UNITED STATES 
SECURITIES AND EXCHANGE COMMISSION 
Washington, D.C. 20549
 
FORM 8-K
 
CURRENT REPORT 
Pursuant to Section 13 or 15(d) of
The Securities Exchange Act of 1934
 
Date of Report (Date of earliest event reported): December 4, 2017
 
BAKER HUGHES, A GE COMPANY	BAKER HUGHES, A GE COMPANY, LLC	

(Exact name of registrant as specified in its charter)
 
Delaware	1-38143	81-4403168	Delaware	1-09397	76-0207995	
(State of Incorporation)	(Commission File No.)	(I.R.S. Employer
Identification No.)	(State of Incorporation)	(Commission File No.)	(I.R.S. Employer
Identification No.)	
 	
17021 Aldine Westfield Road
Houston, Texas 77073
  
Registrant’s telephone number, including area code: (713) 439-8600
 
(former name or former address, if changed since last report)
 
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
 
 	☐	Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)	
 	☐	Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)	
 	☐	Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))	
 	☐	Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))	
 
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
 
Emerging growth company ☐
 
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

 

Item 7.01. Regulation FD Disclosure

On December 4, 2017, Baker Hughes, a GE company, LLC, a Delaware limited liability company (the “Company,” “we” or “our”) distributed a confidential preliminary offering memorandum relating to a proposed offering of new senior notes to be offered and sold only to persons reasonably believed to be qualified institutional buyers pursuant to Rule 144A under the U.S. Securities Act of 1933, as amended (the “Securities Act”), and to certain non-U.S. persons pursuant to Regulation S under the Securities Act.  The new senior notes will not be registered under the Securities Act, or the securities laws of any state or other jurisdiction, and, unless so registered, may not be offered or sold in the United States absent registration or an applicable exemption from the registration requirements of the Securities Act and applicable state securities laws.

This Current Report on Form 8-K (“Current Report”) does not constitute an offer to sell or the solicitation of an offer to buy any securities and shall not constitute an offer, solicitation or sale in any state or jurisdiction in which, or to any person to whom, such offer, solicitation or sale is unlawful.

As provided in General Instruction B.2 of Form 8-K, the information in this Item 7.01 shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, nor shall they be deemed to be incorporated by reference in any filing under the Securities Act of 1933, as amended, except as shall be expressly set forth by specific reference in such a filing.

Item 8.01. Other Events

On July 3, 2017, we closed our previously announced business combination (the “Transactions”) to combine the oil and gas business (“GE O&G”) of General Electric Company (“GE”) and Baker Hughes Incorporated (“BHI”), creating a fullstream oilfield technology provider that has a unique mix of integrated oilfield products, services and digital solutions.  In connection with the Transactions, we entered into and are governed by an Amended & Restated Operating Agreement, dated as of July 3, 2017 (the “Agreement”).  Under the Agreement, EHHC Newco, LLC (“EHHC”), a wholly owned subsidiary of Baker Hughes, a GE company (“BHGE”), is our sole managing member and BHGE is the sole managing member of EHHC and the holding company of the combined businesses.  The Transactions were executed using a partnership structure, pursuant to which GE O&G and BHI each contributed their operating assets to the Company.  GE holds an approximate 62.5% controlling interest in us and former BHI shareholders hold an approximate 37.5% interest through the ownership of 100% of the Class A Common Stock of BHGE.  GE’s interest is held through a voting interest of Class B Common Stock in BHGE and its economic interest through a corresponding number of our Common Units.  The Transactions were treated as a “reverse acquisition” for accounting purposes and, as such, the historical financial statements of the accounting acquirer, GE O&G, are the historical financial statements of the Company.

Following the Transactions, we revised our segment structure and began to manage and report our operating results through four operating segments as defined below.

 	·	Oilfield Services:  Oilfield Services provides equipment and services ranging from well evaluation to decommissioning.  Products and services include diamond and tri-cone drill bits, drilling services (including directional drilling technology, measurement while drilling & logging while drilling), downhole completion tools and systems, wellbore intervention tools and services, wireline services, drilling and completions fluids, oilfield and industrial chemicals, pressure pumping, and artificial lift technologies (including electrical submersible pumps).	
 
 	·	Oilfield Equipment:  Oilfield Equipment provides a broad portfolio of products and services required to facilitate the safe and reliable flow of hydrocarbons from the subsea wellhead to the surface.  Products and services include pressure control equipment and services, subsea production systems and services, drilling equipment, and flexible pipeline systems.  Oilfield Equipment operation designs and manufactures onshore and offshore drilling and production systems and equipment for floating production platforms and provides a full range of services related to onshore and offshore drilling activities.	
 
 	·	Turbomachinery & Process Solutions:  Turbomachinery & Process Solutions provides equipment and related services for mechanical-drive, compression and power-generation applications across the oil and gas industry as well as products and services to serve the downstream segments of the industry including refining, petrochemical, distributed gas, flow and process control and other industrial applications.  The Turbomachinery & Process Solutions portfolio includes drivers (aeroderivative gas turbines, heavy-duty gas turbines and synchronous and induction electric motors), compressors (centrifugal and axial, direct drive high speed, integrated, subsea compressors, turbo expanders and reciprocating), turn-key solutions (industrial modules and waste heat recovery), pumps, valves, and compressed natural gas (CNG) and small-scale liquefied natural gas (LNG) solutions used primarily for shale oil and gas field development.	

 
 	·	Digital Solutions:  Digital Solutions provides equipment and services for a wide range of industries, including oil & gas, power generation, aerospace, metals, and transportation.  The offerings include sensor-based measurement, nondestructive testing and inspection, turbine, generator and plant controls and condition monitoring, as well as pipeline integrity solutions.	
 
In addition, following the Transactions, we changed the presentation of the statement of income (loss) and statement of cash flows in our financial statements as we believe that the new presentation is a more appropriate presentation of the combined businesses.

