10-K 1 wft201310-k.htm 10-K Wdesk | WFT 2013 10-K

 
UNITED STATES
 
 
SECURITIES AND EXCHANGE COMMISSION
 
 
Washington, DC 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, 2013
 
 
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 001-34258
 

WEATHERFORD INTERNATIONAL LTD.
(Exact name of registrant as specified in its charter)
Switzerland
 
98-0606750
(State or other jurisdiction of incorporation or organization)
 
(IRS Employer Identification No.)
4-6 Rue Jean-François Bartholoni, 1204 Geneva, Switzerland
 
Not Applicable
(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
Registered Shares, par value 1.16 Swiss francs per share
 
New York Stock Exchange
 
 
SIX Stock Exchange
 
 
NYSE Euronext Paris
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 nonaffiliates of the registrant as of June 30, 2013 was approximately $8.0 billion based upon the closing price on the New York Stock Exchange as of such date.
As of February 14, 2014, there were 771,183,045 shares of Weatherford registered shares, 1.16 Swiss francs par value per share, outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Registrant’s Definitive Proxy Statement for the 2014 Annual General Meeting of Shareholders.



Weatherford International Ltd.
Form 10-K for the Year Ended December 31, 2013
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
 
 
 
 


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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 Private Securities Litigation Reform Act of 1995. These forward-looking statements generally are identified by the words “believe,” “project,” “expect,” “anticipate,” “estimate,” “budget,” “intend,” “strategy,” “plan,” “guidance,” “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 assumptions we use in our forward-looking statements, as well as risks and uncertainties relating to those statements. Certain of the 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:

global political, economic and market conditions, political disturbances, war, terrorist attacks, changes in global trade policies, and international currency fluctuations;
our inability to realize expected revenues and profitability levels from current and future contracts;
our ability to manage our workforce, supply chain and business processes, information technology systems, and technological innovation and commercialization;
increases in the prices and availability of our raw materials;
nonrealization of expected reductions in our effective tax rate;
nonrealization of expected benefits from our acquisitions or business dispositions;
downturns in our industry which could affect the carrying value of our goodwill;
member-country quota compliance within Organization of Petroleum Exporting Countries (“OPEC”);
adverse weather conditions in certain regions of our operations;
failure to ensure on-going compliance with current and future laws and government regulations, including but not limited to environmental and tax and accounting laws, rules and regulations; and
limited access to capital or significantly higher cost of capital related to liquidity or uncertainty in the domestic or international financial 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 Securities and Exchange Commission (the “SEC”) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and the Securities Act of 1933, as amended (the “Securities Act”). For additional information regarding risks and uncertainties, see our other filings with the SEC. 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 are made available free of charge on our web site www.weatherford.com as soon as reasonably practicable after we have electronically filed the material with, or furnished it to, the SEC.


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PART I
Item 1. Business
 
Weatherford International Ltd., a Swiss joint-stock corporation (together with its subsidiaries, “Weatherford,” the “Company,” “we,” “us” and “our”), 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 and Middle East/North Africa (“MENA”)/Asia Pacific.

Our headquarters are located at 4-6 Rue Jean-Francois Bartholoni, 1204 Geneva, 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. 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, Room 1580, 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.
 
The following is a summary of our business strategies and the markets we serve. We have also included a description of our products and services offered and of our competitors. Segment financial information appears in “Item 8.Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 20Segment Information.”
 
Strategy
 
Our primary objective is to build stakeholder value through profitable growth with disciplined, efficient use of capital and a commitment to our core values and core product lines.
 
Principal components of our strategy include:
Continuously improving the efficiency, productivity and quality of our products and services and their respective delivery in order to grow revenues, operating margins and generate free cash flow from our core operations (Formation Evaluation, Well Construction, Completion and Production) in all of our geographic markets at a rate exceeding underlying market activity;
A commitment to innovation, invention and integration, developing and commercializing of new products and services that meet the evolving needs of our clients across the reservoir lifecycle;
Further extending process, productivity, quality, safety and competency across our global infrastructure in scope and scale at a level consistent with meeting client demand for our core products and services in an operationally efficient manner; and
Divestiture of our non-core businesses which include Land Rigs, Drilling Fluids, Wellhead, Pipelines and Specialty Services, and Well Testing.

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 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.

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, technology has become increasingly critical to the marketplace. Clients continue to seek, test and use production-enabling technologies at an increasing rate. Technology is an important aspect of our

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products and services as it helps us provide our clients with more efficient tools to find and produce oil and natural gas. We have invested a substantial amount of our time and resources in building our technology offerings. 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.
 
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 two product service line groups. Within each of our geographic reporting segments, we group our product offerings into two product service line groups: (1) Formation Evaluation and Well Construction and (2) Completion and Production, which together comprise a total of 15 service lines.

Formation Evaluation and Well Construction service lines include Controlled-Pressure Drilling and Testing, Drilling Services, Tubular Running Services, Drilling Tools, Integrated Drilling, Wireline Services, Re-entry and Fishing, Cementing, Liner Systems, Integrated Laboratory Services and Surface Logging.

Completion and Production service lines include Artificial Lift Systems, Stimulation and Chemicals, Completion Systems and Pipeline and Specialty Services.

With the exception of Integrated Drilling, which is offered outside of North America, our service line offerings are provided in all of our geographic segments.

Formation Evaluation and Well Construction

Within the Formation Evaluation and Well Construction product service line 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. The descriptions of our service lines under the Formation Evaluation and Well Construction product service line group are as follows:

Controlled-Pressure Drilling and Testing includes several drilling techniques including closed-loop drilling, air drilling, controlled pressure drilling, and underbalanced drilling. Our 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.

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, drillpipe, 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.

Integrated Drilling encompasses drilling and the project management services we provide to our clients in tandem with all of the products and services needed to drill and complete a well, including the rig.  

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.

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

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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 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 product service line group uses multi-zone isolation and access systems. 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. The descriptions of our service lines under the Completion and Production product service line group 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 all 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. 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.

Stimulation and Chemicals 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, including 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. These products and services also include drilling and completion fluids to prevent formation fluids from entering into the well bore using hydrostatic pressure and Engineered Chemistry® services.

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.

Pipeline and Specialty Services includes a range of services used throughout the life cycle of pipelines and process facilities, onshore and offshore. Our pipeline group serves the pipeline, process, industrial and energy markets worldwide. On permanently installed client equipment, we also provide services such as inspecting, cleaning, drying, testing, improving production, running, or establishing integrity from the wellhead out, including integrated management services.


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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 and Baker Hughes. 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.

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, 2013, our receivables from Latin America customers accounted for 38% of our net outstanding accounts receivable balance with $326 million due from Petroleos de Venezuela, S.A. (“PDVSA”) and $437 million from Petroleos Mexicanos (“Pemex”). On December 17, 2013, we accepted bonds with a face value of $127 million from PDVSA in full settlement of $127 million in trade receivables. Upon receipt, we immediately sold these bonds in a series of transactions recognizing a loss of $58 million. During 2013, 2012 and 2011, no individual customer accounted for more than 10% of our consolidated revenues.

Research, Development and Patents
 
We maintain world-class technology and training centers throughout the world. We have over 20 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 $265 million in 2013, $257 million in 2012 and $245 million in 2011.
 
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 have been noted to affect our operations negatively. Additionally, heavy rains or an exceedingly cold winter in a given region may impact our reported results. 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 2013 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 2014 to be material.
 

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Employees
 
At December 31, 2013, we employed approximately 67,000 employees. Certain of our operations are subject to union contracts. These contracts cover approximately 20% of our employees. We believe that our relationship with our employees is generally satisfactory. On January 30, 2014, we announced, as an important step in making our cost base more efficient, that we would reduce our workforce by 7,000 employees, primarily from our fixed support cost base. The workforce reduction is expected to be completed during the first half of 2014.

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 on the foregoing pages under “Forward-Looking Statements,” 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 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 and results of operations.

Demand for our services and products is tied to the level of exploration, development, production activity and the corresponding capital spending 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.

Prices for oil and natural gas are subject to large fluctuations in response to relatively minor changes in the supply of and demand for oil and natural gas, global market uncertainty, the ability of OPEC to set and maintain production levels for oil, oil and gas production levels by non-OPEC countries, member-country quota compliance within OPEC, governmental policies and subsidies, technological advances affecting energy consumption, weather conditions and a variety of other economic factors that are beyond our control. Any perceived or actual 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.

Our business is dependent on capital spending by our customers, and reductions in capital spending could have a material adverse effect on our business, financial condition and results of operations.

Any change in capital expenditures by our customers or reductions in their capital spending could directly impact our business by reducing demand for our services and products and have a material adverse effect on our business, financial condition and results of operations. Our customers are subject to risks which, in turn, could impact our business, including volatile oil and natural gas prices, difficulty accessing capital on economically advantageous terms and adverse developments in their own business or operations. With respect to national oil company customers, we are also subject to risk of policy, regime and budgetary changes.

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.


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The oilfield services business is highly competitive, which may adversely affect our ability to succeed.

Our business, particularly marketing our products and services to our customers and securing equipment and trained personnel, is highly competitive. 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, due in part to the industry’s capacity relative to customer demand and our ability to differentiate the value delivered by our products and services from that of our competitors. 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.

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 provide that our customers indemnify us for claims arising from the injury or death of their employees, the loss or damage of their equipment, damage to the reservoir, and pollution originating from the customer’s equipment or from the reservoir (including uncontained oil flow from a reservoir). Conversely, we typically indemnify our customers for claims arising from the injury or death of our employees, the loss or damage of our equipment or pollution emanating from our equipment. Our contracts typically provide that our customer will indemnify us for claims arising from catastrophic events, such as a well blowout, fire or explosion.

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 be held unenforceable in some courts and jurisdictions; or we may be subject to other claims brought by third parties or government agencies. 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 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

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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.

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. Finally, insurance rates have in the past been subject to wide fluctuation. In response to the April 2010 catastrophic accident in the Gulf of Mexico, insurance rates are volatile and increasing, and some forms of insurance may become entirely unavailable in the future or 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. are reviewing 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 states within the U.S. passed new laws and regulations concerning 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, or require other measures intended to prevent operational hazards. Any such federal, state 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 on 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 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. Total estimated losses on these two projects were $307 million at December 31, 2013.

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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 region and the former Soviet Union, 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 early 2011, our operations in Libya, Egypt, Algeria, Tunisia, and to a lesser extent Bahrain and Yemen were disrupted by political revolutions and uprisings in these countries, which had a negative impact on our results for 2011 and 2012. During 2013 and 2012, these six countries accounted for less than 2% of our global revenue, down from 3% in 2011 and 6% in 2010.

