our subsidiaries.

We are also subject to risks resulting from changes in the implementation of exchange controls, as well as limitations on our ability to reinvest earnings from operations in one country to fund the capital needs of our operations in other countries. If we are

12


unable to reinvest earnings or repatriate foreign income, our liquidity and recognition of income tax liabilities may be negatively affected.

Our business in Venezuela subjects us to actions by the Venezuelan government or our primary customer which could have a material adverse effect on our liquidity, results of operations and financial condition.

The future results of our Venezuelan operations may be adversely affected by many factors, including our ability to take action to mitigate the effect of future exchange controls, actions of the Venezuelan government and the general economic conditions in the country, continued inflation, and future customer payments and spending. We may continue to see a delay in payment on our receivables from our primary customer in Venezuela or may be compelled to accept bonds as payment, which may then be sold at a loss, similar to our bond transaction in 2013 related to $127 million of trade receivables. Upon receipt of bonds for these receivables, we immediately sold them, recognizing a loss of $58 million. If PDVSA further delays paying or fails to pay a significant amount of our outstanding receivables, or if there is a major action by the Venezuelan government, it could have a material adverse effect on our liquidity, consolidated results of operations and consolidated financial condition.

Credit rating agencies could further lower our credit ratings.

Our credit ratings have recently been downgraded by multiple credit rating agencies and these agencies could further downgrade our credit ratings. Our Standard & Poor’s Ratings Services’ (“S&P”) credit rating on our senior unsecured debt is currently BB+ and our short-term rating is B, both with a stable outlook. Our Moody’s Investors Ratings Services’ credit rating on our unsecured debt is currently Ba1 and our short-term rating is SGL-2, both with a stable outlook. However, on January 21, 2016, Moody’s placed the company’s rating on review for downgrade. On April 15, 2015, Fitch Rating assigned a credit rating on our senior unsecured debt of BBB- and our short-term rating of F3, with a negative outlook. On January 25, 2016, Fitch Ratings lowered its credit rating on our senior unsecured debt to BB from BBB- and lowered our short-term rating to B from F3 and maintained its negative outlook. The lowering of our credit ratings in 2015 to non-investment grade levels resulted in our loss of access to the commercial paper market for our short-term liquidity needs. Furthermore, our non-investment grade status may limit our ability to refinance our existing debt, could cause us to refinance or issue debt with less favorable and more restrictive terms and conditions, and could increase certain fees and interest rates of our borrowings. Suppliers and financial institutions may lower or eliminate the level of credit provided through payment terms or intraday funding when dealing with us thereby increasing the need for higher levels of cash on hand, which would decrease our ability to repay debt balances.

Capital financing may not be available to us at economic rates.

Credit and equity markets have been highly volatile in recent months, the cost to obtain capital financing has increased, and some markets may not be available at certain times. Credit and equity market conditions and the potential impact on liquidity of major financial institutions may have an adverse effect on our ability to fund operational needs or other activities through borrowings under either existing or newly created instruments in the public or private markets on terms we believe to be reasonable. If we are unable to borrow via debt offerings or our credit facility, or to obtain equity financing, we could experience a reduction of liquidity and may result in difficulty funding our operations, repayment of short-term borrowings, payments of interest and other obligations. This could be detrimental to our business and have a material adverse effect on our liquidity, consolidated results of operations and financial condition.

A terrorist attack could have a material and adverse effect on our business.

We operate in many dangerous countries, such as Iraq, in which acts of terrorism or political violence are a substantial and frequent risk. Such acts could result in kidnappings, illegal detainment, or the loss of life of our employees or contractors, a loss of equipment, which may or may not be insurable in all cases, or a cessation of business in an affected area. We cannot be certain that our security efforts will in all cases be sufficient to deter or prevent acts of political violence or terrorist strikes against us or our customers’ operations.


13


Our failure to maintain effective internal controls over financial reporting has resulted in governmental investigations and shareholder lawsuits and could further result in material misstatements in our financial statements which, in turn, could require us to restate financial statements, may cause investors to lose confidence in our reported financial information and could have an adverse effect on our share price or our debt ratings.

We have previously identified a material weakness in our internal controls over financial reporting that had resulted in a material weakness in accounting for income taxes. As of December 31, 2013, we remediated our material weakness in accounting for income taxes. We cannot assure that additional material weaknesses in our internal controls over financial reporting will not be identified in the future. Any failure to maintain or implement required new or improved controls, or any difficulties we encounter in their implementation, could result in additional material weaknesses, cause us to fail to meet our periodic reporting obligations or result in material misstatements in our financial statements. Any such failure could also adversely affect the results of periodic management evaluations regarding the effectiveness of our internal controls over financial reporting. The existence of a material weakness could result in errors in our financial statements that could result in a restatement of financial statements, cause us to fail to meet our reporting obligations and/or cause investors to lose confidence in our reported financial information, potentially leading to a decline in our share price.

The SEC and DOJ are investigating the circumstances surrounding the prior material weakness in our internal controls over financial reporting for income taxes and the restatements of our historical financial statements in 2011 and 2012. We are cooperating fully with these investigations. We are unable to predict the outcome of these investigations due to the inherent uncertainties they present and we are unable to predict potential outcomes or estimate the range of potential loss contingencies, if any. The government, generally, has a broad range of civil and criminal penalties available for these types of matters under applicable law and regulation, including injunctive relief, fines, penalties and modifications to business practices, some of which, if imposed on us, could be material to our business, financial condition or results of operations. For additional information about these actions and claims, you should refer to the section entitled “Item 8. – Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 21 – Disputes, Litigation and Contingencies.”

In March 2011, a shareholder derivative action was filed purportedly on behalf of the Company against certain current and former officers and directors, alleging breaches of duty related to the material weakness and restatement announcements. In February 2012, a second shareholder derivative action was filed. On June 30, 2015, we signed a stipulation to settle a purported securities class action captioned Freedman v. Weatherford International LTD., et al., No. 12-cv-2121-LAK (SDNY) for $120 million. The case had been filed in the federal court in the Southern District of New York in March 2012. That case alleges violation of the federal securities laws related to the restatement of our historical financial statements announced on February 21, 2012, and later added claims related to the announcement of a subsequent restatement on July 24, 2012. The settlement is subject to notice to the class and court approval. For additional information about these actions and claims, you should refer to the section entitled “Item 8. – Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 21 – Disputes, Litigation and Contingencies.”

Additionally, in March 2011, a purported shareholder class action captioned Dobina v. Weatherford International Ltd., et al., No. 1:11-cv-01646-LAK (SDNY), was filed in the U.S. District Court for the Southern District of New York, following our announcement on March 1, 2011 of a material weakness in our internal controls over financial reporting for income taxes, and restatement of our historical financial statements. The Dobina lawsuit alleged violation of the federal securities laws by us and certain current and former officers. On January 29, 2014, we, together with certain current and former officers, resolved the Dobina lawsuit. The settlement was approved by the U.S. District Court for the Southern District of New York on January 5, 2015, and final judgment entered on January 30, 2015. Pursuant to the settlement, we were required to pay $53 million, which was entirely funded by our insurers, in exchange for dismissal with prejudice of the litigation and the unconditional release of all claims, known or unknown, that settlement class members brought or could have brought against us and individual defendants related to the facts and allegations in the litigation. As a condition of the settlement, we and the other defendants deny any liability or wrongdoing related to the allegations in the litigation.


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Adverse changes in tax laws both in the United States and abroad, changes in tax rates or exposure to additional income tax liabilities could have a material adverse effect on our results of operations.

In 2002, we reorganized from the United States to a foreign jurisdiction. There are frequent legislative proposals in the United States that attempt to treat companies that have undertaken similar transactions as U.S. corporations subject to U.S. taxes or to limit the tax deductions or tax credits available to United States subsidiaries of these corporations. Our tax expense as a foreign incorporated company could be impacted by changes in tax laws, tax treaties or tax regulations or the interpretation or enforcement thereof or differing interpretation or enforcement of applicable law by the U.S. Internal Revenue Service and other taxing jurisdictions, acting in unison or separately. The inability to reduce our tax expense could have a material impact on our financial statements.

Numerous foreign jurisdictions in which we operate have been influenced by studies performed by the Organization of Economic Cooperation and Development (“OECD”) and are increasingly active in evaluating changes to their tax laws. The OECD, which represents a coalition of member countries, has issued various white papers addressing Tax Base Erosion and Jurisdictional Profit Shifting. Their recommendations are aimed at combating what they believe is tax avoidance. Changes in tax laws could significantly increase our tax expense and require us to take actions, at potential significant expense, to seek to preserve our current level of tax expense.

Our effective tax rate has fluctuated in the past and may fluctuate in the future. Future effective tax rates could be affected by changes in the composition of earnings in countries in which we operate with differing tax rates, changes in tax laws, or changes in deferred tax assets and liabilities. We assess our deferred tax assets on a quarterly basis to determine whether a valuation allowance may be required. A prolonged downturn could result in us needing to record a valuation allowance on current or future deferred tax assets, which would negatively impact our financial results.

U.S. persons that own, or are deemed to own, 10% or more of our shares may be subject to U.S. federal income taxation under the controlled foreign corporation (“CFC”) rules and may also subject the Company to increased taxation. The potential for shareholders to be taxed under the CFC rules may impact demand for our shares.

Currently, certain of our subsidiary corporations are not considered CFCs because they are less than 50% owned by our U.S. group of subsidiaries and other 10% or greater shareholders. However, there is a risk that if a U.S. shareholder holds 10% or more of our shares, directly, indirectly or by attribution, that some of our subsidiaries could be classified as CFCs for U.S. federal income tax purposes. If one or more of our subsidiaries is classified as a CFC, any shareholder that is a U.S. person that owns, directly or indirectly or by attribution, 10% or more of our outstanding shares, as well as the Company, may be subject to U.S. income taxation at ordinary income tax rates on all or a portion of the CFC’s undistributed earnings and profits attributable to “subpart F income.” The CFC rules are complex and U.S. persons that hold our shares are urged to consult their own tax advisors regarding the possible application of the CFC rules to them in their particular circumstances. The risk of being subject to increased taxation may deter our current shareholders from acquiring additional ordinary shares or new shareholders from establishing a position in our ordinary shares. Either of these scenarios could impact the demand for, and value of, our shares.

The anticipated benefits of our redomestication to Ireland may not be realized. Additionally, we and our shareholders could be subject to increased taxation if we are considered to be a tax resident in both Switzerland and Ireland.
 
In 2014, we redomesticated from Switzerland to Ireland. We may not realize the benefits we anticipate from this redomestication. Our failure to realize those benefits could have an adverse effect on our business, results of operations and financial condition. Additionally, while we moved our place of incorporation from Switzerland to Ireland in 2014, we continue to be effectively managed from Switzerland. Under current Swiss law a company is regarded as a Swiss tax resident if it has its place of effective management in Switzerland or is incorporated in Switzerland. Where a company is treated as a tax resident of Switzerland as a result of having its place of effective management in Switzerland, Irish law provides Ireland will generally treat the company as not resident in Ireland for Irish tax purposes. We intend to maintain our place of effective management in Switzerland and therefore qualify as a Swiss, but not Irish, tax resident. However, it is possible that in the future, whether as a result of a change in law or tax treaty or how we manage our business, that we could become a tax resident in Ireland in addition to Switzerland. If we were to be considered to be a tax resident of Ireland, we could become liable for Irish and Swiss corporation tax and any dividends paid to its shareholders could be subject to Irish and Swiss dividend withholding tax.


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The rights of our shareholders are governed by Irish law following our 2014 redomestication from Switzerland to Ireland. Irish law differs from the laws in effect in the United States and may afford less protection to holders of our securities.

As an Irish company, we are governed by the Irish Companies Act, which differs in some material respects from laws generally applicable to U.S. corporations and shareholders, including, among others, provisions relating to interested directors, mergers and acquisitions, takeovers, shareholder lawsuits and indemnification of directors. Likewise, the duties of directors and officers of an Irish company generally are owed to the company only. Shareholders of Irish companies generally do not have a personal right of action against directors or officers of the company and may exercise such rights of action on behalf of the company only in limited circumstances. Accordingly, holders of our securities may have more difficulty protecting their interests than would holders of securities of a corporation incorporated in a jurisdiction of the United States. Additionally, while we are an Irish company, we hold shareholders meetings in Switzerland, which may make attendance in person more difficult for some investors.

We are incorporated in Ireland and a significant portion of our assets are located outside the United States. As a result, it might not be possible for shareholders to enforce civil liability provisions of the federal or state securities laws of the United States.

We are organized under the laws of Ireland, and a significant portion of our assets are located outside the United States. The United States currently does not have a treaty with Ireland providing for the reciprocal recognition and enforcement of judgments in civil and commercial matters. As such, a shareholder who obtains a court judgment based on the civil liability provisions of U.S. federal or state securities laws may be unable to enforce the judgment against us in Ireland. In addition, there is some doubt as to whether the courts of Ireland and other countries would recognize or enforce judgments of U.S. courts obtained against us or our directors or officers based on the civil liabilities provisions of the federal or state securities laws of the United States or would hear actions against us or those persons based on those laws. The laws of Ireland do, however, as a general rule, provide that the judgments of the courts of the United States have the same validity in Ireland as if rendered by Irish Courts. Certain important requirements must be satisfied before the Irish Courts will recognize the U.S. judgment. The originating court must have been a court of competent jurisdiction, the judgment must be final and conclusive and the judgment may not be recognized if it was obtained by fraud or its recognition would be contrary to Irish public policy. Any judgment obtained in contravention of the rules of natural justice or that is irreconcilable with an earlier foreign judgment would not be enforced in Ireland.

Similarly, judgments might not be enforceable in countries other than the United States where we have assets.

Item 1B. Unresolved Staff Comments

None.


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Item 2. Properties

Our operations are conducted in over 100 countries and we have manufacturing facilities, research and technology centers, fluids and processing centers and sales, service and distribution locations throughout the world. The following sets forth the locations of our principal owned or leased facilities for our commercial operations by geographic segment as of December 31, 2015:
Region
Specific Location
North America:
Greenville, Houston, Huntsville, Katy, Longview, Odessa, Pasadena, and San Antonio, Texas; Broussard and Schriever, Louisiana; Williston, North Dakota; and Calgary, Edmonton, and Nisku, Canada.
 