The exhibits included as Exhibit 99.1, Exhibit 99.2 and Exhibit 99.3 hereto revise the following information included in the BHI definitive proxy statement/prospectus (“Proxy Statement/Prospectus”) filed on May 30, 2017 with the Securities and Exchange Commission (“SEC”) to reflect the change in segment reporting and new presentation of the statement of income (loss) and statement of cash flows:

 	·	“Business— GE O&G Business,”	

 	·	“Management’s Discussion and Analysis of Financial Condition and Results of Operations of GE O&G”; and	

 	·	“Audited Combined Financial Statements of GE Oil and Gas for the years ended December 31, 2016, 2015, and 2014.”	

The presentation of the historical financial information and related disclosure in this Current Report is consistent with the segment reporting structure and new income statement and cash flow presentations set forth in the Company’s Quarterly Report on Form 10-Q filed for the quarterly period ended September 30, 2017.

The information included in Exhibits 99.1, 99.2 and 99.3 has been revised only to reflect the reporting and presentation changes described above and has not otherwise been updated or revised to reflect events or changes occurring after the date of the Proxy Statement/Prospectus.  This information should be read in conjunction with our other SEC filings.

The Company is also filing with this Current Report as Exhibit 99.4 unaudited pro forma condensed combined statements of income (loss) of Baker Hughes, a GE company, LLC for the nine-month period ended September 30, 2017 and for the year ended December 31, 2016.  Exhibit 99.4 hereto updates the unaudited pro forma condensed combined statements of income (loss) for Baker Hughes, a GE company, LLC previously filed by the Company with the SEC on September 19, 2017 as Exhibit 99.1 to the Company’s Current Report on Form 8-K/A.  Exhibit 99.4 hereto includes updates to the total purchase consideration and the estimates of fair value of assets acquired and liabilities assumed.  In addition, the unaudited pro forma condensed combined statement of income (loss) of the Company for the year ended December 31, 2016 included in Exhibit 99.4 hereto has been updated to reflect the new income statement presentation and more recent available information.  Exhibit 99.4 does not update the previously filed unaudited pro forma financial statements of Baker Hughes, a GE company.

Item 9.01. Financial Statements and Exhibits.
 
     (d) Exhibits.

 	 	 	
Exhibit No.	 	Description	
Exhibit 99.1	 	Revised Description of GE O&G Business	
Exhibit 99.2	 	Revised Management’s Discussion and Analysis of Financial Condition and Results of Operations of GE O&G	
Exhibit 99.3	 	Revised Audited Combined Financial Statements of GE Oil and Gas for the years ended December 31, 2016, 2015, and 2014	
Exhibit 99.4	 	Unaudited pro forma condensed combined statements of income (loss) of for the nine-month period ended September 30, 2017 and for the fiscal year ended December 31, 2016.	

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

 	BAKER HUGHES, A GE COMPANY	 	

Dated:  December 4, 2017	By:	/s/ Lee Whitley	 	
 	 	Lee Whitley
Corporate Secretary	 	

 	BAKER HUGHES, A GE COMPANY, LLC	 	

Dated:  December 4, 2017	By:	/s/ Lee Whitley	 	
 	 	Lee Whitley
Corporate Secretary	 	

 

 
EXHIBIT INDEX

Exhibit No.	 	Description	
Exhibit 99.1	 	Revised Description of GE O&G Business	
Exhibit 99.2	 	Revised Management’s Discussion and Analysis of Financial Condition and Results of Operations of GE O&G	
Exhibit 99.3	 	Revised Audited Combined Financial Statements of GE Oil and Gas for the years ended December 31, 2016, 2015, and 2014	
Exhibit 99.4	 	Unaudited pro forma condensed combined statements of income (loss) for the nine-month period ended September 30, 2017 and for the fiscal year ended December 31, 2016.	

 

 

 
Exhibit 99.1

GE O&G Business

Baker Hughes, a GE company, LLC, a Delaware limited liability company (the Company, BHGE LLC, we, us, or our) and the successor to Baker Hughes Incorporated, a Delaware corporation (Baker Hughes) is a fullstream oilfield technology provider that has a unique mix of equipment and service capabilities. On July 3, 2017, we closed our previously announced business combination (the Transactions) to combine the oil and gas business (GE O&G) of General Electric Company (GE) and Baker Hughes. In connection with the Transactions, we entered into and are governed by an Amended & Restated Operating Agreement, dated as of July 3, 2017 (the BHGE LLC Agreement). Under the BHGE LLC Agreement, EHHC Newco, LLC (EHHC), a wholly owned subsidiary of Baker Hughes, a GE company (BHGE), is our sole managing member and BHGE is the sole managing member of EHHC. As our managing member, EHHC conducts, directs and exercises full control over all our activities, including our day-to-day business affairs and decision-making, without the approval of any other member. As such, EHHC is responsible for all our operational and administrative decisions and the day-to-day management of our business. GE owns approximately 62.5% of our common units and BHGE owns approximately 37.5% of our common units indirectly through two wholly owned subsidiaries.
The Transactions were treated as a “reverse acquisition” for accounting purposes and, as such, the historical financial statements of the accounting acquirer, GE O&G, are the historical financial statements of the Company.  The Company’s financial statements have been prepared on a consolidated basis, effective July 3, 2017. For all periods prior to July 3, 2017, the Company’s financial statements were prepared on a combined basis. The combined financial statements included in Exhibit 99.3 to this Current Report on Form 8-K combine certain accounts of GE and its subsidiaries that were historically managed as part of its Oil & Gas business. The historical financial results in the combined financial statements presented may not be indicative of the results that would have been achieved had GE O&G operated as a separate, stand-alone entity during those periods. The GE O&G numbers in the combined statements of income (loss) and statements of cash flows have been reclassified to conform to the presentation included in BHGE LLC’s Quarterly Report on Form 10-Q for the period ended September 30, 2017. We believe that the reclassified presentation is a more appropriate presentation of the combined businesses.
The following description of GE O&G was included in the definitive proxy statement/prospectus (Proxy Statement/Prospectus) filed by Baker Hughes on May 30, 2017 and has been recast to reflect a change in segment reporting following the Transactions.  The description below is limited to GE O&G’s business as of the date of the Proxy Statement/Prospectus and does not include disclosure on Baker Hughes, except as specifically noted.  The information included below has been revised only to reflect the reporting changes described above and has not otherwise been updated or revised to reflect events or changes occurring after the date of the Proxy Statement/Prospectus. This information should be read in conjunction with BHGE LLC’s SEC filings. Following the Transactions, the majority of the legacy Baker Hughes business is included in the Oilfield Services segment, with a small component included in the Digital Services segment.