Due to the hostilities in Libya, and following an examination of our assets and an evaluation of our accounts receivable, we recognized an expense of $59 million in 2011 to establish a reserve for these assets. We were able to secure our assets and rigs and restart our operations base in Libya in the fourth quarter of 2012 and they have remained secure throughout 2013. At December 31, 2013, we had inventory, property, plant and equipment with a carrying value of approximately $76 million in Libya, as well as $13 million of accounts receivable. 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.

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.

On January 17, 2014, the U.S. District Court for the Southern District of Texas approved the settlement agreements between us and certain of our subsidiaries and the U.S. Department of Justice (“DOJ”). On November 26, 2013, we announced that we and our subsidiaries also entered into settlement agreements with the U.S. Departments of Treasury and Commerce and with the SEC, which the U.S. District Court for the Southern District of Texas entered on December 20, 2013. These agreements collectively resolved investigations of prior alleged violations by us and certain of our subsidiaries relating 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”).

Approximately $66 million of the $253 million to be paid by us and our subsidiaries under the settlement agreements was paid in January 2014 and the remaining $187 million was paid pursuant to the terms of the settlement agreements in February of 2014. These agreements include a requirement to retain, for a period of at least 18 months, an independent monitor responsible to assess our compliance with the terms of the agreement so as to address and reduce the risk of recurrence of alleged misconduct, after which we would continue to evaluate our own compliance program and make periodic reports to the DOJ and SEC and a requirement to maintain agreed compliance monitoring and reporting systems, all of which is costly to us. These agreements also require 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, including for the FCPA and trade sanctions criminal violations that were resolved in the settlement. Under such circumstances, DOJ would be permitted to rely upon the

10


admissions we and certain of our subsidiaries made in the settlement, and would benefit from our waiver of certain procedural and evidentiary defenses. In addition, if we were to breach the terms of the settlement agreements concerning trade sanctions violations, all of our export privileges, and the export privileges of certain of our subsidiaries, could be revoked for one year. Moreover, failure to abide by the terms of the settlement agreements with the SEC or the Commerce or Treasury Departments would permit these agencies to pursue rescission of the settlement agreements, 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.

For additional information about these actions and claims, you should refer to the sections entitled “Item 8.Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 18Disputes, Litigation and Contingencies” and “– Note 21Subsequent Events.”
 
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.

Our significant operations in foreign countries expose us to currency fluctuation risks or devaluation.

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.

As a result, we are subject to significant risks, including foreign currency exchange risks resulting from changes in foreign currency exchange rates and the implementation of exchange controls and limitations on our ability to reinvest earnings from operations in one country to fund the capital needs of our operations in other countries.

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

The concentration of our customers in the energy industry may impact our overall exposure to credit risk as customers may be similarly affected by prolonged changes in economic and industry conditions. Those countries that rely heavily upon income from hydrocarbon exports would be hit particularly hard by a drop in oil prices. Further, 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.

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 a further devaluation of the Venezuelan bolivar, the foreign currency exchange rate and exchange controls, other actions of the Venezuelan government and the general economic conditions in the country, resulting from 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. On December 17, 2013, we accepted bonds with a face value of $127 million from PDVSA in full settlement of $127 million in trade receivables. Upon receipt, we immediately sold these bonds in a series of transactions 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.


11


Credit rating agencies could lower our credit ratings.

Credit rating agencies could downgrade our credit ratings. Our Standard & Poor’s Ratings Services’ credit rating on our senior unsecured debt is currently BBB- and our short-term rating is A-3, both with a stable outlook. Our Moody’s Investors Ratings Services’ credit rating on our unsecured debt is currently Baa2 and our short-term rating is P-2, both with a negative outlook. If our credit ratings are lowered to non-investment grade levels this could limit our ability to refinance our existing debt, could cause us to refinance or issue debt with less favorable 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.

Any capital financing that may be necessary to fund growth may not be available to us at economic rates.

The condition of the credit and equity markets and the potential impact on liquidity of major financial institutions may have an adverse effect on our ability to fund growth opportunities 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, our credit facility or commercial paper program, 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 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.

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 have remediated our material weakness in accounting for income taxes. We cannot assure you 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 and annual auditor attestation reports 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 subsequent restatements of our historical financial statements. We are cooperating fully with these investigations. 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 is subject to notice to the putative class, approval by the U.S. District Court for the Southern District of New York, and other conditions. Pursuant to the settlement, we will pay approximately $53 million, all of which is recoverable from insurance, 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.


12


Also 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 announcement. In February 2012, a second shareholder derivative action was filed. In March 2012, a second purported securities class action was filed against us and certain current and former officers. 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. 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 18Disputes, Litigation and Contingencies.”

We are unable to predict the outcome of these investigations and lawsuits 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 sections entitled “Item 8.Financial Statements and Supplementary DataNotes to Consolidated Financial StatementsNote 18Disputes, Litigation and Contingencies” and “– Note 21Subsequent Events.”

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 Delaware to Bermuda and in 2009, we redomesticated from Bermuda to Switzerland. There are frequently 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. The realization of the tax benefit of our 2002 reorganization from Delaware to Bermuda and our 2009 redomestication from Bermuda to Switzerland 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 or other taxing jurisdictions. The inability to realize this benefit could have a material impact on our financial statements.

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 with differing tax rates, changes in deferred tax assets and liabilities or changes in tax laws. 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 affect the distribution of our earnings and the results of our operations.


13


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 rights of our shareholders are governed by Swiss law and documents following the redomestication.

The rights of our shareholders are governed by Swiss law and Weatherford Switzerland’s articles of association and organizational regulations. The rights of shareholders under Swiss law differ from the rights of shareholders of companies incorporated in other jurisdictions. For example, directors of Weatherford Switzerland may be removed by shareholders with or without cause, but such removal requires the vote of shareholders holding at least 66 2/3% of the voting rights and the absolute majority of the par value of the registered shares represented at the meeting as well as a quorum of at least two-thirds of the registered shares recorded in the share register.

The recent adoption of the Ordinance Against Executive Compensation by the Swiss Federal Council could have a material adverse effect on our business, financial condition and results of operations.

On November 20, 2013, the Swiss Federal Council approved the final Ordinance Against Executive Compensation, commonly known as the Minder Initiative. Starting January 1, 2014, all Swiss companies that are publicly traded on any exchange, including us, are subject to the ordinance. The Minder Initiative requires a mandatory, binding shareholder vote on director and executive management compensation (starting in 2015), requires separate votes for the chairman of the board, board members, compensation committee members and independent proxy holder, prohibits severance payments to directors and executive management and will require substantial amendments to our articles of association and additional proxy disclosure and reports. We believe the adoption of this ordinance may have significant consequences for our corporate governance practices as well as our executive compensation, which in turn, may affect our ability to attract and retain executives. Additionally, implementation of changes required by the Minder Initiative is expected to be cumbersome and costly, which could have a material adverse effect on our business, financial condition and results of operations. Furthermore, we are subject to the Exchange Act and its proxy rules, which provide for a non-binding say-on-pay vote by our shareholders for compensation of our chief executive officer, chief financial officer, and three other most highly compensated executive officers and other disclosures relating to our executive compensation. The regulatory requirements under the Minder Initiative for executive compensation are inconsistent with the proxy rules, both of which are applicable to us, and could lead to confusing and inconsistent proposals to our shareholders for approval at annual general meetings and inconsistencies in executive compensation disclosure in related proxy statements and our other SEC disclosure documents. Any other voter or other initiatives that result in changes in Swiss corporate law could also have a material adverse effect on our business, financial condition and results of operations.

We hold shareholder meetings in Switzerland, and our required quorum for those meetings is lower.

We hold shareholders meetings in Switzerland, which may make attendance in person more difficult for some investors. For shareholders meetings for the transaction of any business other than removal of a director or certain other specified resolutions, a quorum comprises at least one-third of the registered shares recorded in the share register and entitled to vote (and at least two-thirds of the registered shares recorded in the share register and entitled to vote for the removal of directors and certain other specified resolutions).

The divestiture of certain of our non-core business lines may not be completed on the currently contemplated timeline, or at all, and we may not achieve the intended benefits.

In November 2013, we announced our intention to divest certain of our non-core business lines (land drilling rigs, drilling fluids, pipeline and specialty services, testing and production services, and wellheads) and target dates for completing these

14


divestitures. Each of the proposed divestitures is complex in nature and may be affected by unanticipated developments, delays in obtaining regulatory or governmental approvals, challenges in establishing processes and infrastructure and changes in market conditions for both the underlying business and for potential investors or buyers in the targeted businesses. In addition, accomplishing the divestitures will incur considerable expense and require significant time and attention from management and our employees, which could distract them from other tasks in operating our business. Any or all of these proposed divestitures may take longer than we currently anticipate and may lead to the divestitures occurring under less favorable conditions (or not occurring at all), or without our fully realizing the intended benefits of such transactions.

Item 1B. Unresolved Staff Comments

None.


15


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 location of our principal owned or leased facilities for our operations by geographic segment as of December 31, 2013:
Region
Specific Location
North America:
Greenville, Katy, Pasadena and San Antonio, Texas; Schriever, Louisiana;
Leetsdale, Pennsylvania; New Brighton, Minnesota; Williston, North Dakota; and Nisku, Canada.
 
 
Latin America: 
Poza Rica, Reynosa, Venustiano Carranza and Ciudad Del Carmen, Mexico; Ciudad Ojeda, Venezuela; and Rio de Janeiro, Brazil.
 
 
Europe/SSA/Russia:
Lukhovitsy and Nizhnevartovsk, Russia; Langenhagen, Germany; and Stavanger, Norway.
 
 
MENA/Asia Pacific:
Tianjin and Shifang, China; Kurdistan, Iraq; Abu Dhabi and Jebel Ali, United Arab Emirates;
Dharan, Saudi Arabia; and Singapore, Singapore.

Our headquarters are in Geneva, Switzerland and our corporate offices are located 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 that our 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.Business – Other Business Data – Federal 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 Data – Notes to Consolidated Financial Statements – Note 18Disputes, Litigation and Contingencies” and “– Note 21Subsequent Events.”
 
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.



16


PART II

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

Our shares are traded under the symbol “WFT” on the New York Stock Exchange (“NYSE”), the Euronext-Paris Exchange and the SIX Swiss Exchange. As of February 14, 2014, there were 2,204 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, 2013
 
 
 
First Quarter
$
13.70

 
$
11.08

Second Quarter
14.65

 
11.66

Third Quarter
15.80

 
13.60

Fourth Quarter
17.38

 
14.44

 
 
 
 
Year ending December 31, 2012
 
 
 
First Quarter
$
18.33

 
$
14.57

Second Quarter
15.47

 
11.14

Third Quarter
14.04

 
11.17

Fourth Quarter
12.92

 
8.84


On February 14, 2014, the closing sales price of our shares as reported by the NYSE was $14.78 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.
 