 
Latin America: 
Cutral Co, Argentina; Rio de Janeiro, Brazil; Venustiano Carranza and Villahermosa, Mexico; and Anaco, Venezuela.
 
 
Europe/SSA/Russia:
Langenhagen, Germany; Aberdeen, UK; Atyrau, Kazakhstan; and Stavanger, Norway.
 
 
MENA/Asia Pacific:
Hassi Messaoud, Algeria; Luanda, Angola; Dhahran, Saudi Arabia; North Rumaila, Iraq; Abu Dhabi and Dubai, United Arab Emirates; Jiangsu and Shifang, China; Barmer, India; and Singapore, Singapore.

Our headquarters are in Switzerland, with offices in Geneva and Baar, and we have corporate offices in Houston, Texas. We own or lease numerous other facilities such as service centers, shops and sales and administrative offices throughout the geographic regions in which we operate. All of our owned properties are unencumbered. We believe the facilities that we currently occupy are suitable for their intended use.

Item 3. Legal Proceedings

In the ordinary course of business, we are the subject of various claims and litigation. We maintain insurance to cover many of our potential losses, and we are subject to various self-retention limits and deductibles with respect to our insurance.
 
Please see the following:
Item 1. – BusinessOther Business DataFederal Regulation and Environmental Matters,” which is incorporated by reference into this item.
Item 1A.Risk Factors – We have been the subject of governmental and internal investigations related to alleged corrupt conduct and violations of U.S. sanctioned country laws, which were costly to conduct, resulted in a loss of revenue and substantial financial penalties and created other disruptions for the business. If we are the subject of such investigations in the future, it could have a material adverse effect on our business, financial condition and results of operations,” which is incorporated by reference into this item.
Item 8. – Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 21 – Disputes, Litigation and Contingencies.”
 
Although we are subject to various on-going items of litigation, we do not believe it is probable that any of the items of litigation to which we are currently subject will result in any material uninsured losses to us. It is possible, however, that an unexpected judgment could be rendered against us, or we could decide to resolve a case or cases that would result in a liability that could be uninsured and beyond the amounts we currently have reserved and in some cases those losses could be material.

Item 4. Mine Safety Disclosures
 
Not applicable.


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PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Our ordinary shares are traded under the symbol “WFT” on the New York Stock Exchange (“NYSE”). As of February 9, 2016, there were 1,931 shareholders of record. The following table sets forth, for the periods indicated, the range of high and low sales prices per share for our stock as reported on the NYSE.
 
Price
 
High
 
Low
Year ending December 31, 2015
 
 
 
First Quarter
$
13.12

 
$
9.40

Second Quarter
14.91

 
12.10

Third Quarter
12.35

 
7.21

Fourth Quarter
11.49

 
7.52

 
 
 
 
Year ending December 31, 2014
 
 
 
First Quarter
$
17.53

 
$
13.07

Second Quarter
23.25

 
16.68

Third Quarter
24.88

 
20.00

Fourth Quarter
20.89

 
10.07


On February 9, 2016, the closing sales price of our shares as reported by the NYSE was $6.34 per share. We have not declared or paid cash dividends on our shares since 1984. We intend to retain any future earnings and do not expect to pay any cash dividends in the near future.

In conjunction with our 2014 redomestication, we amended our Executive Deferred Compensation Stock Ownership Plan to provide that benefits thereunder may be payable in cash in lieu of our shares of Weatherford. In 2014, the trustee for our executive deferred compensation plan, a consolidated subsidiary, sold 973,611 shares, at $22.41 per share, of our common stock totaling approximately $22 million in cash proceeds for the benefit of the plan participants.
 
Information concerning securities authorized for issuance under equity compensation plans is set forth in Part III of this report under “Item 12(d). – Securities Authorized for Issuance under Equity Compensation Plans,” which is incorporated by reference into this item.



18


Performance Graph
 
This graph compares the yearly cumulative return on our shares with the cumulative return on the Dow Jones U.S. Oil Equipment & Services Index and the Dow Jones U.S. Index for the last five years. The graph assumes the value of the investment in our shares and each index was $100 on December 31, 2010. The stockholder return set forth below is not necessarily indicative of future performance. The following graph and related information shall not be deemed “soliciting material” or to be “filed” with the SEC, nor shall such information be incorporated by reference into any future filing under the Securities Act or the Exchange Act, except to the extent that we specifically incorporate it by reference into such filing.

Comparison of Five-Year Cumulative Total Return
Weatherford ordinary shares, the Dow Jones U.S.
Oil Equipment and Services Index and
the Dow Jones U.S. Index


19


 Item 6. Selected Financial Data

The following table sets forth certain selected historical consolidated financial data and should be read in conjunction with “Item 7. – Management’s Discussion and Analysis of Financial Condition and Results of Operations” and “Item 8. – Financial Statements and Supplementary Data,” which contain information on the comparability of the selected financial data and are both contained in this report. Discussion of material uncertainties is included in “Item 8. – Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 21 – Disputes, Litigation and Contingencies.” The following information may not be indicative of our future operating results.
 
Year Ended December 31,
(Dollars in millions, except per share amounts)
2015
 
2014
 
2013
 
2012
 
2011
Statements of Operations Data:
 
 
 
 
 
 
 
 
 
Revenues
$
9,433

 
$
14,911

 
$
15,263

 
$
15,215

 
$
12,988

Operating Income (Loss)
(1,546
)
 
505

 
523

 
298

 
1,307

Net Income (Loss) Attributable to Weatherford
(1,985
)
 
(584
)
 
(345
)
 
(778
)
 
189

Basic Earnings (Loss) Per Share Attributable To Weatherford
(2.55
)
 
(0.75
)
 
(0.45
)
 
(1.02
)
 
0.25

Diluted Earnings (Loss) Per Share Attributable To Weatherford
(2.55
)
 
(0.75
)
 
(0.45
)
 
(1.02
)
 
0.25

 
 
 
 
 
 
 
 
 
 
Balance Sheet Data:
 
 
 
 
 
 
 
 
 
Total Assets
$
14,787

 
$
18,889

 
$
21,977

 
$
22,795

 
$
21,051

Short-term Borrowings and Current Portion of Long-term Debt
1,582

 
727

 
1,653

 
1,585

 
1,320

Long-term Debt
5,879

 
6,798

 
7,061

 
7,049

 
6,286

Total Shareholders’ Equity
4,365

 
7,033

 
8,203

 
8,818

 
9,345

Cash Dividends Per Share

 

 

 

 



20


Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

As used herein, the “Company,” “we,” “us” and “our” refer to Weatherford International plc (“Weatherford Ireland”), a public limited company organized under the laws of Ireland, and its subsidiaries on a consolidated basis, or for periods prior to June 17, 2014, to our predecessor, Weatherford International Ltd. (“Weatherford Switzerland”), a Swiss joint-stock corporation and its subsidiaries on a consolidated basis.
 
The following discussion should be read in conjunction with our Consolidated Financial Statements and Notes thereto included in “Item 8. – Financial Statements and Supplementary Data.” Our discussion includes various forward-looking statements about our markets, the demand for our products and services and our future results. These statements include certain risks and uncertainties. For information about these risks and uncertainties, refer to the section entitled “Forward-Looking Statements” and the section entitled “Item 1A. – Risk Factors.”
 
Overview
 
General

We conduct operations in over 100 countries and have service and sales locations in nearly all of the oil and natural gas producing regions in the world. Our operational performance is reviewed on a geographic basis, and we report the following regions as separate, distinct reporting segments: North America, MENA/Asia Pacific, Europe/SSA/Russia, Latin America and Land Drilling Rigs.
 
We principally provide products, equipment and services to the oil and natural gas exploration and production industry, both on land and offshore, through our three business groups: (1) Formation Evaluation and Well Construction and (2) Completion and Production, and (3) Land Drilling Rigs, which together include 14 product lines.

Formation Evaluation and Well Construction includes Managed-Pressure Drilling, Drilling Services, Tubular Running Services, Drilling Tools, Wireline Services, Testing and Production Services, Re-entry and Fishing, Cementing, Liner Systems, Integrated Laboratory Services and Surface Logging.

Completion and Production includes Artificial Lift Systems, Stimulation and Completion Systems.

Land Drilling Rigs encompasses our land drilling business, including the products and services ancillary thereto.

We may sell our products and services separately or may bundle them together to provide integrated solutions up to, and including, integrated well construction where we are responsible for the entire process of drilling, constructing and completing a well. Our customers include both exploration and production companies and other oilfield service companies. Depending on the service line, customer and location, our contracts vary in their terms, provisions and indemnities. We earn revenues under our contracts when products are delivered and services are performed. Typically, we provide products and services at a well site where our personnel and equipment may be located together with personnel and equipment of our customer and third parties, such as other service providers. Our services are usually short-term in nature, day-rate based and cancellable should our customer wish to alter the scope of work. Consequently, our backlog of firm orders is not material to the Company.

Change in Reportable Segments

In the first quarter of 2015, we changed our business structure to better align with management’s current view and future growth objectives. This change involved separating our Land Drilling Rigs business into a reportable segment resulting in a total of five reportable segments which are North America, MENA/Asia Pacific, Europe/SSA/Russia, Latin America and Land Drilling Rigs. We have recast prior periods to conform to the current business segment presentation. See “Note 23 – Segment Information” for additional information.


21


Divestitures

Throughout 2014, we successfully disposed of several of our non-core businesses and an equity investment. We received cash proceeds totaling approximately $1.7 billion from these dispositions and used approximately $1.2 billion of the proceeds to reduce debt. For the year ended December 31, 2014, we recognized a gain on these dispositions of $349 million. Dispositions in 2014 included our land drilling and workover rig operations in Russia and Venezuela, pipeline and specialty services business, engineered chemistry and Integrity drilling fluids businesses and the disposal of all our shares in Proserv. See “Note 2 – Business Combinations and Divestitures” for additional information. In 2015, we did not complete any material dispositions.

Long-lived Asset Impairments and Other Related Charges

In 2015, the continued weakness in crude oil prices contributed to lower exploration and production spending and a decline in the utilization of our land drilling rigs and certain U.S. asset groups. Based on our impairment tests, we recognized total long-lived impairment charges of $638 million in 2015 with $383 million related to pressure pumping, drilling tools and wireline assets in the U.S. and $255 million related to Land Drilling Rigs segment assets. In 2015, we also recognized $130 million related to supply agreement charges in our North America segment. These long-lived asset impairments and other related charges are reported as “Long-Lived Asset Impairments and Other Related Charges” on our Consolidated Statements of Operations. In connection with our long-lived asset impairments in 2015, we prepared an analysis to determine the fair value of our equity method investments. We assessed these declines in value as other than temporary and recognized an impairment loss of $25 million.

For the year ended December 31, 2014, we had total non-cash asset impairment charges of $656 million. In the fourth quarter of 2014, we recognized a long-lived asset impairment of $352 million and a $40 million goodwill impairment charge to adjust the assets of our Land Drilling Rig business to fair value. In the second and third quarters of 2014, as a result of our commitment to sell our land drilling and workover rig operations in Russia and Venezuela, we recorded a $143 million long-lived asset impairment loss and a $121 million goodwill impairment loss.

See “Note 8 – Long-lived Asset Impairments” and “Note 9 – Goodwill” for additional information regarding the long-lived, other asset and goodwill impairments.

Litigation Settlement
 
On June 30, 2015, we settled a purported securities class action for $120 million in exchange for the dismissal with prejudice of the litigation and the unconditional release of all claims captioned Freedman v. Weatherford International Ltd., et al., that was filed in the Southern District of New York against us and certain current and former officers in March 2012. The settlement agreement was subject to notice to the class, approval by the U.S. District Court for the Southern District of New York and other conditions and was paid into escrow in August 2015. We are pursuing reimbursement from our insurance carriers and recovered $15 million of the settlement amount in the fourth quarter of 2015. See “Note 21 – Disputes, Litigation and Contingencies” for additional information.

Industry Trends

The level of spending in the energy industry is heavily influenced by changes in the current and expected future prices of oil and natural gas. Changes in expenditures result in an increased or decreased demand for our products and services. Rig count is an indicator of the level of spending for the exploration for and production of oil and natural gas reserves. The following chart sets forth certain statistics that reflect historical market conditions: 
 
WTI Oil (a)
 
Henry Hub Gas (b)
 
North
American
Rig Count (c)
 
International Rig
Count (c)
2015
$
37.04

 
$
2.36

 
910

 
1,105

2014
53.27

 
2.90

 
2,294

 
1,315

2013
98.42

 
4.19

 
2,129

 
1,320

(a)
Price per barrel of West Texas Intermediate (“WTI”) crude oil as of the last business day of the year indicated at Cushing Oklahoma – Source: Thomson Reuters
(b)
Price per MM/BTU as of the last business day of the year indicated at Henry Hub Louisiana – Source: Thomson Reuters
(c)
Average rig count for the fourth quarter – Source: Baker Hughes Rig Count
 

22


Oil prices fluctuated during 2015, ranging from a high of $61.82 per barrel in mid-June to a low of $35.81 per barrel in late December. Natural gas ranged from a high of $3.21 MM/BTU in mid-January to a low of $1.95 MM/BTU in mid-December. As recently as February 2016, a barrel of WTI crude oil traded below $27.00 per barrel on the New York Mercantile Exchange. Factors influencing oil and natural gas prices during the period include hydrocarbon inventory levels, realized and expected global economic growth, realized and expected levels of hydrocarbon demand, the level of production capacity, weather and geopolitical uncertainty.
 
Outlook

We entered into 2015 challenged by a steep decline in oil prices with a severe market contraction. This decline has materially reduced capital spending by our customers which has reduced our revenue, both through lower activity levels and pricing. In 2015, we completed a reduction in force targeting 14,000 employee positions and realized annualized cost savings of $973 million from this cost reduction initiative. In response to the continued significant decline in the price of crude oil and the continued decline in the anticipated level of exploration and production spending in 2016, we initiated another plan to continue reducing our cost structure through a workforce reduction of 6,000 additional employees that we expect to complete by the first half of 2016. Our 2016 capital expenditures are also expected to be significantly reduced to approximately $300 million, which is 56% lower than our 2015 capital spending.