GE O&G offers its customers a leading portfolio of advanced technology and optimization support. GE O&G is active in all segments of the oil and gas industry: upstream to downstream, greenfield to brownfield, and onshore and offshore segments. GE O&G also delivers pipeline integrity solutions, a wide range of sensing, inspection and monitoring technologies and industrial power generation and compression solutions for the midstream liquefied natural gas and pipeline segments and the downstream refining and petro-chemical segments. GE O&G endeavors to continuously improve oil and gas industry performance, output and productivity.
GE O&G offers its solutions through four segments: Oilfield Services (OFS); Oilfield Equipment (OES); Turbomachinery & Process Solutions (TPS); and Digital Solutions (DS). GE O&G also offers its solutions through joint ventures where localization provides a competitive advantage or where local law so requires.

 GE O&G is a global business with consolidated 2016 revenue of $13,269 million. GE O&G generates its revenue and orders from a combination of equipment sales and services. In 2016, 46.0% of revenue was generated from equipment sales and 54.0% from services, while 32.5% of orders were for equipment and 67.5% for services. Due to the nature of GE O&G’s business, including the time required to manufacture equipment and the long-term nature of many of its service contracts, there is a backlog of unfilled customer orders for equipment sales and services, which as of December 31, 2016 totalled $21,697 million. The following charts show the split between equipment sales and services for GE O&G’s 2016 and 2015 revenues, and 2016, 2015 and 2014 orders and year end backlog.

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Equipment/Services Revenues	

 	 	
Orders	  	Backlog	

 
Product services and backlog of product services

GE O&G’s Statement of Earnings displays sales and costs of sales in accordance with SEC regulations under which “goods” is required to include all sales of tangible products and “services” must include all other sales, including other services activities. For the amounts shown above, as well as in the orders and backlog charts included in this Business section and the Management’s Discussion and Analysis of Financial Condition and Results of Operations of GE O&G included in Exhibit 99.2 to this Current Report on Form 8-K, GE O&G distinguishes between “equipment” and “product services,” where product services refers to sales under product services agreements, including sales of both goods (such as spare parts and equipment upgrades) and related services (such as monitoring, maintenance and repairs), which is an important part of its operations. GE O&G refers to “product services” simply as “services” within this Business section and the Management’s Discussion and Analysis of Financial Condition and Results of Operations of GE O&G included in Exhibit 99.2 to this Current Report on Form 8-K.

Backlog is defined as unfilled customer orders for products and services believed to be firm. For product services, an amount is included for the expected life of the contract.
 
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Products and Services

Oilfield Services

The Oilfield Services (OFS) segment provides equipment and services ranging from well evaluation to decommissioning. OFS provides equipment and related services for onshore and shallow water oil and gas wells.  OFS’ product lines design, manufacture and sell artificial lift equipment, including dry trees, surface wellheads, electric submersible pumps, rod lift systems, actuators, progressive cavity pumps, and distribute gas lift systems for extracting crude oil and other fluids from wells.  Products and services also include diamond and tri-cone drill bits, drilling services (including directional drilling technology, measurement while drilling & logging while drilling), downhole completion tools and systems, wellbore intervention tools and services, wireline services, drilling and completions fluids and oilfield and industrial chemicals.  OFS’ products and services are used by international, national, and independent oil companies and oilfield service companies. The OFS portfolio includes the Lufkin ®  and Sondex ®  brands

OFS product lines’ core technologies enable stable, precise and accurate wellbore placement for high quality drilling that supports higher utilization rates by reducing the need for calibrations and repairs. Using data-enabled services, including equipment baseline modeling, condition-based maintenance, rig-based re-certification, and digitized asset history, OFS systems and services are able to increase reliability and reduce downtime.
OFS revenues represented approximately 6% of total GE O&G revenue and generated a loss of $204 million in 2016.
OFS revenues represented approximately 8% of total GE O&G revenue and generated a loss of $79 million in 2015.
Following the Transactions, a majority of the legacy Baker Hughes business operations are included in the OFS segment.

Oilfield Equipment

The Oilfield Equipment (OFE) segment provides a broad portfolio of products and services required to facilitate the safe and reliable flow of hydrocarbons from the subsea wellhead to the surface production facilities. The OFE operation designs and manufactures onshore and offshore drilling and production systems and equipment for floating production platforms and provides a full range of services related to onshore and offshore drilling activities.

The OFE portfolio includes deepwater drilling equipment, subsea production systems (SPS), flexible pipe systems, surface pressure control, and related service solutions. The OFE drilling product line offers blowout preventers, control systems, marine drilling risers, wellhead connectors, diverters and related services. OFE offers SPS, including trees, control systems, manifolds, connections, wellheads, specialty connectors, installation and decommissioning solutions, and related services. OFE also provides advanced flexible composite pipes for deepwater production riser applications and flowlines for use with floating production, storage, and offloading vessels, in a range of extreme operating environments.   OFE also offers a range of comprehensive, worldwide services for installation, technical support, well access through subsea intervention systems, operating resources and tools, offshore products and brownfield asset integrity solutions. The OFE portfolio includes the Hydril™, Vetco ®  Gray, Wellstream ® , and Advantec™ brands.
OFE  customers are oil and gas field developers, drilling and oil companies seeking to undertake new subsea projects, mid-life upgrades and maintenance, well interventions and workover campaigns. OFE differentiates itself in SPS and deepwater drilling systems. OFE’s key competitive areas are large-bore gas fields, deepwater oilfields and fields with long tieback distances. In addition to a robust presence in other subsea areas, including high-pressure high-temperature (HPHT) fields, OFE’s product lines’ production systems are among the industry’s most reliable, with uptime of the critical control system exceeding 99.8%.
 