Under our restricted share plan, employees may elect to have us withhold shares to satisfy minimum statutory federal, state and local tax withholding obligations arising on the vesting of restricted stock awards and exercise of options. When we withhold these shares, we are required to remit to the appropriate taxing authorities the market price of the shares withheld, which could be deemed a purchase of shares by us on the date of withholding. During the quarter ended December 31, 2013, we withheld shares to satisfy these tax withholding obligations as follows:
Period
 
No. of Shares
 
Average Price
October 1 - October 31, 2013
 
18,342

 
$
15.63

November 1 - November 30, 2013
 
140,450

 
16.98

December 1 - December 31, 2013
 
151,129

 
13.86


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.

17



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, 2008. 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 common stock, the Dow Jones U.S.
Oil Equipment and Services Index and
the Dow Jones U.S. Index


18


 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 Data – Notes to Consolidated Financial Statements – Note 18Disputes, 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)
2013
 
2012
 
2011
 
2010
 
2009
Statements of Operations Data:
 
 
 
 
 
 
 
 
 
Revenues
$
15,263

 
$
15,215

 
$
12,988

 
$
10,221

 
$
8,833

Operating Income
523

 
298

 
1,307

 
774

 
687

Income (Loss) From Continuing Operations Attributable To Weatherford
(345
)
 
(778
)
 
189

 
(217
)
 
87

Basic Earnings (Loss) Per Share From Continuing Operations Attributable To Weatherford
(0.45
)
 
(1.02
)
 
0.25

 
(0.29
)
 
0.12

Diluted Earnings (Loss) Per Share From Continuing Operations Attributable To Weatherford
(0.45
)
 
(1.02
)
 
0.25

 
(0.29
)
 
0.12

 
 
 
 
 
 
 
 
 
 
Balance Sheet Data:
 
 
 
 
 
 
 
 
 
Total Assets
$
21,977

 
$
22,795

 
$
21,051

 
$
19,199

 
$
18,782

Long-term Debt
7,061

 
7,049

 
6,286

 
6,530

 
5,847

Shareholders’ Equity
8,203

 
8,818

 
9,345

 
9,118

 
9,175

Cash Dividends Per Share

 

 

 

 



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

Our Management’s Discussion and Analysis of Financial Condition and Results of Operations begins with an executive overview that provides a general description of our Company, a synopsis of industry market trends, insight into management’s perspective of the opportunities and challenges we face and our outlook for 2014. Next, we analyze the results of our operations for the last three years, including the trends in our business. We then review our cash flows and liquidity, capital resources and contractual commitments. We conclude with an overview of our critical accounting policies and estimates and a summary of recently issued accounting pronouncements.
 
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 are based on certain assumptions we consider reasonable. For information about these assumptions, you should refer to the section entitled “Forward-Looking Statements” and the section entitled “Item 1A.Risk Factors.”
 
Overview
 
General
 
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 two product service line groups: (1) Formation Evaluation and Well Construction and (2) Completion and Production, which together comprise a total of 15 service lines.

Formation Evaluation and Well Construction service lines include Controlled-Pressure Drilling and Testing, Drilling Services, Tubular Running Services, Drilling Tools, Integrated Drilling, Wireline Services, Re-entry and Fishing, Cementing, Liner Systems, Integrated Laboratory Services and Surface Logging.

Completion and Production service lines include Artificial Lift Systems, Stimulation and Chemicals, Completion Systems and Pipeline and Specialty Services.

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 and services are delivered. 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.
 
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/SSA/Russia, MENA/Asia Pacific.

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Industry Trends

Changes in the current price and expected future prices of oil and natural gas influence the level of energy industry spending. 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)
2013
$
98.42

 
$
4.19

 
2,129

 
1,320

2012
91.82

 
3.35

 
2,178

 
1,260

2011
98.83

 
2.99

 
2,481

 
1,188

(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
 
Oil prices fluctuated during 2013, ranging from a high of $110.53 per barrel in early September to a low of $86.68 per barrel in mid-April. Natural gas ranged from a high of $4.50 MM/BTU in late December to a low of $3.11 MM/BTU in early January. 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, levels of spare production capacity within the Organization of Petroleum Exporting Countries (“OPEC”), weather and geopolitical uncertainty.

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, successfully maximize the benefits from our acquisitions and successfully complete the disposition of our non-core businesses.
 
Outlook
 
In 2014, we expect to achieve improved profitability by focusing the organization on growing our core businesses, making our cost base more efficient, divesting our non-core businesses and reducing our debt. 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. In November 2013, we announced our intention to divest certain non-core business lines (land drilling rigs, drilling fluids, pipeline and specialty services, testing and production services and wellheads) and target dates for completing these divestitures. The cash proceeds from these divestitures will be used to pay down debt. On January 30, 2014, we announced, as an important step in making our cost base more efficient, that we would reduce our workforce by 7,000 employees, primarily from our fixed support cost base. The workforce reduction is expected to be completed during the first half of 2014 and is designed to lighten our support structure as a complement to our planned divestiture program. Our strategic business reviews of operations that do not generate good margins and are a drain on our cash flow are underway, and we expect to begin eliminating select operations in certain markets in the second quarter of 2014. We expect these actions will bring additional costs savings, in the form of headcount reduction as well as other areas.

In 2014, we expect revenue growth, primarily in our core businesses, in North America, Europe/SSA/Russia and MENA/Asia Pacific regions while Latin America is expected to decline. Overall margins will improve as a result of lower costs and the growth in our more profitable core businesses. The revenue growth and margins will show improvements throughout the year, but will be stronger in the second half of 2014. Our effective tax rate is expected to be between 25% and 35% and will depend on the

21


geographical mix of earnings. Capital expenditures are targeted at approximately 8% of revenues. The continued focus on reducing working capital coupled with improved earnings is expected to generate improved positive free cash flow during 2014.

We believe the long-term outlook for our businesses is favorable. As well production decline rates accelerate and reservoir productivity complexities increase, our clients will continue to face growing challenges securing desired rates of production growth. These challenges increase our customers’ requirements for technologies that improve productivity and efficiency and increase demand for our products and services. These factors provide us with a positive outlook for our core businesses over the longer term. The level of improvement in our businesses in the future will continue to depend heavily on pricing and volume increases, our control of costs and our ability to further penetrate existing markets with our younger technologies, as well as to successfully introduce these technologies to new markets.

The continued and increasing strength of the industry, including client spending, will be highly dependent on many external factors, such as world economic and political conditions, the price of oil and natural gas, member-country quota compliance within OPEC and weather conditions, including the factors described in the section entitled “Forward-Looking Statements” and the section entitled “Item 1A.Risk Factors.”
 
Results of Operations

The following charts contain selected financial data comparing our consolidated and segment results from operations for 2013, 2012 and 2011. See “Notes to Consolidated Financial Statements – Note 20Segment Information“ for additional information regarding variances in operating income. 
 
Year Ended December 31,
 (Dollars in millions, except per share data)
2013
 
2012
 
2011
Revenues:
 
 
 
 
 
North America
$
6,390

 
$
6,824

 
$
6,023

MENA/Asia Pacific
3,344

 
2,795

 
2,441

Europe/SSA/Russia
2,693

 
2,519

 
2,298

Latin America
2,836

 
3,077

 
2,226

 
15,263

 
15,215

 
12,988

Operating Income (Expense):
 
 
 
 
 
North America
820

 
1,078

 
1,259

MENA/Asia Pacific
(96
)
 
34

 
25

Europe/SSA/Russia
288

 
315

 
287

Latin America
306

 
395

 
254

Research and Development
(266
)
 
(257
)
 
(245
)
Corporate Expenses
(200
)
 
(196
)
 
(177
)
Goodwill and Equity Investment Impairment

 
(793
)
 

U.S. Government Investigation Loss
(153
)
 
(100
)
 

Other Items
(176
)
 
(178
)
 
(96
)
 
523

 
298

 
1,307

 
 
 
 
 
 
Interest Expense, Net
(516
)
 
(486
)
 
(453
)
Devaluation of Venezuelan Bolivar
(100
)
 

 

Other, Net
(77
)
 
(100
)
 
(107
)
Provision for Income Tax
(144
)
 
(462
)
 
(542
)
Net Income (Loss) per Diluted Share
(0.45
)
 
(1.02
)
 
0.25

Depreciation and Amortization
1,402

 
1,282

 
1,136



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Revenues

The following chart contains the percentage distribution of our consolidated revenues by product service line group for 2013, 2012 and 2011:
 
Year Ended December 31,
 
2013
 
2012
 
2011
Formation Evaluation and Well Construction
61
%
 
56
%
 
57
%
Completion and Production
39

 
44

 
43

Total
100
%
 
100
%
 
100
%

Consolidated revenues increased $48 million in 2013 compared to 2012. International revenues increased $482 million, or 6%, in 2013 compared to 2012, on a 5% increase in the 2013 annual international average rig count. International revenues include revenue from all segments other than North America. Increased activity in the eastern hemisphere, primarily due to higher demand for our drilling services, well construction, artificial lift and integrated drilling product service lines, was the driver for the increase compared to 2012. Revenue in our North America segment decreased $434 million, or 6%, in 2013 compared to the prior year, on a 7% decrease in 2013 annual North American average rig count. The decrease in revenue was due to reduced demand and the associated pricing pressure on our pressure pumping and wireline service lines as well as the sale of our industrial screen business in the first half of 2013.

Consolidated revenues increased $2.2 billion, or 17%, in 2012 compared to 2011. North America segment revenues increased $801 million, or 13%, in 2012 compared to 2011, on a 1% decrease in rig count. International revenues increased $1.4 billion, or 20%, on a 6% rig count increase. Latin America was the strongest contributor to our year-over-year international revenue growth. From a service line perspective, artificial lift, integrated drilling, and pipeline and specialty services experienced the strongest growth in 2012.

Operating Income

Consolidated operating income increased $225 million, or 76%, in 2013 compared to 2012, primarily due to the 2012 goodwill and equity investment impairment charges totaling $793 million. Excluding these impairment charges, operating income declined $568 million, driven by a $504 million decrease from our operating segments income primarily due to pricing pressure and decreased demand across most service lines in our North America segment as compared to 2012, as well as estimated losses of $232 million for our long-term early production facility construction contracts in Iraq. In 2013, we recognized bad debt expense of $98 million, of which $59 million was in Latin America and almost entirely attributable to a $58 million loss on PDVSA bond exchange for Venezuelan accounts receivable, $27 million in MENA/Asia Pacific, $10 million in Europe/SSA/Russia and $2 million in North America.