We have closed approximately 90 operating facilities across North America as of December 31, 2015. In addition to our headcount and operating facility reductions, we have closed six of our manufacturing and service facilities during 2015 and plan additional closures of 9 manufacturing and service facilities during 2016.

We expect market conditions to continue to weaken during the first half of 2016 with the potential for a slight recovery during the second half of the year if commodity prices stabilize. North America will continue to be severely impacted by both lower volume and pricing pressure as our customers continue to respond to the decline in commodity prices. We expect Latin America to show contraction in Mexico, Colombia and Brazil from lower activity levels as well as self-imposed reductions in Ecuador and Venezuela. We expect the Eastern Hemisphere to also show further reductions in all markets due to volume declines and pricing pressure.

Over the longer term, we believe the outlook for our core businesses is favorable. As well production decline rates accelerate and reservoir productivity complexities increase, our clients will continue to face challenges associated with decreasing the cost of extraction activities and securing desired rates of production. These challenges increase our customers’ requirements for technologies that improve productivity and efficiency and therefore increase demand for our products and services. These factors provide us with a positive outlook for our core businesses over the longer term. However, the level of improvement in our core businesses in the future will depend heavily on pricing, volume of work and our ability to offer solutions to more efficiently extract hydrocarbons, control costs and penetrate new and existing markets with our newly developed technologies.

We continually seek opportunities to maximize efficiency and value through various transactions, including purchases or dispositions of assets, businesses, investments or joint ventures. We evaluate our disposition candidates based on the strategic fit within our business and/or objectives. It is also our intention to divest our remaining land drilling rigs when market conditions improve. Upon completion, the cash proceeds from any divestitures are expected to be used to repay or repurchase debt. Any such debt reduction may include the repurchase of our outstanding senior notes prior to their maturity in the open market, privately negotiated transaction or otherwise.

The oilfield services industry growth is highly dependent on many external factors, such as our customers’ capital expenditures, world economic and political conditions, the price of oil and natural gas, member-country quota compliance within OPEC and weather conditions and other factors, including those described in the section entitled “Forward-Looking Statements” and the section entitled “Item 1A. – Risk Factors.”

Opportunities and Challenges
 
Our industry offers many opportunities and challenges. The cyclicality of the energy industry impacts the demand for our products and services. Certain of our products and services, such as our drilling and evaluation services, well installation services and well completion services, depend on the level of exploration and development activity and the completion phase of the well life cycle. Other products and services, such as our production optimization and artificial lift systems, are dependent on production activity. We have created a long-term strategy aimed at growing our businesses, servicing our customers, and most importantly, creating value for our shareholders. The success of our long-term strategy will be determined by our ability to manage effectively any industry cyclicality, respond to industry demands and periods of over-supply or low oil prices, successfully maximize the benefits from our acquisitions and complete the disposition of our land drilling rigs business.

23



Results of Operations

The following table contains selected financial data comparing our consolidated and segment results from operations for 2015, 2014 and 2013. See “Notes to Consolidated Financial Statements – Note 23 – Segment Information” for additional information regarding variances in operating income. 
 
 
 
 
 
 
 
Percentage Change
 
Year Ended December 31,
 
Favorable (Unfavorable)
 (Dollars in millions, except per share data)
2015
 
2014
 
2013
 
2015 vs 2014
 
2014 vs 2013
Revenues:
 
 
 
 
 
 
 
 
 
North America
$
3,494

 
$
6,852

 
$
6,390

 
(49
)%
 
7
 %
MENA/Asia Pacific
1,947

 
2,406

 
2,746

 
(19
)%
 
(12
)%
Europe/SSA/Russia
1,533

 
2,129

 
1,947

 
(28
)%
 
9
 %
Latin America
1,746

 
2,282

 
2,635

 
(23
)%
 
(13
)%
Subtotal
8,720

 
13,669

 
13,718

 
(36
)%
 
 %
Land Drilling Rigs
713

 
1,242

 
1,545

 
(43
)%
 
(20
)%
Total Revenues
$
9,433

 
$
14,911

 
$
15,263

 
(37
)%
 
(2
)%
 
 
 
 
 
 
 
 
 
 
Operating Income (Expense):
 
 
 
 
 
 
 
 
 
North America
$
(308
)
 
$
1,005

 
$
827

 
(131
)%
 
22
 %
MENA/Asia Pacific
(28
)
 
115

 
(62
)
 
(124
)%
 
285
 %
Europe/SSA/Russia
173

 
367

 
266

 
(53
)%
 
38
 %
Latin America
254

 
339

 
320

 
(25
)%
 
6
 %
Subtotal
91

 
1,826

 
1,351

 
(95
)%
 
35
 %
Land Drilling Rigs
(13
)
 
(103
)
 
(33
)
 
87
 %
 
(212
)%
Total Segment Operating Income
78

 
1,723

 
1,318

 
(95
)%
 
31
 %
Research and Development
(231
)
 
(290
)
 
(265
)
 
20
 %
 
(9
)%
Corporate Expenses
(194
)
 
(178
)
 
(201
)
 
(9
)%
 
11
 %
Long-Lived Asset Impairment and Other Related Charges
(768
)
 
(495
)
 

 
(55
)%
 
 %
Restructuring Charges
(232
)
 
(331
)
 

 
30
 %
 
 %
Litigation Charges
(116
)
 

 
(153
)
 
 %
 
100
 %
Goodwill and Equity Investment Impairment
(25
)
 
(161
)
 

 
84
 %
 
 %
Gain (Loss) on Sale of Businesses and Investments, Net
(6
)
 
349

 
24

 
(102
)%
 
1,354
 %
Other Items
(52
)
 
(112
)
 
(200
)
 
54
 %
 
44
 %
Total Operating Income (Expense)
$
(1,546
)
 
$
505

 
$
523

 
(406
)%
 
(3
)%
 
 
 
 
 
 
 
 
 
 
Interest Expense, Net
$
(468
)
 
$
(498
)
 
$
(516
)
 
6
 %
 
3
 %
Currency Devaluation and Related Charges
(85
)
 
(245
)
 
(100
)
 
65
 %
 
(145
)%
Other Income (Expense), Net
3

 
(17
)
 
(77
)
 
118
 %
 
78
 %
Benefit (Provision) for Income Taxes
145

 
(284
)
 
(144
)
 
151
 %
 
(97
)%
Net Loss per Diluted Share
(2.55
)
 
(0.75
)
 
(0.45
)
 
(240
)%
 
(67
)%
Weighted Average Diluted Shares Outstanding
779

 
777

 
772

 
 %
 
(1
)%
Depreciation and Amortization
1,200

 
1,371

 
1,402

 
12
 %
 
2
 %


24


Revenues

The following table contains the percentage distribution of our consolidated revenues by business groups for 2015, 2014 and 2013:
 
Year Ended December 31,
 
2015
 
2014
 
2013
Formation Evaluation and Well Construction
55
%
 
52
%
 
52
%
Completion and Production
37

 
40

 
38

Land Drilling Rigs
8

 
8

 
10

Total
100
%
 
100
%
 
100
%

Consolidated Revenues

2015 vs 2014

Consolidated revenues decreased $5.5 billion, or 37%, in 2015 compared to 2014 across all our segments with declines of $3.4 billion, or 49%, in North America, $1.6 billion, or 23%, in our International segments and $529 million, or 43%, in Land Drilling Rigs. International revenues represent revenues of our regional segments other than North America and the Land Drilling Rigs segments. The decline in North America revenue is consistent with the 60% decrease in North American rig count since December 31, 2014 with significant declines across product lines, particularly pressure pumping, drilling tools, artificial lift, intervention services and drilling services. The decline in the North America segment was driven by a combination of lower activity and customer pricing pressure, with the largest decline primarily in the United States. The disposition of our engineered chemistry business on December 31, 2014 also negatively impacted revenues when compared to the prior year.

The decline in revenues in our International segments is in line with the decrease in international rig count of 16% since 2014 as well as declines in revenue from Europe/SSA/Russia and MENA/Asia Pacific due to pricing pressure and reduced activity across all our product lines. Lastly, our Latin America segment experienced lower activity particularly in the Well Construction and Formation Evaluation product lines.

The decline in our Land Drilling Rigs revenue is primarily attributable to the decline in drilling activity consistent with the rig count declines, decreases in new drilling activity and the 2014 disposal of our land drilling and workover rig operations in Russia and Venezuela.

2014 vs 2013

Consolidated revenues decreased $352 million, or 2%, in 2014 compared to 2013. International revenues decreased $511 million, or 7%, and our Land Drilling Rigs revenues decreased $303 million, or 20%, in 2014 compared to 2013, on a slight decrease in the 2014 annual international rig count and the disposal of our land drilling and workover rig operations in Russia and Venezuela. The decline in Europe/SSA/Russia, Latin America and Land Drilling Rigs revenues was aided by the disposal of our land drilling and workover rig operations in Russia and Venezuela and our pipeline services business. These divestitures were completed on July 31, 2014 and September 1, 2014, respectively. Latin America also experienced additional revenue declines related to the completion of project work in Mexico and the impact of our self-imposed capital discipline to reduce activity in Venezuela which impacted the first half of 2014. The international revenue decline was also attributable to our MENA/Asia Pacific segment due to lower activity on our remaining legacy contracts in Iraq and a reduction in scope of work on a project in China.

The decline in International revenue was partially offset by an increase in North America. Revenue in our North America segment increased $462 million, or 7%, in 2014 compared to the prior year, on an 6% increase in the 2014 annual North American rig count. The increased revenue was primarily due to higher demand for pressure pumping, artificial lift, completions and formation evaluation products and services.


25


Operating Income

2015 vs 2014

Consolidated operating income decreased $2.1 billion, or 406%, in 2015 compared to 2014. The decline in operating income is consistent with the reduction in activity resulting from the significant decline in both the price of oil and rig counts, which has put pressure on our pricing and has resulted in a lower volume of work.

Consolidated operating income for 2015 includes $1.2 billion of charges as follows:

$768 million of long-lived asset impairment charges and supply contract related charges;
$232 million of severance and restructuring charges;
$116 million of litigation charges primarily for the settlement of a lawsuit related to the restatement of our historical financial statements in previous years;
$58 million in professional and other fees, divestiture related charges and facility closures, loss on sale of businesses and investments, and other charges; and
$25 million of equity investment impairment charges.

For additional information regarding charges by segment, see the subsection entitled “Segment Results” and “Restructuring Charges” below.

2014 vs 2013

Consolidated operating income increased $18 million, or 3%, in 2014 compared to 2013. Consolidated operating income for 2014 includes the following charges:

$656 million of non-cash charges primarily for the impairment of long-lived assets and goodwill, of which $495 million is related to long-lived asset impairments and $161 million is related to goodwill impairments;
$331 million of severance and restructuring charges; and
$112 million in charges incurred in conjunction with the divestiture of our non-core businesses, restatement related litigation, the settlement of the U.S. government investigations and our redomestication from Switzerland to Ireland.

Partially offsetting these charges in 2014 was a $349 million gain on sale of businesses and investments, which includes gains on the disposition of our engineered chemistry and Integrity drilling fluids businesses, Proserv investment and pipeline and specialty services business, offset by a loss on the sale of our land drilling and workover rig operations in Russia and Venezuela.

Excluding, from both years, the impairment charges for long-lived assets and goodwill, restructuring charges, the $153 million of FCPA settlement charge in 2013 and the gain on the sale of businesses and investments in both years our consolidated adjusted operating income increased $491 million, or 75%, in 2014 compared to 2013, primarily due to improvements in our geographic segments partially offset by the decline in the Land Drilling Rigs segment.

North America operating income increased $178 million, or 22%, in 2014 driven by the higher revenues from increased demand and improved pricing from our pressure pumping, completions and formation evaluation product lines and a lower cost structure achieved through our reduction in workforce and closure of less profitable locations.
MENA/Asia Pacific operating income increased $177 million, or 285%, primarily due to decreased operating costs related to lower activity on our remaining legacy contract in Iraq, the completion of another legacy Iraq contract earlier in 2014 and a gain of $16 million from the acquisition of an additional 30% ownership interest in a joint venture in China.
Europe/SSA/Russia operating income increased $101 million, or 38%, in 2014, which was largely attributable to improvements in activity in Europe and continued growth in Sub-Sahara Africa, generally across all product lines.
Latin America operating income increased 6% largely related to focus on higher margin activity in Argentina and Brazil with improvements in pressure pumping, formation evaluation and well construction services partially offset by lower demand for our artificial lift and formation evaluation services resulting from the completion of project work in Mexico and our self-imposed capital discipline driven activity reductions in Venezuela during the first half of 2014.
Land Drilling Rigs operating income decreased $70 million, or 212%, in 2014 compared to 2013 primarily the result of the sale of our Russian Land Drilling Rigs business, slight decrease in the international rig count, and facility closure costs related to the 2014 restructuring plan.


26



Gain (Loss) on Sale of Businesses and Investments, Net

During 2015, we did not recognize any material net gain or loss on sale of businesses and investments. During 2014, we recognized a $349 million net gain on sale of businesses and investments, which includes a $250 million gain on the disposition of our engineered chemistry and Integrity drilling fluids businesses, a $65 million gain on the disposition of our Proserv investment and a $49 million gain on the disposition of our pipeline and specialty services business. These gains were partially offset by a $15 million loss on the sale of our land drilling and workover rig operations in Russia and Venezuela.

During 2013, we recognized a $24 million net gain on sale of businesses and investments, which included an $18 million gain on the disposition of our remaining interest in Borets International Limited (“Borets”) and a $6 million gain on the disposition of our industrial screens business.