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OFE revenues represented approximately 27% of total GE O&G revenue and 19% of GE O&G segment profit in 2016.
OFE revenues represented approximately 30% of total GE O&G revenue and 25% of 2015 GE O&G segment profit.

Turbomachinery & Process Solutions

The Turbomachinery & Process Solutions (TPS) segment provides equipment and related services for mechanical-drive, compression and power-generation applications across the oil and gas industry as well as products and services to serve the downstream segments of the industry including refining, petrochemical, distributed gas, flow and process control and other industrial applications. TPS segment is a leader in designing, manufacturing, maintaining and upgrading rotating equipment across the oil and gas, petro-chemical and industrial sectors.

The TPS portfolio includes drivers, driven equipment, flow control and turnkey solutions. Drivers comprise aero-derivative gas turbines, heavy-duty gas turbines, small- to medium-sized steam turbines, and synchronous and induction electric motors. TPS’ driven equipment consists of electric generators, reciprocating, centrifugal, axial, direct-drive high speed, integrated and subsea compressors, and turbo-expanders. TPS’ flow control includes pumps, valves, regulators, control systems and other flow and process control technologies. As part of its turnkey solutions, GE O&G TPS offers power generation modules, waste heat/energy recovery, energy storage, modularized small and large liquefaction plants, carbon capture and storage/use facilities. TPS also offers a variety of system upgrades and conversion solutions, from a single machine to full plant debottlenecking and modernization. The TPS portfolio includes the NuovoPignone ® , Salof™, Dresser™ and Thermodyn ®  brands.
TPS’ products enable customers to increase upstream oil and gas production, liquefy natural gas, compress gas for transport  via  pipelines, generate electricity, store gas and energy, refine oil and gas and produce petro-chemicals, while minimizing both operational and environmental risks in the most extreme service conditions. TPS’ customers are upstream, midstream and downstream, onshore and offshore, and small to large scale. Midstream and downstream customers include liquefied natural gas plants, pipelines, storage facilities, refineries and a wide range of industrial and engineering, procurement and construction (EPC) companies.
TPS’ value proposition is founded on its turbomachinery and flow control technology, a unique competence to integrate gas turbine and compressors in the most critical natural gas applications, best-in-class manufacturing and testing capabilities, reliable maintenance and service operations, and innovative real-time diagnostics and control systems, enabling condition-based maintenance and increasing overall productivity, availability, efficiency and reliability for oil and gas assets. TPS differentiates itself from competitors with its expertise in technology and project management, local presence and partnerships, as well as the deep industry know-how of its teams to provide fully integrated equipment and services solutions with state-of-art technology from design and manufacture through to operations.
 
TPS revenues represented approximately 52% of GE O&G revenue and 73% of GE O&G segment profit in 2016.

TPS revenues represented approximately 48% of total GE O&G revenue and 63% of GE O&G segment profit in 2015.

Digital Solutions

The Digital Solutions (DS) segment provides a diverse portfolio of hardware, software, industrial control systems, inspection solutions, sensor and measurement instruments and advisory services to improve machinery health and productivity of industrial assets.

The DS portfolio includes condition monitoring, inspection technologies, measurement and sensing and pipeline inspections. The DS condition monitoring product line, which includes the Bently Nevada ®  and System 1 ®  brands, provides rack-based vibration monitoring equipment, sensors, software cybersecurity solutions and industrial controls for power generation and oil and gas operations. The DS inspection technologies product line includes a broad portfolio of non-destructive testing (NDT) technology, software, and services, including industrial radiography, ultrasonic sensors, testing machines and gauges, NDT film, and remote visual inspection.
 
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The  DS measurement and sensing product line, which includes the Panametrics®, Druck®, Reuter Stokes™, Presens™ and Naxys™ brands,provides instrumentation including flow meters, moisture, humidity and oxygen analyzers, pressure sensors, controllers, calibrators, leak detection systems, radiation monitoring, flame sensors, and neutron scattering technology. The  DS pipeline inspections product line, operating under the PII™ brand, provides services to assess metal loss, identify deformation and abnormal geometry, detect cracks and assess overall pipeline integrity.
The DS segment helps companies optimize industrial assets by providing solutions such as performance management, condition and asset health monitoring, enabling customers to mitigate risk, boost safety, meet regulatory requirements, reduce maintenance costs, and improve equipment reliability, uptime, and efficiency. It also provides customers with the first step of their digital transformation, using sensors, services and inspections to connect industrial assets to the industrial internet  via  GE’s Predix cloud-based platform. Deployed on machines, onsite, or in the cloud, Predix handles big data on an industrial scale and with industrial-strength security, giving customers the power to innovate and make faster, more confident decisions. Predix provides the insights that transform asset performance and operations, allowing customers to enhance the safety, productivity and life of assets.
DS revenues represented approximately 16% of GE O&G revenue and 21% of GE O&G segment profit in 2016.
DS revenues represented approximately 13% of total GE O&G revenue and 15% of GE O&G segment profit in 2015.

Raw Materials and Suppliers

The principal raw materials used by GE O&G include steel alloys, chromium, nickel, titanium, barite, beryllium, copper, lead, tungsten carbide, synthetic and natural diamonds, gels, sand and other proppants, printed circuit boards and other electronic components and hydrocarbon-based chemical feed stocks. Raw materials that are essential to GE O&G’s business are normally readily available from multiple sources, but may be subject to price volatility. Market conditions can trigger constraints in the supply of certain raw materials, and GE O&G is always seeking ways to ensure the availability and manage the cost of raw materials. GE O&G’s procurement department uses its size and buying power to enhance its access to key materials at competitive prices.

In addition to raw materials, GE O&G also uses the products and services of metal fabricators, machine shops, foundries, forge shops, assembly operations, contract manufacturers, logistics providers, packagers, indirect material providers, and others in order to produce and deliver products to its customers. These materials and services are generally available from multiple sources.

Intellectual Property

GE O&G’s technology, brands and other intellectual property rights are important elements of its business. GE O&G relies on patent, trademark, copyright and trade secret laws, as well as non-disclosure and employee invention assignment agreements to protect its intellectual property rights. Many of the patents and patent applications in GE O&G’s portfolio are owned by GE O&G, while other patents and patent applications in GE O&G’s portfolio are licensed to GE O&G by GE and third parties. GE O&G does not consider any individual patent, trademark or copyright to be material to its business operations.