During 2013, we recorded a $153 million accrual related to U.S. government investigations and recognized other items of $176 million, including $67 million in professional fees and expenses related to the settlement of the U.S. government investigations and the remediation of our material weakness related to income taxes, $94 million of severance, and $15 million of exit costs and other items, net of $24 million of gains related to the sale of our 38.5% equity interest in Borets International Limited (“Borets”) and our industrial screen business.

Consolidated operating income decreased $1 billion, or 77%, in 2012 compared to 2011. Our operating segments contributed to only $3 million of the decrease. The primary drivers of the decline in operating income were the recognition of goodwill and equity investment impairment charges of $793 million, a $100 million accrual related to settlement of U.S. government investigations and an $82 million increase in other items expenses compared to 2011. Research and development expenditures represented a consistent 2% of revenues in both 2012 and 2011. The increase in our corporate general and administrative expenses is primarily attributable to increased personnel cost and professional services fees.

We incurred $178 million of net other items during 2012, which included $103 million of professional fees associated with our income tax restatement and material weakness remediation, $79 million of severance, exit and other charges, including $13 million of costs incurred in connection with investigations by the U.S. government, $12 million of total costs, including fees and expenses, associated with our 2012 debt consent solicitation, offset by a $28 million gain related to the sale of our subsea controls business.


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We incurred $96 million of net other items during 2011, which included $55 million of severance, exit and other charges, income tax restatement and material weakness remediation expenses of $22 million, $10 million of costs incurred in connection with investigations by the U.S. government and $9 million associated with the termination of a corporate consulting contract.

Devaluation of Venezuelan Bolivar

Effective January 1, 2011, the Venezuelan government modified the fixed rate of exchange, eliminating the previous two-tier structure and establishing 4.30 per dollar as the official exchange rate of the Venezuelan bolivar for all goods and services. This modification did not have a material impact to our financial position or results of operations.

On February 8, 2013, the Venezuelan government announced its intention to further devalue its currency effective February 13, 2013 at which time the official exchange rate moved from 4.30 per dollar to 6.30 per dollar for all goods and services. In connection with this devaluation, we recognized a charge of $100 million in 2013 for the remeasurement of our net monetary assets denominated in the Venezuelan bolivar at the date of the devaluation, which was not tax deductible in Venezuela. We also recorded a $6 million benefit for Venezuelan income tax purposes related to our net U.S. dollar determined tax liability in the country.

As of December 31, 2013, we had a net monetary asset position denominated in Venezuelan bolivars of approximately $238 million, comprised primarily of accounts receivable and current liabilities. We are continuing to explore opportunities to reduce our exposure, but should another devaluation occur in the future, we may be required to take further charges related to the remeasurement of our net monetary asset position.

Interest Expense, Net

Interest expense, net increased $30 million, or 6%, in 2013 compared to 2012 due to increases in our levels of indebtedness. Interest expense, net increased $33 million, or 7%, in 2012 compared to 2011 due to increases in our levels of indebtedness. In both years the increase in indebtedness was largely via our commercial paper program.

Other Expense, Net

Other expense, net was $77 million in 2013, $100 million in 2012 and $107 million in 2011, and these expenses primarily represent foreign currency exchange losses, excluding the devaluation of the Venezuelan bolivar, associated with our foreign denominated net asset or liability positions relative to the strength of the U.S. dollar. In addition, during 2013 we recognized a charge of approximately $100 million on the devaluation of the Venezuelan bolivar. Due to the magnitude the 2013 devaluation of the Venezuelan bolivar we have provided a discussion mentioned previously under the heading “Devaluation of Venezuelan Bolivar.”

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.

Our provision for income taxes in the countries in which we operate was $144 million in 2013, $462 million in 2012 and $542 million in 2011, which resulted in an effective tax rate of (85)%, (160)% and 73%, respectively. Our provision for income taxes was significantly impacted by discrete tax expense items in each of these years. In 2013, our income before tax includes 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

24


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. In 2012, our results include a $589 million goodwill impairment charge, which was substantially non-deductible, a $204 million equity method impairment charge and a $100 million accrual for a loss contingency, both of which are fully non-deductible. In 2011, we recognized $20 million of withholding tax on the redemption of equity in one of our U.S. subsidiaries. Our results in 2013 and 2012 included significant losses in Iraq with a valuation allowance of $134 million and $72 million, respectively.
 
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/Asia Pacific segment, 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 withholding taxes were $85 million in 2013, $138 million in 2012 and $94 million in 2011. 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 decreased from 2012 to 2013 primarily due to tax restructuring benefits and decrease in our reserve for uncertain tax positions due to audit settlements and statue expirations. These reductions were partially offset by higher valuation allowances recognized in 2013, mainly as a result of an increase of losses on certain projects in Iraq and the loss due to the devaluation of the Venezuelan bolivar. Our effective tax rate increased from 2011 to 2012 due primarily to significant impairment charges and accrual for a loss contingency that are not deductible for tax. Our effective tax rate will generally be lower in periods of higher pre-tax earnings as the rate impact of certain of the items discussed above is mitigated by the higher earnings.

Segment Results
 
North America
 
North America segment revenues decreased $434 million, or 6%, in 2013 compared to 2012. The 2013 North America average rig count decreased 7% compared to 2012. The decline in revenues was primarily due to reduced demand and the related pricing pressure on our pressure pumping and wireline service lines, as well as a decline in our industrial screens revenue due to the sale of this business unit in 2013. These declines were partially offset by an increase in service line revenues from our well construction services.

Operating income decreased $258 million, or 24%, in 2013 compared to 2012. Declines in operating margin are primarily attributable to pressure pumping margin declines due to price reductions and higher fixed costs, as well as lower gross profit in drilling services driven by a decline in activity. Operating margins were 13% in 2013 compared to 16% in 2012. These margin declines were partially offset by increases in artificial lift operating margins due to increased demand and utilization of our products and services.

North America revenues increased $801 million, or 13%, in 2012 compared to 2011 on a 1% decrease in average rig count in North America over the comparable period. Revenues increased due to higher demand for our well construction, artificial lift systems, drilling services and completions services, which were our strongest service line contributors year-over-year.

Operating income decreased $181 million, or 14%, in 2012 compared to 2011. Operating margins fell to 16% in 2012 compared to 21% in 2011. Pricing pressures in stimulation contributed to the decline in margins over the comparable period of the prior year. Also, during 2012, we recognized charges attributable to the North America reporting segment totaling $51 million to adjust the carrying value of our guar inventory, a component of certain drilling fluids, to the lower of cost or market, and for excess and obsolete inventory.


25


MENA/Asia Pacific
 
MENA/Asia Pacific revenues increased $549 million, or 20%, which includes $512 million related to projects in Iraq, in 2013 compared to 2012. The increased revenue was due to higher demand for our drilling services, well construction and artificial lift service lines primarily in Iraq, Saudi Arabia and United Arab Emirates.

Operating income decreased $130 million in 2013 compared to 2012. The 2013 decrease in operating income is primarily due to increased costs in completions, drilling services and integrated drilling, and the additional losses on the long-term early production facility construction contracts in Iraq, accounted for under the percentage of completion method. During 2013, we recognized estimated project losses of $232 million related to these construction contracts. Total estimated losses on these projects were $307 million at December 31, 2013. During 2013, we recognized bad debt expense of $27 million in the MENA/Asia Pacific reporting segment.

MENA/Asia Pacific revenues increased $354 million, or 15%, in 2012 compared to 2011, outpacing the 10% increase in rig count. The increase in revenues is attributable to the contribution made by several key countries including Iraq, Saudi Arabia and Oman. Increased demand for our drilling services, integrated drilling, artificial lift systems and completions service lines were the strong contributors in the region.
 
Operating income increased $9 million, or 36%, in 2012 as compared to 2011 and operating margins were flat. Losses incurred in our Iraq operations during 2012 of $189 million were more than offset by increases in operating income in Saudi Arabia and in Asia Pacific countries. During 2012, we recognized a charge for excess and obsolete inventory of $16 million attributable to the MENA/Asia Pacific reporting segment.
 
In early 2011, our operations in Libya, Algeria, Tunisia, Egypt, and to a lesser extent Yemen and Bahrain were disrupted by political revolutions and uprisings in these countries, which had a negative impact on our results for 2011 and 2012. During 2013 and 2012, these six countries accounted for less than 2% of our global revenue, down from 3% in 2011 and 6% in 2010.

Due to the hostilities in Libya, and following an examination our assets and an evaluation of our accounts receivable, we recognized an expense of $59 million in 2011 to establish a reserve for these assets. We were able to secure our assets and rigs and restart our operations base in Libya in the fourth quarter of 2012 and they have remained secure throughout 2013. At December 31, 2013, we had inventory, property, plant and equipment with a carrying value of approximately $76 million in Libya, as well as $13 million of accounts receivable.

Europe/SSA/Russia
 
Revenues in our Europe/SSA/Russia segment increased $174 million, or 7%, in 2013 compared to 2012. The region realized strong performances due to increased activity in integrated drilling in Russia. In addition, Russia and SSA, particularly in Gabon, Congo and Cameroon, had higher demand for our drilling services in 2013.

Operating income decreased $27 million, or 9%, in 2013 compared to 2012. Operating margins were 11% in 2013 and 13% in 2012. The decrease in operating income and margins was due to increased costs for drilling equipment in Russia, relative to the prior year related to drilling services, integrated drilling and pipeline and specialty services activity.

Revenues in our Europe/SSA/Russia segment increased $221 million, or 10%, in 2012 compared to 2011, with a 6% rig count increase over the comparable period. Our integrated drilling, completions, pipeline and specialty services and drilling tool service lines were the strongest contributors to the year-over-year growth.

Operating income increased $28 million, or 10%, in 2012 compared to 2011. Operating margins were flat when compared to 2011. With consistent margins the increases are attributable to integrated drilling, completions, pipeline and specialty services and drilling tool service lines, which offset a charge recognized during 2012 for excess and obsolete inventory of $11 million attributable to the Europe/SSA/Russia reporting segment.
 
Latin America
 
Revenues in our Latin America segment decreased $241 million, or 8%, in 2013 compared to 2012 largely due to lower demand for our artificial lift and integrated drilling services in Mexico, Venezuela and Brazil, partially offset by increased demand for our well construction and pipeline and specialty services.