Currency Devaluation and Related Charges

In 2015, currency devaluations and related charges were $85 million and are included in current earnings in the line captioned “Currency Devaluation and Related Charges” on the accompanying Consolidated Statements of Operations. In 2015, currency devaluation and related charges reflect the impacts of the continued devaluation of the Angolan kwanza of $39 million and Argentine peso of $11 million and the recognized remeasurement charges related to the Venezuelan bolivar of $26 million and the Kazakhstani tenge of $9 million. The Angolan kwanza charges reflect currency devaluations of approximately 24% in 2015. The devaluation of the Argentine peso was due to the modifying of currency control restrictions on purchasing foreign currencies by the Argentine Central Bank. The cumulative depreciation of the Kazakhstani tenge was 46% during 2015 after the National Bank of Kazakhstan abandoned its peg of the tenge to the U.S. dollar. The Venezuelan bolivar charge reflects remeasurement charges when we began using the exchange rate published by the Venezuelan currency exchange system known as the “Marginal Currency System” or SIMADI. The SIMADI opened for trading February 12, 2015, replacing the Venezuela’s Supplementary Foreign Currency Administration System auction rate (“SICAD II”) mechanism. The SIMADI is intended to provide limited access to a free market rate of exchange.

In 2014 and 2013, we recognized charges of $245 million and $100 million, respectively, on the devaluation of the Venezuelan bolivar. As of December 31, 2014, we adopted the SICAD II daily auction rate of approximately 50 Venezuelan bolivars per U.S. dollar. This rate was used at December 31, 2014 for the purposes of remeasuring Venezuelan bolivar denominated assets and liabilities (primarily cash, accounts receivables, trade payables and other current liabilities). The 2013 devaluation was due to the Venezuelan government changing the official exchange rate of the bolivar from 4.3 per dollar to 6.3 per dollar for all goods and services.

Segment Results
 
North America
 
2015 vs 2014

Revenues in our North America segment decreased $3.4 billion, or 49%, in 2015 compared to 2014 primarily due to the 60% decline in the North America rig count since December 31, 2014. The decline in revenue in 2015 was driven by lower activity and pricing pressure that broadly impacted all product lines, particularly pressure pumping, drilling tools, artificial lift, intervention services and drilling services. The disposition of our engineered chemistry business on December 31, 2014 also negatively impacted revenues when compared to the prior year.

Total revenues in the U.S. were $2.9 billion in 2015, $5.6 billion in 2014 and $5.1 billion in 2013. The remaining revenues of our North America segment of $630 million in 2015, $1.3 billion in 2014 and $1.2 billion in 2013, were derived from our operations in Canada.

Operating income in our North America segment decreased $1.3 billion, or 131%, in 2015 compared to 2014. Operating margins were (9)% in 2015 compared to 15% in 2014. The same factors contributing to the decline in revenues directly contributed to the decline in operating income. During 2015, we recognized inventory write-down charges of $73 million and bad debt expense charges of $20 million.

2014 vs 2013


27


Revenues in our North America segment increased $462 million, or 7%, in 2014 compared to 2013. North America rig count increased 8% since December 31, 2013. The 2014 revenue increase was due to higher demand for pressure pumping, artificial lift, completion and formation evaluation products and services and improved pricing in North America across essentially all our core product lines. North America results were also positively impacted by less severe spring seasonality in Canada that resulted in increased productivity in Canada. Revenue in these core product lines had growth of approximately 8% for artificial lift and formation evaluation and 20% for pressure pumping and completions in 2014 compared to 2013.

Operating income increased $178 million, or 22%, in 2014 compared to 2013. The increase in operating income was driven by higher demand and improved pricing from pressure pumping, completions and formation evaluation product lines. Additionally, our decision to reduce our workforce and close lower margin operations this year improved our operating income. Operating margins were 15% in 2014 compared to 13% in 2013.

MENA/Asia Pacific
 
2015 vs 2014

Revenues in our MENA/Asia Pacific segment decreased $459 million, or 19%, in 2015 compared to 2014. The revenue decline affected most product lines although primarily intervention services, wireline, testing and production services, and well construction. The decline was attributable to lower revenues from our legacy Zubair contract in Iraq as it nears completion, lower activity in Yemen from the political disruption and lower activity levels in the Asia Pacific region, primarily in China, Indonesia and Malaysia. Pricing pressure also had an impact on the revenue decline. In addition, our lower revenues reflect the sale of the pipeline and specialty services business in September 2014.

Operating income decreased $143 million, or 124%, in 2015 compared to 2014. The decrease in operating income is primarily attributable to legacy contract project losses in Iraq, lower activity across most product lines and a gain on a step acquisition of a joint venture investment in China in 2014 that did not recur in 2015. The decline was also partially offset by improved profitability for the tubular running services line in 2015 and higher profitability resulting from the closure of unprofitable locations in 2014. During 2015, we recognized inventory write-down charges of $38 million and bad debt expense charges of $7 million.

2014 vs 2013

MENA/Asia Pacific revenues decreased $340 million, or 12%, in 2014 compared to 2013. The lower revenue for 2014 was primarily due to lower activity on legacy contracts in Iraq as a result of lower progress on our percentage-of-completion projects. In addition, we had reduced demand related to decreased activity in Australia and Indonesia, primarily from well construction and our non-core businesses. Furthermore, the 2014 revenues were impacted by a reduction of revenue due to a change in scope on a project in China accounted for under the percentage-of-completion method. Partially offsetting the decline in revenues were improvements across our product lines associated with increased demand for services in the Gulf Countries and Southeast Asia.
 
Operating income increased $177 million, or 285%, in 2014 compared to 2013. The increase in 2014 operating income was primarily due to decreased operating costs related to lower activity on our remaining legacy contracts in Iraq, the completion of a legacy Iraq contract earlier in 2014 and a gain of $16 million as a result of the acquisition of an additional 30% ownership interest in a joint venture in China. Additionally, our decision to reduce our workforce and close lower margin operations in 2014 improved our operating income. Partially offsetting the improvement in MENA/Asia Pacific operating income was the recognition of a $27 million loss resulting from a change in scope on the otherwise profitable project in China accounted for under the percentage-of-completion method.

Europe/SSA/Russia
 
2015 vs 2014

Revenues in our Europe/SSA/Russia segment decreased $596 million, or 28%, in 2015 compared to 2014. The decline in activity directly impacted the decline in revenues in all product lines due to lower demand and pricing pressure. The overall decline was led by Europe, primarily in Norway and Romania. The lower activity from continued project delays and cancellations in Angola and Gabon in Sub-Sahara Africa contributed to the revenue decline while the sale of the pipeline and specialty services and engineered chemistry product lines in the third and fourth quarters of 2014 also resulted in lower segment revenues.


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Operating income decreased $194 million, or 53%, in 2015 compared to 2014. The decline was the direct impact of lower revenue activity and pricing pressure as mentioned above. During 2015, we recognized inventory write-down charges of $32 million and bad debt expense charges of $12 million.

2014 vs 2013

Revenues in our Europe/SSA/Russia segment increased $182 million, or 9%, in 2014 compared to 2013. The increase was driven by increased activity in Europe and new contract start-ups in Sub-Sahara Africa. The Europe and Sub-Sahara Africa regions realized strong performances due to increased demand primarily for our well construction, completions, and formation evaluation products and services. Revenues were down in Russia and the North Sea and due to the impact of a markedly weaker Russian ruble.

Operating income increased $101 million, or 38%, in 2014 compared to 2013. The operating income improvement was primarily attributable to the recovery in the region, improvements in activity in Europe and continued growth in SSA, generally across all product lines. Additionally, our decision to reduce our workforce and close lower margin operations in 2014 improved our operating income. Operating margins were 17% in 2014 and 14% in 2013.
 
Latin America
 
2015 vs 2014

Revenues in our Latin America segment decreased $536 million, or 23%, in 2015 compared to 2014. The decline in revenue is primarily due to reduced demand across our core product lines, primarily artificial lift, drilling services, intervention and pressure pumping in Mexico, Colombia, Venezuela and Ecuador, partially offset by an increase in sales in our managed-pressure drilling product line in Brazil.

Operating income decreased $85 million, or 25%, in 2015 compared to 2014. The same factors contributing to the decline in revenues directly contributed to the decline in operating income, which were partially offset by cost reduction initiatives in Mexico and a continued focus on higher margin activity in Brazil. During 2015, we recognized inventory write-down charges of $54 million and bad debt expense charges of $9 million.

2014 vs 2013

Revenues in our Latin America segment decreased $353 million, or 13%, and operating income increased $19 million, or 6%, in 2014 compared to 2013. The decline in revenues were largely related to a decline in activity associated with lower demand for our artificial lift and formation evaluation services resulting from the completion of project work in Mexico and our self-imposed capital discipline driven activity reductions in Venezuela, which impacted the first half of the year. The increase in operating income was largely due to a continued focus on improved higher margin activity around unconventionals in Argentina and well construction services in Brazil. Operating margins were 15% in 2014 and 12% in 2013.


29


Land Drilling Rigs
 
2015 vs 2014

Revenues in our Land Drilling Rigs segment decreased $529 million, or 43%, in 2015 compared to 2014. The decrease is due to the sale of the Russian Land Drilling Rigs business in July 2014, in addition to the overall decrease in the international rig count and drilling activity, partially offset by improved activity in Oman and Kuwait. Operating loss decreased $90 million, or 87%, in 2015 compared to 2014. The decrease is primarily the result of improved drilling efficiencies in Iraq and Oman and contract termination fees in Chad and India while 2014 included facility closure costs that did not reoccur in 2015. During 2015, we recognized inventory write-down charges of $26 million.

2014 vs 2013

Revenues in our Land Drilling Rigs segment decreased $303 million, or 20%, in 2014 compared to 2013. The decrease was primarily driven by the decrease in the international rig count, which reduced drilling activity and the sale of the Russian Rigs business in July 2014. Operating income decreased $70 million, or 212%, in 2014 compared to 2013. The decrease is primarily the result of the sale of our Russian Land Drilling Rigs business and facility closure costs related to the 2014 restructuring plan.

Interest Expense, Net

Interest expense, net decreased $30 million, or 6%, in 2015 compared to 2014 primarily due to a reduction in our debt balance as a result of lower net debt from divestiture proceeds received in 2014 and the repurchase of certain senior notes in 2014 and 2015. Interest expense, net decreased $18 million, or 3%, in 2014 compared to 2013 primarily due to repayments of our higher coupon senior notes partially offset by an increase in lower cost short-term borrowings in 2014.

Other Income/Expense, Net

Other income, net was $3 million in 2015, and other expense, net was $17 million and $77 million in 2014 and 2013, respectively. In 2015, other income was driven by gains on the repurchase of certain senior notes offset by foreign currency exchange losses due to the strengthening U.S. dollar compared to our foreign denominated operations.

In 2014, other expense, net represents foreign currency exchange losses due to the weakening of foreign currencies of our foreign denominated operations compared to the U.S. Dollar, partially offset by gains on the repurchase of certain senior notes. In 2013, other expense, net primarily represent foreign currency exchange losses due to the strengthening U.S. dollar compared to our foreign denominated operations partially offset by the changes in fair value of our foreign currency forward contracts and cross-currency swap contracts.

Income Taxes

We provide for income taxes based on the laws and rates in effect in the countries in which operations are conducted, or in which we or our subsidiaries are considered resident for income tax purposes. We are exempt from Swiss cantonal and communal tax on income derived outside Switzerland, and are also granted participation relief from Swiss federal tax for qualifying dividend income and capital gains related to the sale of qualifying investments in subsidiaries. We expect that the participation relief will result in a full exemption of participation income from Swiss federal income tax.

The relationship between our pre-tax income or loss from continuing operations and our income tax benefit or provision varies from period to period as a result of various factors which include changes in total pre-tax income or loss, the jurisdictions in which our income is earned, the tax laws in those jurisdictions, the impacts of tax planning activities and the resolution of tax audits. Our income derived in Switzerland is taxed at a rate of 7.83%; however, our effective rate is substantially above the Swiss statutory tax rate as the majority of our operations are taxed in jurisdictions with much higher tax rates.


30


Our income tax benefit in 2015 was $145 million compared to an income tax provision of $284 million in 2014 and $144 million in 2013, respectively, which resulted in an effective tax rate of 7%, (111)% and (85)%, respectively. In 2015, we had a tax benefit of $145 million on a loss before income taxes of $2.1 billion. The tax benefit was favorably impacted by a U.S. loss, which included restructuring impairment charges and a worthless stock deduction. Our results for 2015, includes $255 million of Land Drilling Rig impairment charges, $232 million of restructuring charges, $116 million of litigation settlements, $153 million of legacy project losses, $85 million of currency devaluation and related losses and $25 million of equity investment impairment, all with no significant tax benefit. In addition, we recorded a tax charge of $265 million for a non cash tax expense on distribution of subsidiary earnings.

In 2014, we had a tax provision of $284 million on a loss before income taxes of $255 million. Our results for 2014 included a $161 million goodwill impairment charge, a $245 million loss due to the devaluation of Venezuela bolivar and $72 million of project losses related to our early production facility contracts in Iraq, all of which provided no tax benefit. In addition, we incurred a $495 million long-lived assets impairment charge, with limited tax benefit. During 2014, we also sold our land drilling and workover rig operations in Russia and Venezuela, pipeline and specialty services business, engineered chemistry, Integrity drilling fluids business and our equity investment in Proserv for a total gain of approximately $349 million. Our results in 2014 include significant tax losses in Mexico, Venezuela, and Iraq and in 2013 include significant tax losses in Iraq upon which we recorded valuation allowances of $172 million and $134 million, respectively.

In 2013, our income before tax included a $153 million charge for the settlement of the United Nations oil-for-food program governing sales of goods into Iraq and FCPA matters, a $299 million loss on certain projects in Iraq, a $98 million Venezuela notes receivable impairment charge and other bad debt expense and a $100 million loss due to the devaluation of the Venezuelan bolivar, all with no or little tax benefit. Our 2013 tax provision includes certain discrete tax benefits primarily due to tax planning activities, decreases in reserves for uncertain tax positions due to statute of limitation expiration and audit closures, and the enactment of the American Taxpayer Relief Act, which decreased our effective tax rate for the period.