In connection with the Transactions, GE entered into a IP cross-license agreement (the IP Cross-License Agreement) with BHGE LLC. GE  agreed to license to BHGE LLC the right to use certain intellectual property owned or controlled by GE (other than GE Digital) pursuant to the terms of the IP Cross-License Agreement. BHGE LLC agreed to license to GE the right to use certain intellectual property rights pursuant to the terms of the IP Cross-License Agreement. This license allows BHGE LLC to have continued rights to use some of GE’s intellectual property so that they can be leveraged pursuant to the terms of the IP Cross-License Agreement. Any improvements to such intellectual property made or developed by BHGE LLC will be owned by BHGE LLC and licensed back to GE pursuant to the terms of the IP Cross-License Agreement and any improvements to such intellectual property made or developed by GE will be owned by GE and licensed to BHGE LLC. See “Item 1.01 Entry into a Material Definitive Agreement—Commercial Agreements—IP Cross-License Agreement” in BHGE LLC’s Current Report on Form 8-K filed on July 3, 2017 for more information.
 
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GE O&G follows a policy of seeking patent and trademark protection in numerous countries and regions throughout the world for products and methods that appear to have commercial significance and in regions where GE O&G has, or desires to have, a business presence. GE O&G has over 8,500 issued patents and pending patent applications worldwide, of which more than 2,000 are in the United States. GE O&G believes that protection of its patents, trademarks, and other intellectual property rights is central to the conduct of its business, and enforces its intellectual property rights against infringement worldwide as it deems appropriate to protect its business. Additionally, GE O&G considers the quality and timely delivery of its products, the services it provides to its customers and the technical knowledge and skills of its personnel to be other important components of the portfolio of capabilities and assets that support its ability to compete.

Customers and Sales

GE O&G’s sales efforts are organized around the constantly evolving needs of its customers and markets. GE O&G provides products and solutions to international, national, and independent oil companies and oilfield service companies in the upstream offshore, upstream onshore, pipeline and storage, refinery and petro-chemical, liquefied natural gas, industrial power generation and drilling segments. GE O&G’s customers also include EPC companies that perform projects using GE O&G products and services, as well as other industrial companies, including participants in the automotive, mining, aviation, aerospace and food and beverages sectors. No single customer accounted for 10% or more of GE O&G’s revenues in any of the past three fiscal years.

GE O&G sells to its customers through direct and indirect channels. Its primary sales channel is through its direct sales force, which has a strong regional focus with local teams close to the customer, who are able to draw support from centers of excellence in each of GE O&G’s major product lines. GE O&G’s sales force also uses its application engineers, field application engineers, service engineers, commercial and sales managers, and account executives to help deliver and provide customers with the best product and service solutions which GE O&G can offer.
In indirect channels, GE O&G relies upon its channel partners who act as buy/resell distributors, agents, or third-party sales representatives and provide GE O&G products, generally on a non-exclusive basis. Other indirect sales channels include original equipment manufacturers (OEMs) who incorporate GE O&G products and services as part of their design package and product offerings, and GE entities outside of GE O&G that incorporate GE O&G products and services in their offerings.
GE O&G’s marketing strategy spans traditional and digital media and includes exhibiting expertise through white papers, presentations and engineering focused publications, tradeshow and event marketing. Central to this strategy is engaging customers to understand the core challenges they face and how GE O&G can co-create innovative solutions to address these needs.

Certain non-U.S. GE O&G entities have received purchase orders for the sale of goods pursuant to General License H issued in January 2016 by the U.S. Department of Treasury’s Office of Foreign Assets Control that could potentially enhance Iran’s ability to develop petroleum resources. The first of these non-U.S. entities received four purchase orders during the fourth quarter of 2016 and two sets of purchase orders during the first quarter of 2017 covering the sale of spare parts for gas turbine equipment for ultimate end use by an Iranian company in gas production projects in Iran and have a total value of €33.6 million ($35.4 million). The non-U.S. affiliate also booked a modification of a previously reported contract to add additional scope valued at €2.0 million ($2.2 million). As of March 31, 2017 this non-U.S. GE O&G entity has not recognized any revenue, but has incurred €2.7 million ($2.9 million) in costs. A second non-U.S. GE O&G entity received a purchase order pursuant to General License H valued at €0.2 million ($0.2 million) during the fourth quarter of 2016 and a second purchase order during the first quarter of 2017 valued at €0.3 million ($0.3 million) for the sale of services associated with the commissioning of gas compressors in Iran. As of March 31, 2017, gross revenues attributable to this purchase order was €0.3 million ($0.3 million), and net profits attributable to this purchase order was €0.2 million ($0.2 million). A third non-U.S. affiliate of GE’s Oil & Gas business received purchase orders pursuant to General License H valued at €0.3 million ($0.3 million) during the first quarter of 2017 for the sale of production logging equipment and spare parts to an Iranian customer. As of March 31, 2017, the non-US affiliate has not yet recognized revenue or profit associated with this transaction. The non-U.S. GE O&G entities intend to continue this activity pursuant to General License H.

 
6

 

Contracts

GE O&G conducts its business under various types of contracts, including fixed-fee or turnkey contracts, transactional agreements for products and/or services across upstream, midstream and downstream segments and long-term aftermarket service agreements.