26


Operating income decreased $89 million, or 23%, in 2013 compared to 2012 due in part to a $58 million loss recognized upon settlement of $127 million in outstanding receivables due from PDVSA. On December 17, 2013, we accepted bonds with a face value of $127 million from PDVSA in full settlement of $127 million in trade receivables. Upon receipt, we immediately sold these bonds in a series of transactions recognizing a bad debt expense of $58 million. Operating margins were 11% in 2013 and 13% in 2012 due primarily to higher bad debt expenses in the region. Without this bad debt expense, operating margin in 2013 would have been 13%.

Latin American revenues increased $851 million, or 38%, in 2012 compared to 2011, despite a flat average rig count for the region. The increase in revenue was mostly due to improved demand in our integrated drilling, artificial lift systems, completions and stimulation and chemicals service lines. Geographically, Colombia, Mexico and Venezuela contributed significant revenue improvements.

Operating income for Latin America increased $141 million, or 56%, in 2012 compared to 2011. Operating margins were 13% in 2012 compared to 11% in 2011. A main driver of this increase was the extent of progress on our project work in Mexico. During 2012, we recognized a charge for excess and obsolete inventory of $5 million attributable to the Latin America reporting segment.

Liquidity and Capital Resources

Cash Flows
 
Year Ended December 31,
(Dollars in millions)
2013
 
2012
 
2012
Net cash provided by operating activities
$
1,229

 
$
1,221

 
$
852

Net cash used by investing activities
(1,104
)
 
(2,306
)
 
(1,674
)
Net cash provided by financing activities
6

 
1,012

 
777


At December 31, 2013, we had cash and cash equivalents of $435 million compared to $300 million at December 31, 2012. Cash flows provided by operating activities were $1.2 billion during both 2013 and 2012. 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. The change in our net working capital provided operating cash flows of $186 million.

At December 31, 2012, we had cash and cash equivalents of $300 million compared to $371 million at December 31, 2011. Cash flow from operating activities provided $1.2 billion during 2012 compared to $852 million during 2011. Our net loss in 2012 was $750 million compared to a net income of $205 million in 2011. Non-cash charges in 2012 were higher by $891 million compared to 2011, primarily due to the impairment of goodwill and equity investment which occurred in 2012. The net change in our total operating assets and liabilities used $433 million less cash in 2012 than in 2011.

Investing Activities

The main driver of our investing cash flow activities is capital expenditures for property, plant and equipment. Capital expenditures were $1.6 billion in 2013, $2.2 billion in 2012 and $1.5 billion in 2011. The amount we spend for capital expenditures varies each year based on the type of contracts in which we enter, our asset availability and our expectations with respect to industry activity levels in the following year.

Investing activities also include net cash amounts paid for acquisitions and net proceeds received for sales of assets, businesses and equity investments. Cash proceeds received from dispositions were $488 million in 2013, primarily from the sale of our 38.5% equity interest in Borets and our industrial screen business. Cash proceeds received from dispositions were $61 million from the sale of our subsea controls business in 2012 and $31 million from other dispositions in 2011. We paid $17 million for acquisitions in 2013, $190 million in 2012 and $166 million in 2011. Our current focus is on disposition of businesses or capital assets that are no longer core to our long-term strategy, although we will continue to make business acquisitions when strategically advantageous.


27


Financing Activities

Our financing activities primarily consisted of borrowing and repayment of long-term and short-term debt. Our short-term borrowings amounted to $612 million in 2013 and $992 million in 2011. In 2012, our net repayments of short-term borrowings were $13 million. In 2013, our long-term borrowings were $3 million. In 2012, we increased our long-term debt by $1.3 billion through the issuance of senior notes, as noted below under “Sources of Liquidity.” In 2011, our long-term borrowings were $22 million. Total long-term debt repayments were $603 million in 2013, $310 million in 2012 and $216 million in 2011, which included the repayment of our senior notes of $544 million in 2013, $273 million in 2012 and $183 million in 2011.

During 2012, our financing activities include $65 million for the exercise of warrants as discussed below. Our other financing activities included dividends paid to noncontrolling partners in consolidated joint ventures of $27 million in 2013, $21 million in 2012 and $29 million in 2011. In addition, we received proceeds from the exercise of stock options issued to our employees and directors of $22 million for 2013, $4 million for 2012 and $3 million for 2011.

Expense, fees and other costs associated with our debt consent solicitation in 2012 included approximately $18 million we paid to the holders of our senior notes in connection with a consent solicitation from our senior note holders and $12 million of total other costs, including fees and expenses, incurred associated with our 2012 debt consent solicitation. See “Item 8.Financial Statements and Supplementary Data – Notes to Consolidated Financial Statements – Note 11Long-term Debt.”

Sources of Liquidity

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

Committed Borrowing Facility

We maintain a $2.25 billion unsecured, revolving credit agreement (the “Credit Agreement”) with JPMorgan Chase Bank, N.A., as administrative agent, scheduled to mature July 13, 2016. The Credit Agreement can be used for a combination of borrowings, support for our $2.25 billion commercial paper program and issuances of letters of credit. This agreement requires that we maintain a debt-to-total capitalization ratio of less than 60%. We were in compliance with this covenant at December 31, 2013. At December 31, 2013, our borrowings under our commercial paper program had a weighted average interest rate of 1.00%, and there were $42 million in outstanding letters of credit under the Credit Agreement.

The following summarizes our availability under the Credit Agreement at December 31, 2013 (dollars in millions):
Facility
$
2,250

Less uses of facility:
 

Revolving credit facility
772

Commercial paper
292

Letters of credit
42

Availability
$
1,144


On May 1, 2013, we entered into a $300 million, 364-day term loan facility with a syndicate of banks. The facility was fully drawn on May 1, 2013 and will mature on April 30, 2014. The terms and conditions of the facility are substantially similar to our $2.25 billion revolving credit agreement. The facility is used for general corporate purposes, including the repayment of other credit facility borrowings and the reduction of outstanding commercial paper.

On April 4, 2012, we completed a $1.3 billion long-term debt offering comprised of $750 million of 4.5% Senior Notes due 2022 and $550 million of 5.95% Senior Notes due 2042. The net proceeds from this offering were used to repay short-term indebtedness under our commercial paper program and for general corporate purposes.
In August 2012, as a result of the delay in filing our second quarter report on Form 10-Q and potential delay in filing our third quarter report on Form 10-Q, we sought consents from the holders of our senior notes to extend the due date under the senior note indentures for providing our Form 10-Q filings and our 2012 Form 10-K filing to no later than March 31, 2013. We received

28


sufficient consents to apply this extension to all series of our publicly traded senior notes. We offered a cash payment of $2.50 for each $1,000 in principal amount for those note holders who consented to the extension and we paid approximately $30 million in connection with this consent solicitation including costs.

Our Standard & Poor’s Ratings Services’ credit rating on our senior unsecured debt is currently BBB- and our short-term rating is A-3, both with a stable outlook. Our Moody’s Investors Ratings Services’ credit rating on our unsecured debt is currently Baa2 and our short-term rating is P-2, both with a negative outlook. We have access and expect we will continue to have access to credit markets, including the U.S. commercial paper market, although the commercial paper amounts outstanding may be reduced as a result of a negative rating change. We expect to utilize the Credit Agreement or other facilities to supplement commercial paper borrowings as needed.

Cash Requirements
During 2014, we anticipate our cash requirements will include payments for working capital needs and capital expenditures, interest payments on our outstanding debt, the repayment of our 364-day term loan facility, payments associated with our settlement agreement with the DOJ and SEC related to the United Nations oil-for-food program governing sales of goods into Iraq and our subsidiaries’ non-compliance with the Foreign Corrupt Practices Act. Our cash requirements may also include opportunistic business acquisitions and an amount to settle the governmental investigations described in “Item 1A.Risk Factors” and “Item 8.Financial Statements and Supplementary Data – Notes to Consolidated Financial Statements – Note 18Disputes, Litigation and Contingencies.” Consistent with 2013, we anticipate funding these requirements from cash generated from operations, availability under our existing or additional credit facilities, the issuance of commercial paper and potential proceeds from disposals of businesses or capital assets that are no longer closely aligned with our core long-term growth strategy. Capital expenditures for 2014 are projected to be approximately 8% of our revenues. 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 2014. Expenditures are expected to be used primarily to support anticipated near-term growth of our core businesses and our sources of liquidity are anticipated to be sufficient to meet our needs. Capital expenditures during 2013 were $1.6 billion.
Cash and cash equivalents of $434 million at December 31, 2013 are held by subsidiaries domiciled outside of Switzerland. Based on the nature of our structure, we are generally able to redeploy cash with no significant incremental tax expense.

Accounts Receivable Factoring

Since 2010, we have entered into an accounts receivable factoring program to sell accounts receivable in Mexico to third party financial institutions. In 2013, we sold $215 million under the program, received cash totaling $204 million and recognized a loss of $3 million on these sales. In 2012, we sold approximately $177 million under the program, received cash totaling $163 million and recognized a loss of $1 million on these sales. In 2011, we sold approximately $65 million under our factoring program, received cash totaling $64 million and recognized a loss of $1 million on these sales. In each of the years, our factoring transactions qualified for sale accounting under U.S. generally accepted accounting principles (“U.S. GAAP”) and proceeds are included in operating cash flows in our Consolidated Statements of Cash Flows.


29


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)
2014
 
2015 and 2016
 
2017 and 2018
 
Thereafter
 
Total
Short-term Debt
$
1,593

 
$

 
$

 
$

 
$
1,593

Long-term Debt (a)
71

 
480

 
1,181

 
5,458

 
7,190

Interest on Long-term Debt
456

 
891

 
782

 
4,075

 
6,204

Noncancellable Operating Leases
277

 
424

 
246

 
270

 
1,217

Purchase Obligations
399

 

 

 

 
399

Government investigations and other litigation obligations
306

 

 

 

 
306

 
$
3,102

 
$
1,795

 
$
2,209

 
$
9,803

 
$
16,909


(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, $410 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 2013, we contributed approximately $12 million towards those plans and we anticipate funding approximately $12 million during 2014. Our projected benefit obligations for our defined benefit pension and other post-retirement benefit plans were $297 million as of December 31, 2013.

Derivative Instruments

Fair Value Hedges

We may use interest rate swaps to help mitigate exposures related to changes in the fair values of the associated debt. Amounts paid or received upon termination of the interest rate swaps accounted for as fair value hedges represent the fair value of the agreements at the time of termination and are amortized as a reduction, in the case of gains, or as an increase, in the case of losses, to interest expense over the remaining term of the debt.