Our effective tax rate for these periods was also negatively impacted by the taxing regimes in certain countries and our operating structure. Several of the countries in which we operate, primarily in our MENA and SSA regions, tax us based on "deemed", rather than actual, profits. We are not currently profitable in certain of those countries, which results in us accruing and paying taxes based on a "deemed profit" instead of recognizing no tax expense or potentially recognizing a tax benefit. Our operating structure results in us paying withholding taxes on intercompany charges for items such as rentals, management fees, royalties, and interest as well as on applicable third party transactions. Such net withholding taxes were $101 million in 2015, $140 million in 2014 and $85 million in 2013 prior to possibly receiving a tax benefit in the jurisdiction of the payee. We also incur pre-tax losses in certain jurisdictions that do not have a corporate income tax and thus we are not able to recognize an income tax benefit on those losses.

Our effective tax rate improved in 2015 compared to 2014 primarily due to utilization of tax benefits on loss from operations, tax restructuring benefits and decrease in our reserve for uncertain tax positions due to audit settlements and statute expirations, offset by additional valuation allowances booked on non U.S. deferred tax assets and a tax charge for a non cash tax expense on distribution of subsidiary earnings. Our effective tax rate increased from 2013 to 2014 primarily due to the sale of our non-core businesses during the year, non-tax deductible losses, such as the Venezuela bolivar devaluation, Iraq project losses and goodwill impairment, which are partially offset by the decrease of our reserve for uncertain tax benefits due to settlements and statute expirations.


31


Restructuring Charges

In the first quarter of 2014, we announced a cost reduction plan (“the 2014 Plan”), which included a worldwide workforce reduction of 6,300 people and other cost reduction measures. In the fourth quarter of 2014, in response to the significant decline in the price of crude oil and our anticipation of a lower level of exploration and production spending in 2015, we initiated an additional plan (“the 2015 Plan”) to reduce our overall costs and workforce to better align with anticipated activity levels. In 2015, we completed a reduction in force targeting 14,000 employee positions and realized annualized cost savings of $973 million from this cost reduction initiative. In response to the continued significant decline in the price of crude oil and the continued decline in the anticipated level of exploration and production spending in 2016, we initiated a reduction in force plan to reduce our overall costs and workforce to align with the anticipated activity levels and expect to complete a workforce reduction of 6,000 employees in the first half of 2016 and estimate we will incur $75 million to $95 million of severance charges.

In connection with the 2015 Plan, we recognized restructuring charges of $232 million in 2015 and $58 million in 2014. Our restructuring charges during 2015 in connection with the 2015 Plan include termination (severance) benefits of $149 million, restructuring related asset charges of $64 million and other restructuring charges of $19 million. Restructuring related asset charges include asset write-offs of $26 million related to Yemen due to the political disruption and $38 million in other regions. Other restructuring charges include exit costs, contract termination costs, relocation costs and other associated costs. Our restructuring charges during 2014 in connection with the 2015 Plan include termination (severance) benefits of $58 million.

In connection with the 2014 Plan, we recognized restructuring charges of $273 million in 2014. Our restructuring charges during 2014 in connection with the 2014 Plan include restructuring related asset charges of $135 million, termination (severance) benefits of $114 million and other restructuring charges of $24 million. Other restructuring charges include contract termination costs, relocation and other associated costs.
 
The impairments recognized in connection with the 2014 Plan primarily pertain to operations in our MENA region, where geopolitical issues and recent disruptions in North Africa, primarily Libya, resulted in the decisions in the third quarter of 2014 to exit certain businesses in selected markets. The 2014 Plan activities resulted in $106 million of cash payments in 2014.

As of December 31, 2015, we completed our planned headcount reductions and closures of underperforming operating locations in connection with the 2014 and 2015 Plans. The following tables present the components of the restructuring charges by segment and plan for the years ended December 31, 2015 and 2014.
 
Year Ended December 31, 2015
 
 
Other
Total
(Dollars in millions)
Severance
Restructuring
Severance and
2015 Plan
Charges
Charges
Other Charges
North America
$
28

$
24

$
52

MENA/Asia Pacific
21

35

56

Europe/SSA/Russia
34

22

56

Latin America
38

2

40

Subtotal
121

83

204

Land Drilling Rigs
12


12

Corporate and Research and Development
16


16

Total
$
149

$
83

$
232



32


 
Year Ended December 31, 2014
 
 
Other
Total
 
Severance
Restructuring
Severance and
(Dollars in millions)
Charges
Charges
Other Charges
2014 Plan:
North America
$
17

$
27

$
44

MENA/Asia Pacific
19

106

125

Europe/SSA/Russia
17

13

30

Latin America
29

7

36

Subtotal
82

153

235

Land Drilling Rigs
5

4

9

Corporate and Research and Development
27

2

29

2014 Plan Total
$
114

$
159

$
273

2015 Plan:
North America
$
32

$

32

MENA/Asia Pacific
8


8

Europe/SSA/Russia
5


5

Latin America
12


12

Subtotal
57


57

Land Drilling Rigs



Corporate and Research and Development
1


1

2015 Plan Total
$
58

$

$
58

Total
$
172

$
159

$
331


Liquidity and Capital Resources

Cash Flows

At December 31, 2015, we had cash and cash equivalents of $467 million compared to $474 million at December 31, 2014 and $435 million at December 31, 2013. At December 31, 2015, cash and cash equivalents reflected a negative impact of $43 million related to the revaluation of cash balances held in the Venezuelan bolivar, Angolan kwanza, Argentine peso and the Kazakhstani tenge. At December 31, 2014, cash and cash equivalents reflected a $92 million charge due to the devaluation of the Venezuelan bolivar related to our decision to adopt the SICAD II exchange rate. The following table summarizes cash provided by (used in) each type of business activity, for the years ended December 31, 2015, 2014 and 2013:
 
Year Ended December 31,
(Dollars in millions)
2015
 
2014
 
2013
Net Cash Provided by Operating Activities
$
706

 
$
963

 
$
1,229

Net Cash Provided by (Used in) Investing Activities
(659
)
 
330

 
(1,104
)
Net Cash Provided by (Used in) Financing Activities
12

 
(1,180
)
 
6


Operating Activities

Cash flows provided by operating activities were $706 million in 2015 compared to $963 million during 2014. The decrease in operating cash flow is primarily due to the reduction in income associated with the significant decline in drilling activity resulting from the significant decline in commodity prices and the net payment of $105 million related to the Freedman litigation.

Cash flows provided by operating activities was $963 million in 2014 compared to $1.2 billion in 2013. The cash provided by our operating activities in 2014 is a result of our positive operating results excluding the non-cash impact of $656 million in long-lived assets and goodwill impairment, the $245 million Venezuelan bolivar devaluation charge and $112 million of Land Drilling Rig business related write-down and reserve charges. The significant uses of operating cash in 2014 included over $340 million of completion and end of contract payments associated with our legacy percentage-of-completion contracts in Iraq and

33


the payment of $253 million to settle the United Nations oil-for-food program governing sales of goods into Iraq and FCPA matters.

Cash flows provided by operating activities in 2013 were attributable to our positive operating income and improved net working capital operating cash flows of $186 million. Our net loss decreased by $436 million for 2013 compared to the net loss in 2012, primarily due to the non-cash charges related to the impairment of goodwill and equity investment which occurred in 2012 that did not recur in 2013.

Investing Activities

In 2015, our investing activities used cash of $659 million versus providing cash of $330 million in 2014 and used cash of $1.1 billion in 2013. Cash used in 2015 was primarily for capital expenditures for property, plant and equipment and was $682 million in 2015 compared to $1.45 billion in 2014. The amount we spend for capital expenditures varies each year based on the nature of our contracts, asset availability and our expectations with respect to industry activity levels in the following year. The significant reduction in capital expenditures is responsive to the severe downturn in the industry resulting from the decline in commodity prices and customer spending.

Investing activities in 2014 provided cash of $330 million primarily due to $1.8 billion in cash proceeds from the sale of businesses in 2014. Dispositions in 2014 included our land drilling and workover rig operations in Russia and Venezuela, pipeline and specialty services business, engineered chemistry and Integrity drilling fluids businesses and the disposal of all our shares in Proserv. In 2014, we also received net cash of $18 million from consolidation following the purchase of additional ownership interest in a joint venture in China. See “Note 2 – Business Combinations and Divestitures” for additional information regarding these transactions. While we expect to continue to make business acquisitions when strategically advantageous, our current focus is on disposition of businesses or capital assets that are no longer core to our long-term strategy.

In 2013, cash used in investing activities totaled $1.1 billion primarily for capital expenditures of $1.6 billion, partially offset by $488 million of cash proceeds from dispositions primarily from the sale of our 38.5% equity interest in Borets and our industrial screen business. Cash used for acquisitions of businesses and intellectual property in 2013 totaled $17 million.

Financing Activities

Our 2015 financing activities primarily consisted of the borrowing and repayment of short-term and long-term debt. Our short-term borrowings, net of repayments, were $505 million and total net long-term repayments were $470 million. In 2015, through a series of open market transactions, we repurchased certain of our senior notes with a total book value of $527 million. We recognized a cumulative gain of $84 million on these transactions in the line captioned “Other, Net” on the accompanying Consolidated Statements of Operations. See “Note 12 – Short-term Borrowings and Current Portion of Long-term Debt” and “Note 13 – Long-term Debt” for additional details of our financing activities. Our other financing activities in 2015 included dividends paid to noncontrolling partners in consolidated joint ventures of $49 million and proceeds from the exercise of stock options issued to our employees and directors of $26 million.

Our 2014 financing activities primarily consisted of repayment and repurchase of approximately $924 million of short-term debt and $259 million of long-term debt, including the repurchase of senior notes. In December 2014, through a series of open market transactions, we repurchased certain of our senior notes with a total book value of $138 million and recognized a gain of approximately $11 million.

In conjunction with our 2014 redomestication, we amended our Executive Deferred Compensation Stock Ownership Plan to provide that benefits thereunder may be payable in cash in lieu of our shares. The trustee for our executive deferred compensation plan, a consolidated subsidiary, sold 973,611 shares of our common stock realizing $22 million in cash proceeds for the benefit of the plan participants. Our other financing activities in 2014 included dividends paid to noncontrolling partners in consolidated joint ventures of $39 million and proceeds from the exercise of stock options issued to our employees and directors of $11 million.

Our 2013 financing activities primarily consisted of short-term borrowings of $612 million and long-term debt repayments of $603 million, which included the repayment of our senior notes of $544 million. Our other financing activities in 2013 included dividends paid to noncontrolling partners in consolidated joint ventures of $27 million and proceeds from the exercise of stock options issued to our employees and directors of $22 million.


34


Sources of Liquidity

Our sources of available liquidity include cash and cash equivalent balances, cash generated from operations, dispositions, and availability under committed lines of credit. We also historically have accessed banks for short-term loans from uncommitted borrowing arrangements and have accessed the capital markets with debt and equity offerings. From time to time we may and have entered into transactions to factor accounts receivable or to dispose of businesses or capital assets that are no longer core to our long-term strategy.

Through our sales of assets and businesses in 2014 we realized $1.8 billion in sale proceeds, net of cash on the balance sheets of businesses sold. These proceeds contributed to the early repayment or repurchase of portions of our short-term and long-term debt in 2014 and 2015.

Revolving Credit Facility

At December 31, 2015, we had a $2.25 billion unsecured, revolving credit agreement (the “Credit Agreement”) that matures on July 13, 2017. The Credit Agreement can be used for a combination of borrowings, including support for our former commercial paper program and issuances of letters of credit. This agreement required that we maintain a debt-to-total capitalization ratio of less than 60%, and we were in compliance with this covenant at December 31, 2015 with a ratio of 55.6%, which is calculated as total consolidated indebtedness, net of derivative positions of $9 million, divided by total capitalization, including non-controlling interest balances and excluding $1.6 billion of foreign currency translation adjustments. At December 31, 2015, we had $1.3 billion available under the Credit Agreement. There were $16 million in outstanding letters of credit in addition to borrowings under the Credit Agreement. On February 1, 2016, we amended our Credit Agreement and reduced the limit of borrowings to $2 billion. The amended Credit Agreement requires that we maintain a debt-to-total capitalization ratio of less than 70% for the quarters ending March 31 and June 30, 2016, and less than 60% thereafter. In addition, we intend to renegotiate our Credit Agreement to extend the maturity date.

The following summarizes our availability under the Credit Agreement at December 31, 2015 (dollars in millions):
Facility
$
2,250

Less uses of facility:
 

Revolving credit facility
967

Letters of credit
16

Availability
$
1,267


Other Short-Term Borrowings and Other Debt Activity

We have short-term borrowings with various domestic and international institutions pursuant to uncommitted facilities. At December 31, 2015, we had $214 million in short-term borrowings under these arrangements with a weighted average interest rate of 2.0%, including $180 million borrowed under a credit agreement entered into in March 2014 that matures on March 20, 2016 (with respect to $150 million) and June 20, 2016 (with respect to the remaining $30 million), with a LIBOR-based interest rate of 1.95% as of December 31, 2015. On April 9, 2015, the maturity date, we repaid the remaining balance of $175 million on our $400 million, 364-day term loan facility.

Ratings Services’ Credit Ratings

Our Standard & Poor’s Rating Services’ credit rating on our senior unsecured debt is currently BB+, and our short-term rating is B. On November 3, 2015, S&P lowered our credit rating to the current BB+ from BBB- and changed our outlook from negative to stable. Our Moody’s Investors Ratings Services’ credit rating on our unsecured debt is currently Ba1, and our short-term rating is SGL-2. On October 27, 2015, Moody Investors lowered our credit rating to the current Ba1 from Baa3 and changed our outlook from negative to stable. However, on January 21, 2016, Moody’s placed the company’s rating on review for downgrade. On April 15, 2015, Fitch Rating assigned a credit rating on our senior unsecured debt of BBB- and our short-term rating of F3, with a negative outlook. On January 25, 2016, Fitch Ratings lowered its credit rating on our senior unsecured debt to BB from BBB- and lowered our short-term rating to B from F3 and maintained its negative outlook. We have access and expect we will continue to have access to most credit markets.