GE O&G enjoys stable relationships with many of its customers based on long-term project contracts. Several of those contracts require GE O&G to commit to a fixed price based on the customer’s technical specifications with little or no legal relief due to changes in circumstances, such as changes in local laws or industry or geopolitical events. In some cases, failure to deliver products or perform services within contractual commitments may lead to liquidated damages claims. In other cases, delivery of products or services ahead of contractual commitments can result in bonuses. GE O&G seeks to mitigate these exposures through close collaboration with its customers during work phases.  See “Risk Factors—Risk Factors Related to the Business of New Baker Hughes—Some of our customers require bids in the form of long-term, fixed pricing contracts” included in the Proxy Statement/Prospectus for further detail.
Consistent with industry practice, customers typically indemnify GE O&G for certain claims arising from the injury or death of their employees and their other contractors, the loss of or damage to their equipment and that of their other contractors, damage to the well or reservoir and pollution or clean-up originating from the customer’s equipment or from the reservoir, including uncontained oil flow from a reservoir, and claims arising from catastrophic events, such as a well blowout, fire, explosion and from pollution below the surface. Conversely, GE O&G typically indemnifies its customers for certain claims arising from the injury or death of its employees, the loss of or damage to its equipment (other than equipment lost in the hole) or pollution originating from GE O&G equipment in GE O&G care, custody or control, above the surface of the earth or water.
Subject to limited exceptions, GE O&G’s general practice is to include a limitation of liability clause to limit the overall risk associated with work performed under a contract. It is also GE O&G’s general practice to include a limitation of liability for consequential loss, including loss of profits and loss of revenue.
GE O&G’s indemnity structure may not protect it in every case. Often GE O&G contracts with customers that are not the end user of its products. It is GE O&G’s practice to seek to obtain an indemnity from its customer for any end-user claims but this is not always possible. Similarly, government agencies and other third parties may make claims in respect of which GE O&G is not indemnified and for which responsibility is assessed proportionate to fault. In all cases, deviations from GE O&G’s standard contracting practices are examined through an established risk deviation process.

Research and Development

GE O&G maintains an active research and development program, some of which is conducted using the research and development resources of GE. GE O&G engages in research and development activities directed primarily toward the development of new products, services, technology and other solutions, as well as the improvement of existing products and services and the design of specialized products to meet specific customer needs. GE O&G has technology centers located in many locations relevant to the global oil and gas industry.

In connection with the Transactions, GE agreed to provide BHGE LLC with access to certain of GE’s technological developments, enhancements and software, including tailored technology research and development services related to BHGE LLC’s operations. In addition, BHGE LLC agreed to provide GE with certain access to GE O&G’s technological developments, enhancements and software. See “Item 1.01 Entry into a Material Definitive Agreement—Commercial Agreements—IP Cross-License Agreement” in BHGE LLC’s Current Report on Form 8-K filed on July 3, 2017 for more information.
 
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GE O&G’s expenditures for research and development activities were approximately $352 million in 2016, approximately $408 million in 2015, and approximately $420 million in 2014.
In the TPS product line, GE O&G continues to invest in product improvement of reciprocating and centrifugal compressors, using advanced fluid dynamic simulation and advanced aeromechanics to improve capability, operability and efficiency of its centrifugal compressors family.
GE O&G OFE continues to invest in products to develop capability, improve performance and reduce costs. In SPS, the recent focus has been to expand capability into deeper water, longer offsets and at higher pressures. Subsea Power and Processing is also an area in which GE O&G is investing, covering both pumping and compression.
On the surface, OFS invested in a new and cutting-edge line of hydraulic actuators that offer customers improvements in reliability, efficiency and maintainability.
GE O&G DS continues to invest in advanced digital solutions designed to improve the efficiency, reliability and safety of oil and gas production operations. These systems integrate operational data from producing oil and gas facilities to deliver notifications and analytical reports to engineers so they can identify operational performance issues before they become significant, thus helping to prevent unplanned downtime and improve facility reliability.

Regulatory and Environmental

GE O&G’s operations, including its products and services, are subject to U.S. and non-U.S. laws and regulations relating to the protection of the environment and human health, including laws and regulations governing the investigation and remediation of soil and water contamination, including groundwater, surface water and marine waters, the payment for damages to natural resources, air emissions, water discharges, the use and handling of petroleum products and hazardous materials, and the disposal of petroleum wastes and hazardous wastes. Compliance with these laws and regulations requires obtaining and complying with the terms and conditions of permits, authorizations and other standards. Compliance also requires the installation of equipment, and the carrying out of periodic maintenance, in order to control and limit emissions and discharges, and to decrease the chances of unauthorized releases to the environment. These laws and regulations differ from jurisdiction to jurisdiction, continually change, and tend to become more stringent over time.
 
The laws and regulations governing the investigation and remediation of soil and water have required and may in the future require GE O&G to remediate contamination at both its current and former properties, and potentially at other properties and locations impacted by its operations. These laws and regulations may also require GE O&G to contribute to the costs of investigating and remediating contamination at third-party sites to which GE O&G sent hazardous and petroleum wastes for disposal, notwithstanding that the original disposal activity accorded with all legal and regulatory requirements. These laws and regulations are often no fault, and can require GE O&G to clean up contamination that stems from historic releases into the environment even though the releases may not have violated any then-existing requirements, as well as contamination caused by third parties such as former owners and operators of GE O&G’s current properties. Moreover, these laws and regulations are often joint and several, and GE O&G can be held responsible for the payment of the full amount of an environmental liability even if there are other responsible parties that will not or cannot satisfy their share of the liability. See “Risk Factors—Risk Factors Related to the Business of New Baker Hughes—Compliance with, and rulings and litigation in connection with, environmental regulations and the environmental impacts of our or our customers’ operations may adversely affect our business and operating results” in the Proxy Statement/Prospectus for further detail.

GE O&G has incurred and will continue to incur liabilities, and operating and capital costs, to maintain and achieve compliance with environmental, health and safety laws and regulations.

Competition

GE O&G’s products and services are sold in highly competitive markets and the competitive environment varies by product line, as discussed below:

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Oilfield Services (OFS)

In OFS, competitors include Schlumberger (including Cameron), Halliburton, Weatherford International, TechnipFMC, Weir Oil & Gas, Cactus and Summit.

Oilfield Equipment (OFE)

OFE believes that the principal competitive factors in the industries and markets it serves are product and service quality, reliability and on time delivery, health, safety and environmental standards, technical proficiency, availability of spare parts and price. Its strong track record of innovation enables OFE to enter into long-term, performance-based service agreements with its customers.

In the SPS product line, the primary competitors of OFE include OneSubsea (part of Schlumberger), TechnipFMC, Aker Solutions ASA, Proserv and Dril-Quip Inc. In the flexible pipe product line, competitors include TechnipFMC, NOV, Airborne, and Magma. In the drilling sub-product line, competitors include NOV and Schlumberger.