In July 2011, we entered into interest rate swap agreements to pay a variable interest rate and receive a fixed interest rate with an aggregate notional amount of $300 million. These swaps were designed as fair value hedges of our 6.35% senior notes. In June 2012 these swaps were terminated. As a result of these terminations, we received a cash settlement of $18 million. The gain associated with these interest rate swap terminations was deferred and is being amortized over the remaining term of our 6.35% senior notes as a reduction in interest expense.

As of December 31, 2013 and 2012, we had net unamortized gains of $42 million and $52 million, respectively, associated with interest rate swap terminations.

Cash Flow Hedges

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, 2013 and 2012, we had net unamortized losses of $11 million in both years associated with our cash flow hedge terminations.

In August 2011, we entered into interest rate locks with a notional amount of $294 million intended to hedge our projected exposures to interest rates. In October 2011, we terminated a portion of these interest rate locks with a notional value of $235

30


million and realized a gain on settlement of $4 million. We recognized a $5 million loss associated with these instruments in the fourth quarter of 2011.

Other Derivative Instruments

As of December 31, 2013 and 2012, we had foreign currency forward contracts with aggregate notional amounts of $635 million and $990 million, respectively. These contracts were entered into to hedge 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, 2013 and 2012 resulted in a net liability of approximately $1 million and $15 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 in the line captioned “Other, Net” on the accompanying Consolidated Statements of Operations.

We have cross-currency swaps between the U.S. dollar and Canadian dollar to hedge certain exposures to the Canadian dollar. At December 31, 2013 and 2012, we had notional amounts outstanding of $168 million for each year. The total estimated fair value of these contracts at December 31, 2013 and 2012 resulted in a liability of $21 million and $34 million, respectively. These derivative instruments were 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.

Warrants

At December 31, 2010, warrants were outstanding to purchase up to 12.9 million of our shares at a price of $15.00 per share. On March 4, 2011, 4.3 million of these warrants were exercised through net share settlement resulting in the issuance of 1.7 million shares. At December 31, 2011, 8.6 million of these warrants were outstanding and exercisable until February 28, 2012. On February 28, 2012, 4.3 million of these warrants were exercised through physical delivery of shares in exchange for $65 million and the remaining 4.3 million of these warrants were exercised through net share settlement resulting in the issuance of 494 thousand shares.

Off Balance Sheet Arrangements

Guarantees

Weatherford Switzerland is the ultimate parent of the Weatherford group and guarantees the obligations of Weatherford International Ltd., a Bermuda exempted company (“Weatherford Bermuda”), and Weatherford International, LLC, a Delaware limited liability company (“Weatherford Delaware”), noted below.

The following obligations of Weatherford Delaware were guaranteed by Weatherford Bermuda at December 31, 2013, 2012 and 2011: (1) the 6.35% senior notes and (2) 6.80% senior notes. In addition to these obligations, the 5.95% senior notes of Weatherford Delaware were guaranteed by Weatherford Bermuda at December 31, 2011.

The following obligations of Weatherford Bermuda were guaranteed by Weatherford Delaware at December 31, 2013, 2012 and 2011: (1) the 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. In addition to these obligations, the following obligations of Weatherford Bermuda were guaranteed by Weatherford Delaware at December 31, 2012 and 2011: (1) the 4.95% senior notes and (2) 5.15% senior notes. In 2013, we entered into a 364-day term loan facility, which is an obligation of Weatherford Bermuda guaranteed by Weatherford Delaware.

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, 2013, we had $869 million of letters of credit and performance and bid bonds outstanding, consisting of $541 million outstanding under various uncommitted credit facilities, $42 million letters of credit outstanding under our committed facility and $286 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 facilities, our available liquidity would be reduced by the amount called.


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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 and intangible assets acquired in connection with business combinations represent the excess of consideration over the fair value of tangible net assets acquired. Certain assumptions and estimates are employed in determining the fair value of assets acquired, the fair value of liabilities assumed and the allocation of goodwill to the appropriate reporting unit. We had goodwill totaling $3.7 billion at December 31, 2013 and $3.9 billion at December 31, 2012.

We perform an impairment test for goodwill and indefinite-lived intangible assets annually as of October 1, or more frequently if indicators of potential impairment exist. 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. Our reporting units are based on our regional structure and consist of the United States, Canada, Latin America, Europe, SSA, Russia, MENA and Asia Pacific. If the carrying amount of a reporting unit 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 amount of its goodwill by performing a hypothetical purchase price allocation on 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 recorded amount of goodwill, the recorded goodwill is written down to the new amount.
 
The fair values of all our reporting units were in excess of their carrying value as of our October 2013 annual impairment test. The fair value of our Latin America reporting unit was closest to its carrying value and was 21% in excess of its carrying value at October 1, 2013 and our goodwill at December 31, 2013 for Latin America was $345 million.

The fair value of our reporting units is determined using primarily an income approach. Several estimates and judgments are required in the application of this model. The income approach estimates fair value by discounting each reporting unit’s estimated future cash flows using a weighted-average cost of capital that reflects current market conditions and the risk profile of each reporting unit. To arrive at our future cash flows, we use estimates of economic and market information, including growth rates in revenues, costs, estimates of future expected changes in operating margins, tax rates and also cash needs and expenditures.  Other significant estimates and assumptions include terminal value growth rates, future estimates of capital expenditures and changes in future working capital requirements. The risk-adjusted discount rates applied to our future cash flows under the income approach ranged from 10% to 19% in our October 2013 test. The aggregate fair values estimated using primarily the income approach are then reconciled to our market capitalization, taking into account observable control premiums.
 
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 growth rates for periods beyond the financial forecast period. Our estimates of fair value are sensitive to changes in all of these variables, certain of which relate to conditions outside our control. If any one of the above assumptions changes or fails to materialize, the resulting decline in our estimated fair value could result in an impairment charge to goodwill associated with the applicable reporting unit.

Our reporting unit fair values and the resulting impairment conclusions are sensitive to changes in key variables. Should our forecasted 2014 revenue for our respective reporting units decrease by more than 22.5% of the amount projected, the decline experienced by our Latin America reporting unit would result in a fair value that is exceeded by its carrying value. In the event that the applicable discount rates each climb by 50 basis points, we expect that the resulting fair values would exceed our reporting unit carrying values. In the event that the applicable discount rates each climb by 100 basis points, we expect that the resulting fair values would still exceed our reporting unit carrying values.


32


During the second quarter of 2012, we noted a sustained decline in the market price of our registered shares such that our market capitalization was lower than our total shareholders’ equity for an extended period. Additionally, certain of our reporting units were not performing at the levels previously expected. In response, we considered the associated circumstances to assess whether an event or change occurred that, more likely than not, reduced the fair value of any of our reporting units below their carrying amount. After considering the relevant circumstances, we concluded that the decline in our market capitalization was a potential indicator of impairment and we prepared the analysis necessary to identify potential impairment through the comparison of reporting unit fair values and carrying amounts. This “step one” analysis indicated that the goodwill attributed to our MENA and SSA reporting units was potentially impaired. Consequently, we performed the “step two” analysis of the goodwill impairment test, comparing the implied fair value of reporting unit goodwill with the carrying amount of that goodwill. The “step two” analysis indicated that the goodwill for both reporting units was fully impaired and we recognized an impairment loss of $589 million in the second quarter, of which $512 million was attributable to MENA and $77 million to SSA.

Long-Lived Assets
 
Long-lived assets, which include property, plant and equipment and definite-lived intangibles, comprise a significant amount of our assets. In accounting for long-lived assets, we must make estimates about the expected useful lives of the assets and the potential for impairment based on the fair value of the assets and the cash flows they are expected to generate. 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:
 
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 potential impairment 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 change in industry conditions or a reduction in cash flows 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 significant estimates based upon historical experience and future expectations such as budgets and internal projections. If the undiscounted cash flows do not exceed the carrying value of the long-lived asset, an impairment has occurred, and we recognize a loss for the difference between the carrying amount and 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 generally discounted at an interest rate commensurate with our weighted average cost of capital for a similar asset.
 
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.

33



Measurements of progress are generally based on costs incurred to date as a percentage of total estimated costs or output based 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 “Risk Factors.”

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. 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 have a variety of unapproved contract change orders or claims that are not included in our revenues as of December 31, 2013. Amounts representing these contract change orders or claims are included in revenue only when they can be estimated reliably and their realization is reasonably assured.

During 2012, we recognized losses of $100 million related to a long-term construction contract in Iraq accounted for under the percentage of completion method. As of December 31, 2012, we had claims against our customer of $68 million that were not included in our revenue estimates because they do not meet the criteria for recognition. Additionally, we had accrued $17 million for liquidated damages that we are contractually obligated to pay as a result of delays in the expected completion of the project. In addition, in the quarter ended December 31, 2012, we recognized $63 million in revenue upon revision of project estimates on our projects in Mexico. These amounts were determined to be realizable in the fourth quarter of 2012.

 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.

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 provisions for income taxes for 2013, 2012 and 2011 were $144 million, $462 million and $542 million, 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, 2013, we had recorded reserves for uncertain tax positions of $289 million, excluding accrued interest and penalties of $121 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.


34


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 or future deductibility is not probable. 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 identified 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, 2013, our gross deferred tax assets were $1.2 billion before a related valuation allowance of $571 million. As of December 31, 2012, our gross deferred tax assets were $976 million before a related valuation allowance of $317 million. Our results in 2013 and 2012 include significant operating losses in Iraq upon which we recorded a valuation allowance of $134 million and $72 million, respectively.
 
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, 2013 and 2012, the allowance for doubtful accounts totaled $114 million, or 3%, and $84 million, or 2%, of total gross accounts receivable, respectively. 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 2013.

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, 2013 and 2012, inventory reserves totaled $87 million, or 3%, and $88 million, or 2%, of gross inventory, respectively. During 2013, we recognized a charge for excess and obsolete inventory of $62 million ($0.08 per share) attributable to each reporting segment as follows: $35 million for North America, $7 million for MENA/Asia Pacific, $13 million for Europe/SSA/Russia and $7 million for Latin America. During 2012, we recognized a charge for excess and obsolete inventory of $53 million ($0.07 per share) attributable to each reporting segment as follows: $21 million for North America, $16 million for MENA/Asia Pacific, $11 million for Europe/SSA/Russia and $5 million for Latin America. We believe that our reserves are adequate to properly value potential excess, slow-moving and obsolete inventory under current conditions.
 

35


Disputes, Litigation and Contingencies

As of December 31, 2013, 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 Data – Notes to Consolidated Financial Statements – Note 18Disputes, Litigation and Contingencies.”

For a more comprehensive list of our accounting policies, see “Item 8.Financial Statements and Supplementary Data – Notes to Consolidated Financial Statements – Note 1Summary of Significant Accounting Policies.”