35


Cash Requirements
During 2016, we anticipate our cash requirements will include payments for capital expenditures, repayment of debt, interest payments on our outstanding debt, severance and payments for short-term working capital needs. Our cash requirements may also include opportunistic debt repurchases, business acquisitions and amounts to settle litigation related matters described in “Item 1A. – Risk Factors” and “Item 8. – Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 21 – Disputes, Litigation and Contingencies.” We anticipate funding these requirements from cash generated from operations, availability under our existing or additional credit facilities, and if completed, proceeds from disposals of businesses or capital assets. We anticipate that cash generated from operations will be augmented by working capital improvements driven by capital discipline including further inventory reductions. Capital expenditures for 2016 are projected to be approximately $300 million, which will be 56% lower than capital expenditures of $682 million in 2015. The amounts we ultimately spend will depend on a number of factors including the type of contracts we enter into, asset availability and our expectations with respect to industry activity levels in 2016. Expenditures are expected to be used primarily to supporting ongoing activities of our core businesses and our sources of liquidity are anticipated to be sufficient to meet our needs.

Cash and cash equivalent of $467 million at December 31, 2015, are held by subsidiaries outside of Ireland.  Based on the nature of our structure, we are generally able to redeploy cash with no incremental tax. However, in 2015 we recorded a $179 million tax charge to cover future planned distributions of subsidiary earnings to the U.S.

As of December 31, 2015, $149 million of our cash and cash equivalent balance was denominated in Angolan kwanza. The National Bank of Angola supervises all kwanza exchange operations and had limited U.S. Dollar conversions during 2015, causing our kwanza cash balance to increase throughout the year. Prolonged Angolan exchange limitations may limit our ability to repatriate earnings and expose us to additional exchange rate risk.

Accounts Receivable Factoring

From time to time we participate in factoring arrangements to sell accounts receivable to third party financial institutions. In 2015, under these arrangements we sold $78 million, received cash totaling of $77 million and recognized a loss of $0.2 million. We did not sell any accounts receivable in 2014. In 2013, under these arrangements we sold $215 million, received cash totaling $204 million and recognized a loss of $3 million. Our factoring transactions in 2015 and 2013 qualified for sale accounting under U.S. Generally Accepted Accounting Principles (“GAAP”) and all related proceeds are included in operating cash flows in our Consolidated Statements of Cash Flows.

Contractual Obligations

The following summarizes our contractual obligations and contingent commitments by period. The obligations we pay in future periods may vary due to certain assumptions including the duration of our obligations and anticipated actions by third parties.
 
Payments Due by Period
(Dollars in millions)
2016
 
2017 and 2018
 
2019 and 2020
 
Thereafter
 
Total
Short-term Debt
$
1,181

 
$

 
$

 
$

 
$
1,181

Long-term Debt (a)
392

 
1,132

 
1,821

 
2,939

 
6,284

Interest on Long-term Debt
401

 
712

 
433

 
2,931

 
4,477

Noncancellable Operating Leases
349

 
382

 
164

 
277

 
1,172

Purchase Obligations
202

 
119

 
55

 
6

 
382

 
$
2,525

 
$
2,345

 
$
2,473

 
$
6,153

 
$
13,496

(a)
Amounts represent the expected cash payments of principal associated with our long-term debt. These amounts do not include the unamortized discounts or deferred gains on terminated interest rate swap agreements.

Due to the uncertainty with respect to the timing of future cash flows associated with our uncertain tax positions, we are unable to make reasonably reliable estimates of the period of cash settlement, if any, to the respective taxing authorities. Therefore, $245 million in uncertain tax positions, including interest and penalties, have been excluded from the contractual obligations table above.

We have defined benefit pension and other post-retirement benefit plans covering certain of our U.S. and international employees. During 2015, we contributed approximately $6 million towards those plans and we anticipate funding approximately

36


$5 million during 2016. Our projected benefit obligations for our defined benefit pension and other post-retirement benefit plans were $245 million as of December 31, 2015.

Derivative Instruments

Fair Value Hedges

We may use interest rate swaps to help mitigate exposures related to changes in the fair values of fixed-rate debt. As of December 31, 2015 and 2014, we had net unamortized premiums of $23 million and $33 million, respectively, associated with fair value hedge swap terminations. These premiums are being amortized over the remaining term of the originally hedged debt as a reduction to interest expense. See “Note 15 – Derivative Instruments” to our Consolidated Financial Statements for additional details.

Cash Flow Hedges

We may use interest rate derivatives to mitigate our exposure to variability in forecasted cash flows due to changes in interest rates. In 2008, we entered into interest rate derivative instruments to hedge projected exposures to interest rates in anticipation of a debt offering. These hedges were terminated at the time of the issuance of the debt, and the associated loss is being amortized from Accumulated Other Comprehensive Income (Loss) to interest expense over the remaining term of the debt. As of December 31, 2015 and 2014, we had net unamortized losses of $10 million and $11 million, respectively, associated with our cash flow hedge terminations.

Other Derivative Instruments

We enter into contracts to hedge our exposure to currency fluctuations in various foreign currencies. As of December 31, 2015 and 2014, we had outstanding foreign currency forward contracts with total notional amounts totaling $1.7 billion and $1.6 billion, respectively. The notional amounts of our foreign currency forward contracts do not generally represent amounts exchanged by the parties and thus are not a measure of the cash requirements related to these contracts or of any possible loss exposure. The amounts actually exchanged at maturity are calculated by reference to the notional amounts and by other terms of the derivative contracts, such as exchange rates. See “Note 15 – Derivative Instruments” for additional information.

Our foreign currency forward contracts and cross-currency swaps are not designated as hedges, and the changes in fair value of the contracts are recorded in current earnings each period in the line captioned “Other, Net” on the accompanying Consolidated Statements of Operations. See “Note 15 – Derivative Instruments” for additional information.

Off Balance Sheet Arrangements

Guarantees

Weatherford Ireland guarantees the obligations of our subsidiaries Weatherford International Ltd. (“Weatherford Bermuda”) and Weatherford International, LLC (“Weatherford Delaware”), including the notes and credit facilities listed below.

The following obligations of Weatherford Delaware were guaranteed by Weatherford Bermuda at December 31, 2015, 2014 and 2013: (1) 6.35% senior notes and (2) 6.80% senior notes.
 
The following obligations of Weatherford Bermuda were guaranteed by Weatherford Delaware at December 31, 2015, 2014 and 2013: (1) revolving credit facility, (2) 5.50% senior notes, (3) 6.50% senior notes, (4) 6.00% senior notes, (5) 7.00% senior notes, (6) 9.625% senior notes, (7) 9.875% senior notes, (8) 5.125% senior notes, (9) 6.75% senior notes, (10) 4.50% senior notes and (11) 5.95% senior notes. Our 364-day term loan facility was an obligation of Weatherford Bermuda guaranteed by Weatherford Delaware as of December 31, 2013. In 2014, we refinanced the 364-day term loan facility with a new 364-day term loan facility, which was an obligation of Weatherford Bermuda, was guaranteed by Weatherford Delaware as of December 31, 2014 and was repaid in 2015.

As a result of certain of these guarantee arrangements, we are required to present condensed consolidating financial information. See guarantor financial information presented in “Note 24 – Consolidating Financial Statements.”


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Letters of Credit and Performance and Bid Bonds

We use letters of credit and performance and bid bonds in the normal course of our business. As of December 31, 2015, we had $791 million of letters of credit and performance and bid bonds outstanding, consisting of $626 million outstanding under various uncommitted credit facilities, $16 million of letters of credit outstanding under our Credit Agreement and $149 million of surety bonds, primarily performance bonds, issued by financial sureties against an indemnification from us. These obligations could be called by the beneficiaries should we breach certain contractual or performance obligations. If the beneficiaries were to call the letters of credit under our committed facility, our available liquidity would be reduced by the amount called.

Critical Accounting Policies and Estimates

Our discussion and analysis of our financial condition and results of operation is based upon our Consolidated Financial Statements. We prepare these financial statements in conformity with U.S. GAAP. As such, we are required to make certain estimates, judgments and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the periods presented. We base our estimates on historical experience, available information and various other assumptions we believe to be reasonable under the circumstances. On an on-going basis, we evaluate our estimates; however, actual results may differ from these estimates under different assumptions or conditions. The accounting policies we believe require management’s most difficult, subjective or complex judgments and are the most critical to our reporting of results of operations and financial position are as follows:

Business Combinations and Goodwill

Goodwill represents the excess of consideration paid over the fair value of net tangible and identifiable intangible assets acquired, and liabilities assumed in a business combination. Goodwill is allocated to Weatherford’s reporting units when initially acquired. Reporting units are operating segments or one level below the operating segment level. Our reporting units are based on our regions and include the United States, Canada, Latin America, Europe, SSA, Russia, MENA, Asia Pacific and Land Drilling Rigs. Land Drilling Rigs was separated into its own reportable segment and reporting unit in the first quarter of 2015 in order to align our business structure with management’s current view and future growth objectives.

Goodwill is not amortized but is evaluated for impairment. We perform an impairment test for goodwill annually as of October 1 or more frequently if indicators of potential impairment exist that would more-likely-than-not reduce the fair value of the reporting unit below its carrying value. We have the option to assess qualitative factors to determine if it is necessary to perform further goodwill impairment tests. If it is more-likely-than-not that the fair value of a reporting unit is less than its carrying value, we must perform the first step of the goodwill impairment test. We also have the option to bypass the qualitative assessment at any time and perform the first step. Goodwill impairment is evaluated using a two-step process. The first step of the goodwill impairment test involves a comparison of the fair value of each of our reporting units with their carrying values.

The fair value of our reporting units is determined using a combination of the income approach and the market approach. The income approach estimates fair value by discounting each reporting unit’s estimated future cash flows. The income approach requires us to make certain estimates and judgments. To arrive at our future cash flows, we use estimates of economic and market information, including growth rates in revenues and costs, working capital and capital expenditure requirements, and operating margins and tax rates. Several of the assumptions used in our discounted cash flow analysis are based upon our annual financial forecast. Our annual planning process takes into consideration many factors including historical results and operating performance, related industry trends, pricing strategies, customer analysis, operational issues, competitor analysis, and marketplace data, among others. Assumptions are also made for periods beyond the financial forecast period. The discount rate used in the income approach is determined using a weighted average cost of capital and reflects the risks and uncertainties in the cash flow estimates. The weighted average cost of capital includes a cost of debt and equity. The cost of equity is estimated using the capital asset pricing model, which includes inputs for a long-term risk-free rate, equity risk premium, country risk premium, and an asset beta appropriate for the assets in the reporting unit. The discount rates for our reporting units ranged from 10.50% to 17.25% as of our October 1, 2015 annual impairment test. The market approach estimates fair value using as a multiple of each reporting unit’s actual and forecasted earnings using earnings multiples of comparable publicly traded companies.

We used an independent valuation specialist in each of our annual impairment tests to assist us in our valuations under both methods. The final estimate of each reporting unit’s fair value is determined by using an appropriate weighting of the values from each method, where the income method was weighted heavier than the market method as we believe that the income method and assumptions therein are more reflective of a market participant’s view of fair value given current market conditions.


38


The fair values estimated using the income approach and the market approach cannot be directly compared to our market capitalization due to several factors, most importantly the premium that would be paid by a market participant to acquire a controlling interest in Weatherford, which is not reflected in the price of our publicly traded stock. The sum of the fair values of Weatherford’s reporting units’ implied a control premium of approximately 28% as of our October 1, 2015 testing date, which is consistent with observable control premiums in market transactions.

The fair values of all of our reporting units that have goodwill were in excess of their carrying value as of our October 1, 2015 annual impairment test. Considering declining oil prices and revisions to our forecasts during the fourth quarter 2015, we re-performed the first step of the goodwill impairment test as of December 31, 2015, and the fair values of all of our reporting units continued to exceed their carrying values as of that date.

Our estimates of fair value are sensitive to the aforementioned inputs to the valuation approaches. If any one of the above inputs changes, it could reduce the estimated fair value of the affected reporting unit and result in an impairment charge to goodwill. Some of the inputs, such as forecasts of revenue and earnings growth, are subject to change given their uncertainty. Other inputs, such as the discount rate used in the income approach and the valuation multiple used in the market approach, are subject to change as they are outside of our control. In the event that discount rates increased by more than 100 basis points for our United States reporting unit as of October 1, 2015, all else being equal, we expect that the resulting fair value would still exceed our reporting unit’s carrying value.

If the carrying value of a reporting unit’s goodwill exceeds its fair value, the second step of the goodwill impairment test shall be performed. The second step compares the implied fair value of the reporting unit’s goodwill to the carrying value of its goodwill. The implied fair value of goodwill is determined by performing a hypothetical purchase price allocation of the reporting unit’s assets and liabilities using the fair value of the reporting unit as the purchase price in the calculation. If the amount of goodwill resulting from this hypothetical purchase price allocation is less than the carrying value of a reporting unit’s goodwill, the recorded carrying value of goodwill is written down to the implied fair value.

Based on the results of our impairment tests, we recognized goodwill impairments of $161 million in 2014. We did not recognize a goodwill impairment charge in 2015.

In 2014, our annual goodwill impairment test indicated that the goodwill of the Land Drilling Rigs reporting units in Latin America, Europe and Asia Pacific was impaired. The results of our “step-one” analysis were accompanied by other indicators in the form of a decline in the anticipated utilization rates for our drilling rig fleet. Responsive to the impairment indicators noted, we performed a “step two” analysis, comparing the implied fair value of reporting units’ goodwill with the carrying value of their goodwill. The “step two” analysis indicated that the goodwill for these reporting units was fully impaired and we recognized an impairment loss of $40 million related to Land Drilling Rigs segment in Latin America, Europe and Asia Pacific.