Turbomachinery & Process Solutions (TPS)

TPS believes that the principal competitive factors in the industries and markets it serves are product range (or power range measured in Megawatts) coverage, efficiency, product reliability and availability, service capabilities, packages, references, emissions and price.

In upstream and midstream applications, TPS’ primary equipment competitors include Siemens (Power and Gas business unit), Solar (a Caterpillar company), MAN Turbo and Mitsubishi Heavy Industries. In downstream applications, TPS primarily competes with OEMs and independent service providers, including Flowserve, Pentair, Emerson, Siemens, Hitachi, Solar (a Caterpillar company), Ariel, MAN Turbo, Burckhardt, Elliott Ebara and Mitsubishi Heavy Industries.
TPS’ aftermarket equipment product line competes with smaller independent local providers such as Masaood John Brown, Sulzer, MTU, Trans Canada Turbine, Chromalloy and Ethos Energy (a joint venture of Siemens and the Wood Group).

Digital Solutions (DS)

DS believes that the principal competitive factors in the industries and markets it serves are superior product technology, service, quality, and reliability, as well as its ability to utilize the GE Store.

DS competes across a wide range of industries, including Oil & Gas, Power Generation, Aerospace, and Light and Heavy Industrials. The products and services are sold in a diversified, fragmented arena with a broad range of competitors.
Although no single company competes directly with DS across all its product lines, various companies compete in one or more products. Primary competitors include Emerson, ABB, Schneider Electric, Fortive, Olympus, Comet Group, Honeywell Process Solutions, Roper Technology, Siemens, Spectris, Aspentech and OSISoft.

Employees

As of December 31, 2016, GE O&G had approximately 34,000 employees. A small portion of GE O&G’s employees is represented under collective bargaining agreements or similar labor arrangements. GE O&G believes that its employee relations are generally favorable.
 
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Properties

GE O&G owns or leases numerous properties in domestic and foreign locations. Generally, GE O&G leases office space, with less than 5% of such space being owned, while it owns approximately 80% of its manufacturing locations. Its principal properties include manufacturing facilities, light industrial sites, service shops, research and development laboratories, technology centers, and corporate offices. GE O&G also has numerous smaller facilities that include sales, project, and support offices and bulk storage facilities throughout the world. All of GE O&G’s owned properties are unencumbered.
 
As of January 1, 2017, GE O&G had access to the following principal properties, either owned or leased.
 	 	 	 	 	 	 	
Location	  	Region	  	Purpose	  	Legal Status	
GE O&G	  	 	  	 	  	 	
London, United Kingdom	  	Europe	  	Office	  	Leased	
Houston, Texas	 	NAM	 	Office	 	Leased	
Oilfield Services	 	 	 	 	 	 	
Comodoro, Argentina	  	LATAM	  	Manufacturing	  	Owned	
Lufkin, Texas	  	NAM	  	Manufacturing and Overhaul & Repair	  	Owned	
Ploiesti, Romania	  	Europe	  	Manufacturing	  	Owned	
Oklahoma City, Oklahoma	  	NAM	  	Manufacturing and Overhaul & Repair	  	Owned	
Shawnee, Oklahoma	  	NAM	  	Manufacturing	  	Owned	
Dammam, Saudi Arabia	  	MENAT	  	Manufacturing	  	Leased	
Monterrey, Mexico	  	LATAM	  	Manufacturing	  	Leased	
Comodoro, Argentina	  	LATAM	  	Manufacturing	  	Owned	
Oilfield Equipment	  	 	  	 	  	 	
Bristol, United Kingdom	  	Europe	  	Office	  	Leased	
Aberdeen, United Kingdom	  	Europe	  	Office and Manufacturing	  	Owned	
Newcastle, United Kingdom	  	Europe	  	Office and Manufacturing	  	Owned	
Montrose, United Kingdom	  	Europe	  	Manufacturing	  	Leased	
Houston, Texas (NHR)	  	NAM	  	Manufacturing and services	  	Owned	
Houston, Texas (Hydril)	  	NAM	  	Office and Manufacturing	  	Owned	
Niteroi, Brazil	  	LATAM	  	Manufacturing	  	Leased	
Singapore	  	ASEAN	  	Manufacturing	  	Owned	
Turbomachinery & Process Solutions	  	 	  	 	  	 	
Florence, Italy	  	Europe	  	Office and Manufacturing	  	Owned/Leased	
Avenza, Italy	  	Europe	  	Spare parts distribution	  	Leased	
Massa, Italy	  	Europe	  	Manufacturing and string test	  	Owned	
Jacksonville, Florida	  	NAM	  	Manufacturing	  	Leased	
Lufkin, Texas	  	NAM	  	Manufacturing	  	Owned	
Schertz, Texas	  	NAM	  	Manufacturing	  	Owned	
Houston, Texas (Port NW)	  	NAM	  	Manufacturing	  	Leased	
Houston, Texas (HSC)	  	NAM	  	Overhaul & Repair	  	Owned	
Digital Solutions	  	 	  	 	  	 	
San Ramon, California	  	NAM	  	Office	  	Leased	
Hurth, Germany	  	Europe	  	Manufacturing	  	Owned	
Minden, Nevada	  	NAM	  	Manufacturing	  	Owned	
Billerica, Massachusetts	  	NAM	  	Office and Manufacturing	  	Leased	
Ahrensburg, Germany	  	Europe	  	Manufacturing	  	Leased	
Cramlington, United Kingdom	  	Europe	  	Office and Manufacturing	  	Owned	
Longmont, Colorado	  	NAM	  	Manufacturing	  	Leased	
Groby, United Kingdom	  	Europe	  	Manufacturing	  	Owned	
Wunstorf, Germany	  	Europe	  	Manufacturing	  	Owned	
       
GE O&G believes all properties that it currently occupies are suitable for their intended use.