New Accounting Pronouncements
 
In February 2013, the Financial Accounting Standards Board (“FASB”) issued new guidance intended to improve the reporting of reclassifications out of accumulated other comprehensive income. The guidance requires an entity to report the effect of significant reclassifications out of accumulated other comprehensive income on the respective line items in net income if the amount being reclassified is required under U.S. GAAP to be reclassified in its entirety to net income. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety from accumulated other comprehensive income to net income in the same reporting period, an entity is required to cross-reference other disclosures required under U.S. GAAP that provide additional detail about those amounts. This guidance became effective for us in our second quarter of 2013. Please see “Item 8.Financial Statements and Supplementary Data – Notes to Consolidated Financial Statements – Note 14 Shareholders' Equity”, which presents the reclassifications out of Accumulated Other Comprehensive Income.

In July 2013, the FASB issued new guidance intended to clarify the presentation of unrecognized tax benefits. An unrecognized tax benefit, or a portion of an unrecognized tax benefit, should be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carry forward, a similar tax loss or a tax credit carryforward, with certain exceptions. The unrecognized tax benefit should be presented as a liability and should not be combined with deferred tax assets to the extent that: (1) the deferred tax asset is not available under the tax law of the applicable jurisdiction to settle additional income taxes resulting from disallowance of the tax position, or (2) the entity is not required to use the deferred tax asset under the tax law of the applicable jurisdiction and the entity does not intend to use the deferred tax asset to offset additional taxes that would result from disallowance of the position. This guidance will be effective for us beginning with the first quarter of 2014 and may be adopted prospectively for all unrecognized tax benefits that exist at the effective date or retrospectively. The adoption of this guidance is not expected to have a material impact on our financial position, results of operations or cash flows.

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

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.
 
In January 2010, the Venezuelan government announced its intention to devalue its currency and move to a two-tier exchange structure. The official exchange rate moved from 2.15 per dollar to 2.60 per dollar for essential goods and from 2.15 per dollar to 4.30 per dollar for non-essential goods and services. Our Venezuelan entities maintain the U.S. dollar as their functional currency. In connection with this devaluation, we incurred a charge of $64 million for the remeasurement of our net monetary assets denominated in Venezuelan bolivars at the date of the devaluation, which was not tax deductible in Venezuela. We also recorded a $24 million tax benefit for local Venezuelan income tax purposes related to our net U.S. dollar-denominated monetary liability

36


position in the country. Effective January 1, 2011, the Venezuelan government again modified the fixed rate of exchange, eliminating the two-tier structure and establishing 4.30 per dollar as the official exchange rate for all goods and services. This modification did not have a material impact to our financial position or results of operations. On February 8, 2013, the Venezuelan government announced its intention to further devalue its currency effective February 13, 2013 at which time the official exchange rate moved from 4.30 per dollar to 6.30 per dollar for all goods and services. In connection with this devaluation, we recognized a charge of $100 million for the remeasurement of our net monetary assets denominated in the Venezuelan bolivar at the date of the devaluation. We also recorded a $6 million benefit for Venezuelan income tax purposes related to our net U.S. dollar determined tax liability in the country. As of December 31, 2013, we had a net monetary asset position denominated in Venezuelan bolivars of approximately $238 million, comprised primarily of accounts receivable and current liabilities. We are continuing to explore opportunities to reduce our exposure, but should devaluation occur in the future, we may be required to take further charges related to the remeasurement of our net monetary asset position.

Assets and liabilities of entities for which the functional currency is the local currency are translated into U.S. dollars using the exchange rates in effect at the balance sheet date, resulting in translation adjustments that are reflected in accumulated other comprehensive income (loss) in the shareholders’ equity section on our consolidated balance sheets. A portion of our net assets are impacted by changes in foreign currencies in relation to the U.S. dollar. We recorded a $316 million adjustment to decrease shareholders’ equity for 2013 to reflect the change in the U.S. dollar against various foreign currencies.
 
As of December 31, 2013 and 2012, we had foreign currency forward contracts with aggregate notional amounts of $635 million and $990 million, 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, 2013 and 2012 resulted in a net liability of approximately $1 million and $15 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.

We have cross-currency swaps between the U.S. dollar and Canadian dollar to hedge certain exposures to the Canadian dollar. At December 31, 2013 and 2012, we had notional amounts outstanding of $168 million for each year. The estimated fair value of these contracts at December 31, 2013 and 2012 resulted in a liability of $21 million and $34 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.

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, where the interest rate fluctuates periodically, exposes us to short-term changes in market interest rates. Fixed rate debt, where the interest rate is fixed over the life of the instrument, 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 as interest rates change.
 
Our long-term borrowings that were outstanding at December 31, 2013 and 2012, and that were subject to interest rate risk consist of the following:

37


 
 
 
December 31,
 
 
2013
 
2012
(Dollars in millions)
 
Carrying
Amount
 
Fair
Value
 
Carrying Amount
 
Fair
Value
5.15% Senior Notes due 2013
 
$

 
$

 
$
294

 
$
296

4.95% Senior Notes due 2013
 

 

 
250

 
258

5.50% Senior Notes due 2016
 
353

 
378

 
354

 
380

6.35% Senior Notes due 2017
 
610

 
682

 
613

 
690

6.00% Senior Notes due 2018
 
498

 
557

 
497

 
570

9.625% Senior Notes due 2019
 
1,021

 
1,290

 
1,025

 
1,307

5.125% Senior Notes due 2020
 
798

 
856

 
797

 
875

4.50% Senior Notes due 2022
 
747

 
754

 
747

 
794

6.50% Senior Notes due 2036
 
595

 
629

 
595

 
645

6.80% Senior Notes due 2037
 
298

 
325

 
298

 
339

7.00% Senior Notes due 2038
 
497

 
556

 
497

 
564

9.875% Senior Notes due 2039
 
247

 
350

 
247

 
370

6.75% Senior Notes due 2040
 
596

 
646

 
596

 
680

5.95% Senior Notes due 2042
 
545

 
557

 
545

 
600


We have various other long-term debt instruments of $329 million at December 31, 2013, 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 $1.6 billion at December 31, 2013 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, 2013, interest expense for 2014 would increase by approximately $16 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 and are amortized as a reduction, in the case of gains, or an increase, in the case of losses, to interest expense over the remaining term of the debt.
 
In July 2011, we entered into interest rate swap agreements to pay a variable interest rate and receive a fixed interest rate with an aggregate notional amount of $300 million. These agreements were designed as fair value hedges of our 6.35% senior notes. In June 2012 these swaps were terminated. As a result of these terminations, we received a cash settlement of $18 million. The gain associated with these interest rate swap terminations was deferred and is being amortized over the remaining term of our 6.35% senior notes as a reduction in interest expense.

In August 2011, we entered into interest rate locks with a notional amount of $294 million intended to hedge our projected exposures to interest rates. In October 2011, we terminated a portion of these interest rate locks with a notional value of $235 million and realized a gain on settlement of $4 million. We recognized a $5 million loss associated with these instruments in the fourth quarter of 2011.
 
As of December 31, 2013 and 2012, we had net unamortized gains of $42 million and $52 million, respectively, associated with interest rate swap terminations.


38


Item 8. Financial Statements and Supplementary Data

INDEX TO FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULE



39


Report of Independent Registered Public Accounting Firm


The Board of Directors and Shareholders
Weatherford International Ltd. and Subsidiaries:

We have audited the accompanying consolidated balance sheet of Weatherford International Ltd. and subsidiaries as of December 31, 2013, and the related consolidated statements of operations, comprehensive income (loss), shareholders’ equity, and cash flows for the year ended December 31, 2013. In connection with our audit of the consolidated financial statements, we also have audited financial statement schedule II for the year ended December 31, 2013. 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 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 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 audit provides 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 Ltd. and subsidiaries as of December 31, 2013 and the results of their operations and their cash flows for the year ended December 31, 2013, in conformity with U.S. generally accepted accounting principles. Also in our opinion, the related financial statement schedule for the year ended December 31, 2013, 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 Ltd.’s internal control over financial reporting as of December 31, 2013, based on criteria established in Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated February 25, 2014 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.


/s/ KPMG LLP


Houston, Texas
February 25, 2014


40


Report of Independent Registered Public Accounting Firm


The Board of Directors and Shareholders
Weatherford International Ltd. and Subsidiaries:

We have audited Weatherford International Ltd.’s internal control over financial reporting as of December 31, 2013, based on criteria established in Internal Control - Integrated Framework (1992) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Weatherford International Ltd.’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 Ltd. maintained, in all material respects, effective internal control over financial reporting as of December 31, 2013, based on criteria established in Internal Control - Integrated Framework (1992) 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 sheet of Weatherford International Ltd. and subsidiaries as of December 31, 2013, and the related consolidated statements of operations, comprehensive income (loss), shareholders’ equity, and cash flows for the year ended December 31, 2013, and our report dated February 25, 2014 expressed an unqualified opinion on those consolidated financial statements.



/s/ KPMG LLP

Houston, Texas
February 25, 2014


41


Report of Independent Registered Public Accounting Firm

The Board of Directors and Shareholders of Weatherford International Ltd. and Subsidiaries

We have audited the accompanying consolidated balance sheet of Weatherford International Ltd. and Subsidiaries (the “Company”) as of December 31, 2012, and the related consolidated statements of operations, comprehensive income (loss), shareholders’ equity, and cash flows for each of the two years in the period then ended. Our audits also included the financial statement schedule for each of the two years in the period ended December 31, 2012 listed in the Index at Item 15(a). These financial statements and schedule are the responsibility of the Company’s Board of Directors and management. Our responsibility is to express an opinion on these financial statements and 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 financial statements referred to above present fairly, in all material respects, the consolidated financial position of the Company as of December 31, 2012, and the consolidated results of its operations and its cash flows for each of the two years in the period then ended in conformity with U.S. generally accepted accounting principles. Also, in our opinion, the related financial statement schedule, when considered in relation to the basic financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.