In addition, during the second quarter of 2014, we engaged in negotiation to sell our land drilling and workover operations in Russia and Venezuela and we subsequently entered into an agreement to sell the businesses in July 2014. During this time frame we expected the sale would significantly impact the revenues and results of operations of our Russia reporting unit. Consequently, we considered the associated circumstances to assess whether an event or change had occurred that, more likely than not, reduced the fair value of our reporting units below their carrying amount. We concluded that the planned sale represented an indicator of impairment and we prepared the analysis necessary to identify the potential impairment and recognized the required impairment loss. The analysis indicated that the goodwill for the Russia reporting unit was impaired, and we recognized a goodwill impairment loss of $121 million, $95 million of which pertained to goodwill classified in current assets held for sale.

For further analysis and discussion of goodwill refer to “Item 8. – Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 9 – Goodwill” of this Form 10-K.


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Long-Lived Assets
 
Long-lived assets, which include property, plant and equipment and definite-lived intangibles, comprise a significant amount of our assets. We must make estimates about the expected useful lives of the assets. The value of the long-lived assets is then amortized over its expected useful life. A change in the estimated useful lives of our long-lived assets would have an impact on our results of operations. We estimate the useful lives of our long-lived asset groups as follows:
 
Estimated Useful Lives
Buildings and leasehold improvements
10 – 40 years or lease term
Rental and service equipment
2 – 20 years
Machinery and other
2 – 12 years
Intangible assets
2 – 20 years

In estimating the useful lives of our property, plant and equipment, we rely primarily on our actual experience with the same or similar assets. The useful lives of our intangible assets are determined by the years over which we expect the assets to generate a benefit based on legal, contractual or regulatory terms.
 
Long-lived assets to be held and used by us are reviewed to determine whether any events or changes in circumstances indicate that we may not be able to recover the carrying amount of the asset. Factors that might indicate a long-lived asset may not be recoverable may include, but are not limited to, significant decreases in the market value of the long-lived asset, a significant change in the long-lived asset’s physical condition, the introduction of competing technologies, legal challenges, a reduction in the utilization rate of the assets, a change in industry conditions, or a reduction in cash flows driven by pricing pressure as a result of oversupply associated with the use of the long-lived asset. If these or other factors exist that indicate the carrying amount of the asset may not be recoverable, we determine whether an impairment has occurred through the use of an undiscounted cash flow analysis. The undiscounted cash flow analysis consists of estimating the future cash flows that are directly associated with, and are expected to arise from, the use and eventual disposition of the asset over its remaining useful life. These cash flows are inherently subjective and require estimates based upon historical experience and future expectations. If the undiscounted cash flows do not exceed the carrying value of the long-lived asset, the asset is not recoverable and impairment is recognized to the extent the carrying amount exceeds the estimated fair value of the asset. The fair value of the asset is measured using market prices, or in the absence of market prices, is based on an estimate of discounted cash flows. Cash flows are discounted at an interest rate commensurate with our weighted average cost of capital for a similar asset.

Assets are grouped at the lowest level at which cash flows are identifiable and independent. We generally group operating assets by product line of the respective region. We have long-lived assets, such as facilities, utilized by multiple operating divisions that do not have identifiable cash flows and impairment testing for these long-lived assets is based on the consolidated entity.

A significant decline in crude oil prices contributed to lower anticipated exploration and production spending and a decline in the anticipated utilization rates for our assets. The decline and its impact on demand represent a significant adverse change in the business climate and an indication that some of our long-lived assets may not be recoverable. Based on the impairment indicators noted we performed an analysis of our long-lived assets in 2014 and 2015 and recorded long-lived and other asset impairment charges to adjust to fair value. See “Note 8 – Long-lived Asset Impairments” for additional information regarding the long-lived assets impairment.

We recognized total long-lived asset impairment charges of $638 million in 2015 with $383 million related to pressure pumping, drilling tools and wireline assets in North America segment and $255 million related to Land Drilling Rigs segment assets. In 2014 we recognized total long-lived and other asset impairments of $495 million, of which $352 million related to our Land Drilling Rig business and $143 million related to the sale of our land drilling and workover operations in Russia and Venezuela.

Management cannot predict the occurrence of future impairment-triggering events, so we continue to assess whether indicators of impairment to long-lived assets exist due to the current business conditions in the oilfield services industry.


40


Percentage-of-Completion Revenue Recognition

Revenue from long-term contracts, primarily for our integrated project management services, is reported on the percentage-of-completion method of accounting. This method of accounting requires us to calculate contract profit to be recognized in each reporting period for each contract based upon our projections of future outcomes, which include:
 
estimates of the available revenue under the contracts;
estimates of the total cost to complete the project;
estimates of project schedule and completion date;
estimates of the extent of progress toward completion; and
amounts of any change orders or claims included in revenue.

Measurements of progress are generally based on costs incurred to date as a percentage of total estimated costs or output related to physical progress. At the outset of each contract, we prepare a detailed analysis of our estimated cost to complete the project. Risks related to service delivery, usage, productivity and other factors are considered in the estimation process. Our personnel periodically evaluate the estimated costs, claims, change orders and percentage-of-completion at the contract level. The recording of profits and losses on long-term contracts requires an estimate of the total profit or loss over the life of each contract. This estimate requires consideration of total contract value, change orders and claims, less costs incurred and estimated costs to complete. Anticipated losses on contracts are recorded in full in the period in which they become evident. Profits are recorded based upon the total estimated contract profit multiplied by the current estimated percentage complete for the contract. There are many factors that impact future costs, including but not limited to weather, inflation, client activity levels and budgeting constraints, labor and community disruptions, timely availability of materials, productivity and other factors as outlined in our “Item 1A. – Risk Factors.”

During 2015, we recognized estimated project losses of $153 million related to our long-term early production facility construction contracts in Iraq accounted for under the percentage-of-completion method. Total estimated losses on these loss projects were $532 million at December 31, 2015. As of December 31, 2015, our percentage-of-completion project estimates include $116 million of claims revenue and $28 million of back charges. During 2015, an additional $32 million of claims revenue was included in our project estimates. Our costs in excess of billings as of December 31, 2015 were $6 million and are shown in the “Other Current Assets” line on our Consolidated Balance Sheets. We also have a variety of unapproved contract change orders or claims that are not included in our revenues as of December 31, 2015. The amounts associated with these contract change orders or claims are included in revenue only when they can be reliably estimated and their realization is reasonably assured.

During 2014, we recognized estimated project losses of $72 million related to our long-term early production facility construction contracts in Iraq accounted for under the percentage-of-completion method. Total estimated losses on these projects were $379 million at December 31, 2014. As of December 31, 2014, our percentage-of-completion project estimates include $90 million of claims revenue and $24 million of back charges. Our costs in excess of billings as of December 31, 2014 were $128 million and are shown in the “Other Current Assets” line on the balance sheet. We had a variety of unapproved contract change orders or claims that were not included in our revenues as of December 31, 2014. During 2014, an additional $80 million of claims revenue was included in our project estimates and $26 million of our prior claims were approved.

During 2013, we recognized estimated project losses of $232 million related to our long-term early production facility construction contracts in Iraq accounted for under the percentage-of-completion method. The total estimated losses on these projects were $307 million at December 31, 2013. As of December 31, 2013, our percentage-of-completion project estimates include $36 million of claims revenue and $82 million for liquidated damages that we are contractually obligated to pay as a result of delays in the expected completion of the project. We had a variety of unapproved contract change orders or claims that were not included in our revenues as of December 31, 2013.

 Although we have not yet met the recognition criteria for revenue recognition, we expect to vigorously pursue collection of the claims and reduction or elimination of the liquidated damages. Any benefits resulting from those efforts will be recognized when the criteria for the revenue recognition are met.


41


Income Taxes
 
We take into account the differences between the financial statement treatment and tax treatment of certain transactions. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates is recognized as income or expense in the period that includes the enactment date. Our income tax benefit in 2015 was $145 million compared to an income tax provision of $284 million in 2014 and $144 million in 2013, respectively, which resulted in an effective tax rate of 7%, (111)% and (85)%, respectively.
 
We recognize the impact of an uncertain tax position taken or expected to be taken on an income tax return in the financial statements at the largest amount that is more likely than not to be sustained upon examination by the relevant taxing authority.

We operate in over 100 countries through hundreds of legal entities. As a result, we are subject to numerous tax laws in the jurisdictions, and tax agreements and treaties among the various taxing authorities. Our operations in these jurisdictions in which we operate are taxed on various bases: income before taxes, deemed profits (which is generally determined using a percentage of revenues rather than profits), withholding taxes based on revenue, and other alternative minimum taxes. The calculation of our tax liabilities involves consideration of uncertainties in the application and interpretation of complex tax regulations in a multitude of jurisdictions across our global operations. We recognize potential liabilities and record tax liabilities for anticipated tax audit issues in the tax jurisdictions based on our estimate of whether, and the extent to which, additional taxes will be due. As of December 31, 2015, we had recorded reserves for uncertain tax positions of $195 million, excluding accrued interest and penalties of $50 million. The tax liabilities are reflected net of realized tax loss carryforwards. We adjust these reserves upon specific events; however, due to the complexity of some of these uncertainties, the ultimate resolution may result in a payment that is different from our current estimate of the tax liabilities.

If our estimate of tax liabilities proves to be less than the ultimate assessment, an additional charge to expense would result. If payment of these amounts ultimately proves to be less than the recorded amounts, the reversal of the liabilities would result in tax benefits being recognized in the period when the contingency has been resolved and the liabilities are no longer necessary. Changes in tax laws, regulations, agreements and treaties, foreign currency exchange restrictions or our level of operations or profitability in each taxing jurisdiction could have an impact upon the amount of income taxes that we provide during any given year.
 
Valuation Allowance for Deferred Tax Assets
 
We record a valuation allowance to reduce the carrying value of our deferred tax assets when it is more likely than not that a portion or all of the deferred tax assets will expire before realization of the benefit. The ultimate realization of the deferred tax assets depends on the ability to generate sufficient taxable income of the appropriate character and in the related jurisdiction in the future. In evaluating our ability to recover our deferred tax assets, we consider the available positive and negative evidence, including our past operating results, the existence of cumulative losses in the most recent years and our forecast of future taxable income. In estimating future taxable income, we develop assumptions, including the amount of future pre-tax operating income, the reversal of temporary differences and the implementation of feasible and prudent tax planning strategies. These assumptions require significant judgment.

We have considered various tax planning strategies that we would implement, if necessary, to enable the realization of our deferred tax assets; however, when the likelihood of the realization of existing deferred tax assets changes, adjustments to the valuation allowance are charged to our income tax provision in the period in which the determination is made.

As of December 31, 2015, our gross deferred tax assets were $1.6 billion before a related valuation allowance of $868 million. As of December 31, 2014, our gross deferred tax assets were $1.2 billion before a related valuation allowance of $732 million. The gross deferred tax assets were also offset by gross deferred tax liabilities of $474 million and $573 million as of December 31, 2015 and 2014, respectively.


42


Allowance for Doubtful Accounts

We maintain an allowance for doubtful accounts in order to record accounts receivable at their net realizable value. Significant judgment is involved in recognizing this allowance. The determination of the collectability requires us to use estimates and make judgments regarding future events and trends, including monitoring our customers’ payment history and current creditworthiness to determine that collectability is reasonably assured, as well as consideration of the overall business and political climate in which our customers operate. Provisions for doubtful accounts are recorded when it becomes evident that customer accounts are uncollectible. At December 31, 2015 and 2014, the allowance for doubtful accounts totaled $113 million, or 6%, and $108 million, or 3%, of total gross accounts receivable, respectively. In 2015, we recognized a charge for bad debt expense of $48 million attributable to our reporting segments. We believe that our allowance for doubtful accounts is adequate to cover potential bad debt losses under current conditions. However, uncertainties regarding changes in the financial condition of our customers, either adverse or positive, could impact the amount and timing of any additional provisions for doubtful accounts that may be required. A 5% change in the allowance for doubtful accounts would have had an impact on income before income taxes of approximately $6 million in 2015.

Inventory Reserves

Inventory represents a significant component of current assets and is stated at the lower of cost or market using either a first-in, first-out (“FIFO”) or average cost method. To maintain a book value that is the lower of cost or market, we maintain reserves for excess, slow moving and obsolete inventory. To determine these reserve amounts, we review inventory quantities on hand, future product demand, market conditions, production requirements and technological obsolesce. This review requires us to make judgments regarding potential future outcomes. At December 31, 2015 and 2014, inventory reserves totaled $288 million, or 11%, and $147 million, or 5%, of gross inventory, respectively. During 2015, we recognized a charge of $186 million for excess and obsolete inventory attributable to our reporting segments. We believe that our reserves are adequate to properly value potential excess, slow-moving and obsolete inventory under current conditions.
 
During 2014, we recognized a charge of $21 million for excess and obsolete inventory associated with rigs reporting units with the remaining charge attributable to our regional excess and obsolete inventory review. During 2013, we recognized a charge for excess and obsolete inventory of $62 million attributable to our reporting segments.

Disputes, Litigation and Contingencies

As of December 31, 2015, we have accrued an estimate of the probable and estimable cost to resolve certain legal and investigation matters. For matters not deemed probable and reasonably estimable, we have not accrued any amounts in accordance with U.S. GAAP. Our legal department manages all pending or threatened claims and investigations on our behalf. The estimate of the probable costs related to these matters is developed in consultation with internal and outside legal counsel. Our contingent loss estimates are based upon an analysis of potential results, assuming a combination of probable litigation and settlement strategies. The accuracy of these estimates is impacted by the complexity of the issues. Whenever possible, we attempt to resolve these matters through settlements, mediation and arbitration proceedings if advantageous to us. If the actual settlement costs, final judgments or fines differ from our estimates, our future financial results may be adversely affected. For a more comprehensive discussion of our Disputes, Litigation and Contingencies, see “Item 8. – Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 21 – Disputes, Litigation and Contingencies.”

New Accounting Pronouncements

See “Note 1 – Summary of Significant Accounting Policies” to our Consolidated Financial Statements for additional information.


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Item 7A. Quantitative and Qualitative Disclosures about Market Risk

We are currently exposed to market risk from changes in foreign currency and changes in interest rates. From time to time, we may enter into derivative financial instrument transactions to manage or reduce our market risk. A discussion of our market risk exposure in these financial instruments follows.
 
Foreign Currency Exchange Rates and Inflationary Impacts

We operate in virtually every oil and natural gas exploration and production region in the world. In some parts of the world, such as Latin America, the Middle East and Southeast Asia, the currency of our primary economic environment is the U.S. dollar, and we use the U.S. dollar as our functional currency. In other parts of the world, we conduct our business in currencies other than the U.S. dollar, and the functional currency is the applicable local currency.

The currency devaluation and related charges resulting from certain devaluations and depreciation are included in the line captioned “Currency Devaluation and Related Charges” on the accompanying Consolidated Statements of Operations.

In 2015, currency devaluations and related charges were $85 million and reflects the impact of the continued devaluation of the Angolan kwanza of $39 million and Argentine peso of $11 million and the recognized remeasurement charges of $26 million related to the Venezuelan bolivar and Kazakhstani tenge of $9 million. The Angolan kwanza charges reflect currency devaluations of approximately 24% in 2015. After the National Bank of Kazakhstan abandoned its peg of the tenge to the U.S. dollar, the cumulative depreciation of the Kazakhstani tenge was 46% during 2015. The devaluation of the Argentine peso was due to the modifying of currency control restrictions on purchasing foreign currencies by the Argentine Central Bank. The Venezuelan bolivar charge reflects remeasurement charges when we began using the exchange rate published by the Venezuelan currency exchange system known as the “Marginal Currency System” or SIMADI, which opened for trading February 12, 2015, replacing the Venezuela’s SICAD II mechanism. The SIMADI is intended to provide limited access to a free market rate of exchange.

In 2014 and 2013, we recognized charges of $245 million and $100 million respectively, on the devaluation of the Venezuelan bolivar. As of December 31, 2014, we adopted the SICAD II daily auction rate of approximately 50 Venezuelan bolivars per U.S. dollar. This rate was used at December 31, 2014 for the purposes of remeasuring Venezuelan bolivar denominated assets and liabilities (primarily cash, accounts receivables, trade payables and other current liabilities). The 2013 devaluation was due to the Venezuelan government changing the official exchange rate of the bolivar from 4.3 per dollar to 6.3 per dollar for all goods and services.

Potential Highly Inflationary Country

We have noted the concerns raised by the IMF relating to the accuracy of Argentina’s officially reported consumer price index. We are closely monitoring Argentina’s price index. As of December 31, 2015, we had a net monetary asset position denominated in Argentine pesos of $42 million, comprised primarily of accounts receivable and current liabilities. Any future change in the inflation rate in Argentina could cause us to change to a U.S. dollar functional currency, which would result in gains or losses on the Argentine peso denominated assets held by our subsidiaries for subsequent changes in the exchange rate.

Foreign Currency, Forward Contracts and Cross-Currency Swaps

Assets and liabilities of entities for which the functional currency other than the U.S. dollar are translated into U.S. dollars using the exchange rates in effect at the balance sheet date result in translation adjustments that are reflected in Accumulated Other Comprehensive Income (Loss) in the Shareholders’ Equity section on our Consolidated Balance Sheets. We recorded a $789 million and $763 million adjustment to decrease shareholders’ equity for 2015 and 2014, respectively, to reflect the change in the U.S. dollar against various foreign currencies.

As of December 31, 2015 and 2014, we had outstanding foreign currency forward contracts with total notional amounts aggregating $1.7 billion and $1.6 billion, respectively. These contracts were entered into in order to hedge our net monetary exposure to currency fluctuations in various foreign currencies. The total estimated fair value of these contracts and amounts owed associated with closed contracts at December 31, 2015 and 2014, resulted in a net liability of approximately $9 million and $5 million, respectively. These derivative instruments were not designated as hedges, and the changes in fair value of the contracts are recorded each period in current earnings.


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Interest Rates

We are subject to interest rate risk on our long-term fixed-interest rate debt and variable-interest rate borrowings. Variable rate debt exposes us to short-term changes in market interest rates. Fixed rate debt exposes us to changes in market interest rates reflected in the fair value of the debt and to the risk that we may need to refinance maturing debt with new debt at a higher rate. All other things being equal, the fair value of our fixed rate debt will increase or decrease inversely to changes in interest rates.
 
Our senior notes that were outstanding at December 31, 2015 and 2014, and that were subject to interest rate risk consist of the following:
 
December 31,
 
2015
 
2014
(Dollars in millions)
Carrying
Amount
 
Fair
Value
 
Carrying Amount
 
Fair
Value
5.50% Senior Notes due 2016
$
350

 
$
351

 
$
352

 
$
362

6.35% Senior Notes due 2017
604

 
585

 
607

 
643

6.00% Senior Notes due 2018
499

 
463

 
498

 
533

9.625% Senior Notes due 2019
1,014

 
965

 
1,018

 
1,180

5.125% Senior Notes due 2020
771

 
626

 
798

 
793

4.50% Senior Notes due 2022
644

 
484

 
715

 
642

6.50% Senior Notes due 2036
449

 
291

 
556

 
520

6.80% Senior Notes due 2037
257

 
180

 
298

 
286

7.00% Senior Notes due 2038
459

 
347

 
497

 
493

9.875% Senior Notes due 2039
247

 
213

 
247

 
312

6.75% Senior Notes due 2040
460

 
327

 
596

 
562

5.95% Senior Notes due 2042
372

 
263

 
478

 
407

 Total
$
6,126

 
$
5,095

 
$
6,660

 
$
6,733


During 2015, through a series of open market transactions, we repurchased certain of our 4.5% senior notes, 5.125% senior notes, 5.95% senior notes, 6.5% senior notes, 6.75% senior notes, 6.80% senior notes and 7.00% senior notes with a total book value of $527 million. We recognized a cumulative gain of approximately $84 million on these transactions. In December 2014, through a series of open market transactions, we repurchased certain of our 4.5% senior notes, 5.95% senior notes and 6.5% senior notes with a an aggregate book value of $138 million and recognized a gain of approximately $11 million.

We have various capital lease and other long-term debt instruments of $154 million at December 31, 2015, but believe the impact of changes in interest rates in the near term will not be material to these instruments. The carrying value of our short-term borrowings of $1.2 billion at December 31, 2015 approximates their fair value.
 
As it relates to our variable rate debt, if market interest rates increase by an average of 1% from the rates as of December 31, 2015, interest expense for 2015 would increase by approximately $12 million. This amount was determined by calculating the effect of the hypothetical interest rate on our variable rate debt. For purposes of this sensitivity analysis, we assumed no changes in our capital structure.
 
Interest Rate Swaps and Derivatives
 
We manage our debt portfolio to limit our exposure to interest rate volatility and may employ interest rate derivatives as a tool to achieve that goal. The major risks from interest rate derivatives include changes in the interest rates affecting the fair value of such instruments, potential increases in interest expense due to market increases in floating interest rates and the creditworthiness of the counterparties in such transactions. The counterparties to our interest rate swaps are multinational commercial banks. We continually re-evaluate counterparty creditworthiness and modify our requirements accordingly.

Amounts paid or received upon termination of the interest rate swaps represent the fair value of the agreements at the time of termination. Derivative gains and losses are recognized each period in current earnings or other comprehensive income (loss), depending on whether the derivative is designated as part of a hedge relationship, and if so, the type of hedge.


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Item 8. Financial Statements and Supplementary Data

INDEX TO FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULE



46


Report of Independent Registered Public Accounting Firm


The Board of Directors and Shareholders
Weatherford International plc:

We have audited the accompanying consolidated balance sheets of Weatherford International plc and subsidiaries as of December 31, 2015 and 2014, and the related consolidated statements of operations, comprehensive income (loss), shareholders’ equity, and cash flows for each of the years in the three-year period ended December 31, 2015. In connection with our audits of the consolidated financial statements, we also have audited financial statement schedule II for each of the years in the three-year period ended December 31, 2015. These consolidated financial statements and financial statement schedule are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements and financial statement schedule based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Weatherford International plc and subsidiaries as of December 31, 2015 and 2014, and the results of their operations and their cash flows for each of the years in the three-year period ended December 31, 2015, in conformity with U.S. generally accepted accounting principles. Also in our opinion, the related financial statement schedule for each of the years in the three-year period ended December 31, 2015, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), Weatherford International plc’s internal control over financial reporting as of December 31, 2015, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated February 16, 2016 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.


/s/ KPMG LLP


Houston, Texas
February 16, 2016


47


Report of Independent Registered Public Accounting Firm


The Board of Directors and Shareholders
Weatherford International plc:

We have audited Weatherford International plc’s internal control over financial reporting as of December 31, 2015, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Weatherford International plc’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.
 
We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

In our opinion, Weatherford International plc maintained, in all material respects, effective internal control over financial reporting as of December 31, 2015, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Weatherford International plc and subsidiaries as of December 31, 2015 and 2014, and the related consolidated statements of operations, comprehensive income (loss), shareholders’ equity, and cash flows for each of the years in the three-year period ended December 31, 2015, and our report dated February 16, 2016 expressed an unqualified opinion on those consolidated financial statements.



/s/ KPMG LLP

Houston, Texas
February 16, 2016


48


WEATHERFORD INTERNATIONAL PLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
 
 
 
 
 
 
 
Year Ended December 31,
(Dollars and shares in millions, except per share amounts)
2015
 
2014
 
2013
Revenues:
 
 
 
 
 
Products
$
3,573

 
$
6,059

 
$
6,007

Services
5,860

 
8,852

 
9,256

Total Revenues
9,433

 
14,911

 
15,263

 
 
 
 
 
 
Costs and Expenses:
 
 
 
 
 
Cost of Products
3,433

 
4,942

 
4,480

Cost of Services
4,588

 
6,519

 
7,822

Research and Development
231

 
290

 
265

Selling, General and Administrative Attributable to Segments
1,353

 
1,727

 
1,728

Corporate General and Administrative
227

 
290

 
316

Long-Lived Asset Impairments and Other Related Charges
768

 
495

 

Goodwill and Equity Investment Impairment
25

 
161

 

Severance and Restructuring Charges
232

 
331

 

Litigation Charges
116

 

 
153

Loss (Gain) on Sale of Businesses and Investments, Net
6

 
(349
)
 
(24
)
Total Costs and Expenses
10,979

 
14,406

 
14,740

 
 
 
 
 
 
Operating Income (Loss)
(1,546
)
 
505

 
523

 
 
 
 
 
 
Other Income (Expense):
 
 
 
 
 
Interest Expense, Net
(468
)
 
(498
)
 
(516
)
Currency Devaluation and Related Charges
(85
)
 
(245
)
 
(100
)
Other, Net
3

 
(17
)
 
(77
)
 
 
 
 
 
 
Loss Before Income Taxes
(2,096
)
 
(255
)
 
(170
)
Benefit (Provision) for Income Taxes
145

 
(284
)
 
(144
)
Net Loss
(1,951
)
 
(539
)
 
(314
)
Net Income Attributable to Noncontrolling Interests
34

 
45

 
31

Net Loss Attributable to Weatherford
$
(1,985
)
 
$
(584
)
 
$
(345
)
 
 
 
 
 
 
Loss Per Share Attributable to Weatherford:
 
 
 
 
 
Basic & Diluted
$
(2.55
)
 
$
(0.75
)
 
$
(0.45
)
 
 
 
 
 
 
Weighted Average Shares Outstanding:
 
 
 
 
 
Basic & Diluted
779

 
777

 
772




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

49


WEATHERFORD INTERNATIONAL PLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
 
 
 
 
 
 
 
Year Ended December 31,
(Dollars in millions)
2015
 
2014
 
2013
Net Loss
$
(1,951
)
 
$
(539
)
 
$
(314
)
Other Comprehensive Loss, Net of Tax:
 
 
 
 
 
Foreign Currency Translation
(789
)
 
(673
)
 
(353
)
Defined Benefit Pension Activity
28

 
(19
)
 
2

Other
1

 
(2
)
 
1

Other Comprehensive Loss
(760
)
 
(694
)
 
(350
)
Comprehensive Loss
(2,711
)
 
(1,233
)
 
(664
)
Comprehensive Income Attributable to Noncontrolling Interests
34

 
45

 
31

Comprehensive Loss Attributable to Weatherford
$
(2,745
)
 
$
(1,278
)
 
$
(695
)

The accompanying notes are an integral part of these consolidated financial statements.
50


WEATHERFORD INTERNATIONAL PLC AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
 
 
 
 
 
December 31,
(Dollars and shares in millions, except par value)
2015
 
2014
Current Assets:
 
 
 
Cash and Cash Equivalents
$
467

 
$
474

Accounts Receivable, Net of Allowance for Uncollectible Accounts of $113 in 2015 and $108 in 2014
1,781

 
3,015

Inventories, Net
2,344

 
3,087

Prepaid Expenses
343

 
357

Deferred Tax Assets
165

 
303

Other Current Assets
464

 
708

Total Current Assets
5,564

 
7,944

 
 
 
 
Property, Plant and Equipment:
 
 
 
Land, Buildings and Leasehold Improvements
1,780

 
1,836

Rental and Service Equipment
8,702

 
9,714

Machinery and Other
2,432

 
2,468

Property, Plant and Equipment, Gross
12,914

 
14,018

Less: Accumulated Depreciation
7,235

 
6,895

Property, Plant and Equipment, Net
5,679

 
7,123

 
 
 
 
Goodwill
2,803

 
3,011

Other Intangible Assets, Net
356

 
440

Equity Investments
76

 
106

Other Non-current Assets
309

 
265

Total Assets
$
14,787

 
$
18,889

 
 
 
 
Current Liabilities:
 
 
 
Short-term Borrowings and Current Portion of Long-term Debt
$
1,582

 
$
727

Accounts Payable
948

 
1,736

Accrued Salaries and Benefits
406

 
425

Income Taxes Payable
203

 
230

Other Current Liabilities
892

 
909

Total Current Liabilities
4,031

 
4,027

 
 
 
 
Long-term Debt
5,879

 
6,798

Other Non-current Liabilities
512

 
1,031

Total Liabilities