/s/ Ernst & Young LLP


Houston, Texas
March 4, 2013


42


WEATHERFORD INTERNATIONAL LTD. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
 
December 31,
(Dollars and shares in millions, except par value)
2013
 
2012
Current Assets:
 
 
 
Cash and Cash Equivalents
$
435

 
$
300

Accounts Receivable, Net of Allowance for Uncollectible Accounts of $114 in 2013 and $84 in 2012
3,594

 
3,885

Inventories, Net
3,371

 
3,675

Deferred Tax Assets
309

 
376

Other Current Assets
1,065

 
793

Total Current Assets
8,774

 
9,029

 
 
 
 
Property, Plant and Equipment:
 

 
 

Land, Buildings and Leasehold Improvements
1,860

 
1,714

Rental and Service Equipment
10,869

 
10,208

Machinery and Other
2,547

 
2,407

 
15,276

 
14,329

Less: Accumulated Depreciation
6,908

 
6,030

 
8,368

 
8,299

 
 
 
 
Goodwill
3,709

 
3,871

Other Intangible Assets, Net
626

 
766

Equity Investments
296

 
646

Other Non-current Assets
204

 
184

Total Assets
$
21,977

 
$
22,795

 
 
 
 
Current Liabilities:
 

 
 

Short-term Borrowings and Current Portion of Long-term Debt
$
1,666

 
$
1,585

Accounts Payable
2,091

 
2,108

Accrued Salaries and Benefits
472

 
490

Billings in Excess of Costs and Estimated Earnings
127

 
281

Income Taxes Payable
183

 
167

Other Current Liabilities
1,160

 
1,079

Total Current Liabilities
5,699

 
5,710

 
 
 
 
Long-term Debt
7,061

 
7,049

Other Non-current Liabilities
1,014

 
1,218

Total Liabilities
13,774

 
13,977

 
 
 
 
Shareholders’ Equity:
 

 
 

Shares - Par Value 1.16 Swiss Francs; Authorized 840 shares, Conditionally Authorized 372 shares, Issued 840 shares at December 31, 2013 and 2012, Outstanding 767 shares and 761 shares at December 31, 2013 and 2012, respectively.
775

 
775

Capital in Excess of Par Value
4,600

 
4,674

Treasury Shares, 73 shares and 79 shares, at cost, at December 31, 2013 and 2012, respectively.
(37
)
 
(182
)
 Retained Earnings
3,011

 
3,356

Accumulated Other Comprehensive Income
(187
)
 
163

Weatherford Shareholders’ Equity
8,162

 
8,786

Noncontrolling Interests
41

 
32

Total Shareholders’ Equity
8,203

 
8,818

Total Liabilities and Shareholders’ Equity
$
21,977

 
$
22,795

 

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

43


WEATHERFORD INTERNATIONAL LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS

 
Year Ended December 31,
 (Dollars and shares in millions, except per share amounts)
2013
 
2012
 
2011
Revenues:
 
 
 
 
 
Products
$
6,007

 
$
6,024

 
$
4,884

Services
9,256

 
9,191

 
8,104

 
15,263

 
15,215

 
12,988

 
 
 
 
 
 
Costs and Expenses:
 

 
 

 
 

Cost of Products
4,480

 
4,693

 
3,742

Cost of Services
7,822

 
7,162

 
5,936

Research and Development
265

 
257

 
245

Selling, General and Administrative Attributable to Segments
1,728

 
1,585

 
1,532

Corporate General and Administrative
316

 
355

 
226

Goodwill and Equity Investment Impairment

 
793

 

U.S. Government Investigation Loss
153

 
100

 

Gain on Sale of Businesses
(24
)
 
(28
)
 

 
14,740

 
14,917

 
11,681

 
 
 
 
 
 
Operating Income
523

 
298

 
1,307

Other Income (Expense):
 

 
 

 
 

Interest Expense, Net
(516
)
 
(486
)
 
(453
)
Devaluation of Venezuelan Bolivar
(100
)
 

 

Other, Net
(77
)
 
(100
)
 
(107
)
 
 
 
 
 
 
Income (Loss) Before Income Taxes
(170
)
 
(288
)
 
747

Provision for Income Taxes
(144
)
 
(462
)
 
(542
)
Net Income (Loss)
(314
)
 
(750
)
 
205

Net Income Attributable to Noncontrolling Interests
(31
)
 
(28
)
 
(16
)
Net Income (Loss) Attributable to Weatherford
$
(345
)
 
$
(778
)
 
$
189

 
 
 
 
 
 
Earnings (Loss) Per Share Attributable To Weatherford:
 

 
 

 
 

Basic
$
(0.45
)
 
$
(1.02
)
 
$
0.25

Diluted
$
(0.45
)
 
$
(1.02
)
 
$
0.25

 
 
 
 
 
 
Weighted Average Shares Outstanding:
 

 
 

 
 

Basic
772

 
765

 
753

Diluted
772

 
765

 
760



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

44


WEATHERFORD INTERNATIONAL LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

 
Year Ended December 31,
(Dollars in millions)
2013
 
2012
 
2011
Net Income (Loss)
$
(314
)
 
$
(750
)
 
$
205

Other Comprehensive Income (Loss), Net of Tax:
 
 
 
 
 
Foreign Currency Translation
(353
)
 
86

 
(118
)
Defined Benefit Pension Activity
2

 
(4
)
 
(5
)
Other
1

 
1

 
1

Other Comprehensive Income (Loss)
(350
)
 
83

 
(122
)
Comprehensive Income (Loss)
(664
)
 
(667
)
 
83

Comprehensive Income (Loss) Attributable to Noncontrolling Interests
(31
)
 
(28
)
 
(16
)
Comprehensive Income (Loss) Attributable to Weatherford
$
(695
)
 
$
(695
)
 
$
67


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

45


WEATHERFORD INTERNATIONAL LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY

(Dollars in millions)
Par Value of Issued Shares
 
Capital In Excess of Par Value
 
Retained Earnings
 
Accumulated
Other
Comprehensive
Income (Loss)
 
Treasury Shares
 
Non-controlling Interests
 
Total Shareholders’ Equity
Balance at December 31, 2010
$
761

 
$
4,617

 
$
3,949

 
$
202

 
$
(478
)
 
$
67

 
$
9,118

 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net Income

 

 
189

 

 

 
16

 
205

Other Comprehensive Loss

 

 

 
(122
)
 

 

 
(122
)
Dividends Paid to Noncontrolling Interests

 

 

 

 

 
(29
)
 
(29
)
Shares Issued for Acquisitions
6

 
63

 

 

 
65

 

 
134

Equity Awards Granted, Vested and Exercised

 
(7
)
 

 

 
79

 

 
72

Excess Tax Benefits of Share-based Compensation Plans

 
4

 

 

 

 

 
4

Deconsolidation of Joint Ventures

 

 
(4
)
 

 

 
(34
)
 
(38
)
Other
2

 
(2
)
 

 

 

 
1

 
1

Balance at December 31, 2011
769

 
4,675

 
4,134

 
80

 
(334
)
 
21

 
9,345

 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net Income (Loss)

 

 
(778
)
 

 

 
28

 
(750
)
Other Comprehensive Income

 

 

 
83

 

 

 
83

Dividends Paid to Noncontrolling Interests

 

 

 

 

 
(21
)
 
(21
)
Shares Issued for Acquisitions

 
(27
)
 

 

 
66

 

 
39

Equity Awards Granted, Vested and Exercised

 
(22
)
 

 

 
86

 

 
64

Excess Tax Benefit of Share-Based Compensation Plans

 
(3
)
 

 

 

 

 
(3
)
Exercise of Warrants
6

 
59

 

 

 

 

 
65

Other

 
(8
)
 

 

 

 
4

 
(4
)
Balance at December 31, 2012
775

 
4,674

 
3,356

 
163

 
(182
)
 
32

 
8,818

 
 
 
 
 
 
 
 
 
 
 
 
 
 
Net Income (Loss)

 

 
(345
)
 

 

 
31

 
(314
)
Other Comprehensive Loss

 

 

 
(350
)
 

 

 
(350
)
Dividends Paid to Noncontrolling Interests

 

 

 

 

 
(27
)
 
(27
)
Equity Awards Granted, Vested and Exercised

 
(68
)
 

 

 
145

 

 
77

Excess Tax Benefit of Share-Based Compensation Plans

 
(1
)
 

 

 

 

 
(1
)
Other

 
(5
)
 

 

 

 
5

 

Balance at December 31, 2013
$
775

 
$
4,600

 
$
3,011

 
$
(187
)
 
$
(37
)
 
$
41

 
$
8,203


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

46


WEATHERFORD INTERNATIONAL LTD. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
 
Year Ended December 31,
(Dollars in millions)
2013
 
2012
 
2011
Cash Flows From Operating Activities:
 
 
 
 
 
Net Income (Loss)
$
(314
)
 
$
(750
)
 
$
205

Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities:
 
 
 
 
 
Depreciation and Amortization
1,402

 
1,282

 
1,136

Goodwill and Equity Investment Impairment

 
793

 

U.S. Government Investigation Loss
153

 
100

 

Employee Share-Based Compensation Expense
66

 
76

 
87

Bad Debt Expense
102

 
22

 
52

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

 
(9
)
 
29

Deferred Income Tax Provision (Benefit)
(33
)
 
(13
)
 
121

Excess Tax Benefits from Share-Based Compensation
1

 
(1
)
 
(4
)
Devaluation of Venezuelan Bolivar
100

 

 

Other, Net
10

 
43

 
(19
)
Change in Operating Assets and Liabilities, Net of Effect of Businesses Acquired:
 
 
 
 
 
Accounts Receivable
(12
)
 
(705
)
 
(623
)
Inventories
129

 
(738
)
 
(606
)
Other Current Assets
(65
)
 
(231
)
 
(81
)
Accounts Payable
69

 
543

 
242

Billings in Excess of Costs and Estimated Earnings
(154
)
 
255

 
29

Other Current Liabilities
(185
)
 
452

 
202

Other, Net
(46
)
 
102

 
82

Net Cash Provided by Operating Activities
1,229

 
1,221

 
852

 
 
 
 
 
 
Cash Flows from Investing Activities:
 

 
 

 
 

Capital Expenditures for Property, Plant and Equipment
(1,575
)
 
(2,177
)
 
(1,524
)
Acquisitions of Businesses, Net of Cash Acquired
(8
)
 
(165
)
 
(144
)
Acquisition of Intellectual Property
(9
)
 
(17
)
 
(8
)
Acquisition of Equity Investments in Unconsolidated Affiliates

 
(8
)
 
(14
)
Proceeds from Sale of Assets and Businesses, Net
488

 
61

 
31

Other Investing Activities

 

 
(15
)
Net Cash Used by Investing Activities
(1,104
)
 
(2,306
)
 
(1,674
)
 
 
 
 
 
 
Cash Flows From Financing Activities:
 

 
 

 
 

Borrowings of Long-term Debt
3

 
1,313

 
22

Repayments of Long-term Debt
(603
)
 
(310
)
 
(216
)
Borrowings (Repayments) of Short-term Debt, Net
612

 
(13
)
 
992

Proceeds from Exercise of Warrants