Legal Proceedings

GE O&G is subject to litigation and other risks posed under the different regimes in all parts of the world where the company operates or buys or sells its equipment and services. GE O&G has adopted appropriate risk management and compliance programs to address these and other matters that may arise from time to time. Yet the global and diverse nature of GE O&G’s business, and the changing enforcement environments in which it operates, means the nature and outcome of existing or potential legal proceedings and enforcement actions cannot be predicted with certainty. GE O&G believes, based on its review or the probable outcome of the proceedings to which it is a party, that any unrecorded liability that may result will not have a material adverse effect on its liquidity, financial condition or results of operations.

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Exhibit 99.2

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS OF GE O&G

Baker Hughes, a GE company, LLC, a Delaware limited liability company (the Company, BHGE LLC, we, us, or our ) and the successor to Baker Hughes Incorporated, a Delaware corporation (Baker Hughes) is a fullstream oilfield technology provider that has a unique mix of equipment and service capabilities. On July 3, 2017, we closed our previously announced business combination (the Transactions) to combine the oil and gas business (GE O&G) of General Electric Company (GE) and Baker Hughes.  In connection with the Transactions, we entered into and are governed by an Amended & Restated Operating Agreement, dated as of July 3, 2017 (the BHGE LLC Agreement). Under the BHGE LLC Agreement, EHHC Newco, LLC (EHHC), a wholly owned subsidiary of Baker Hughes, a GE company (BHGE), is our sole managing member and BHGE is the sole managing member of EHHC. As our managing member, EHHC conducts, directs and exercises full control over all our activities, including our day-to-day business affairs and decision-making, without the approval of any other member. As such, EHHC is responsible for all our operational and administrative decisions and the day-to-day management of our business. GE owns approximately 62.5% of our common units and BHGE owns approximately 37.5% of our common units indirectly through two wholly owned subsidiaries.
 
The Transactions were treated as a “reverse acquisition” for accounting purposes and, as such, the historical financial statements of the accounting acquirer, GE O&G, are the historical financial statements of the Company.  The Company’s financial statements have been prepared on a consolidated basis, effective July 3, 2017. For all periods prior to July 3, 2017, the Company’s financial statements were prepared on a combined basis. The combined financial statements included in Exhibit 99.3 to this Current Report on Form 8-K combine certain accounts of GE and its subsidiaries that were historically managed as part of its Oil & Gas business. The historical financial results in the combined financial statements presented may not be indicative of the results that would have been achieved had GE O&G operated as a separate, stand-alone entity during those periods.  The GE O&G numbers in the combined statements of income (loss) and the combined statements of cash flows have been reclassified to conform to the presentation included in BHGE LLC’s Quarterly Report on Form 10-Q for the period ended September 30, 2017. We believe that the reclassified presentation is a more appropriate presentation of the combined businesses.
 
The following management’s discussion and analysis of financial condition and results of operations of GE O&G was included in the definitive proxy statement/prospectus (Proxy Statement/Prospectus) filed by Baker Hughes on May 30, 2017 and has been recast to reflect a change in segment reporting following the Transactions and the reclassified presentation of the statements of income (loss) and the statements of cash flows.  The discussion below is limited to the fiscal years ended December 31, 2016, 2015 and 2014 for GE O&G and does not include financial information for Baker Hughes. The information included in this section has been revised only to reflect the reporting changes described above and has not otherwise been updated or revised to reflect events or changes occurring after the date of the Proxy Statement/Prospectus. This information should be read in conjunction with BHGE LLC’s SEC filings. Following the Transactions, the majority of the legacy Baker Hughes business is included in the Oilfield Services segment, with a small component included in the Digital Services segment.
 
The following discussion and analysis summarizes the significant factors affecting the results of operations, financial condition and liquidity position of GE O&G as of and for the years ended December 31, 2016, 2015 and 2014, and should be read in conjunction with the combined financial statements and related notes of GE O&G included in Exhibit 99.3 to this Current Report on Form 8-K. Neither the following discussion and analysis nor the combined financial statements of GE O&G represent the financial position or results of operations of the Oil & Gas operating segment of GE. The following discussion and analysis of the financial condition and results of operations of GE O&G covers periods prior to the consummation of the Transactions and does not reflect its effect on future periods. The following discussion and analysis contain forward-looking statements that reflect GE O&G’s plans, estimates and beliefs. Actual results could differ materially from those discussed in the forward-looking statements. See “Cautionary Note Regarding Forward-Looking Statements” included in the Proxy Statement/Prospectus. Factors that could cause or contribute to these differences include those discussed below and in the section titled “Risk Factors” included in the Proxy Statement/Prospectus.

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Presentation

The sum of the components reported in millions may not be equal to the total amount reported due to rounding. Percentages presented are calculated from the numbers in millions.
 
Executive Summary

GE O&G operates in more than 120 countries, offering its customers a leading portfolio of advanced technology and optimization support. GE O&G is active in all segments of the oil and gas industry; upstream to downstream, greenfield to brownfield, onshore and offshore. GE O&G also delivers pipeline integrity solutions, a wide range of sensing, inspection and monitoring technologies and industrial power generation and compression solutions for the midstream liquefied natural gas and pipeline segments and downstream refining and petro-chemical segments. GE O&G endeavors to continuously improve oil and gas industry performance, output and productivity.

GE O&G principally provides equipment and services to the oil and natural gas exploration and production industry, both on land and offshore, through its four business segments: Oilfield Services (OFS); Oilfield Equipment (OFE); Turbomachinery & Process Solutions (TPS); and Digital Solutions (DS), which are described below:

 	•	Oilfield Services provides equipment and services ranging from well evaluation to decommissioning. Products and services include diamond and tri-cone drill bits, drilling services (including directional drilling technology, measurement while drilling & logging while drilling), downhole completion tools and systems, wellbore intervention tools and services, wireline services, drilling and completions fluids, oilfield and industrial chemicals, pressure pumping, and artificial lift technologies (including electrical submersible pumps).	

 	•	Oilfield Equipment provides a broad portfolio of products and services required to facilitate the safe and reliable flow of hydrocarbons from the subsea wellhead to the surface. Products and services include pressure control equipment and services, Subsea production systems and services, drilling equipment, and flexible pipeline systems. Oilfield Equipment operation designs and manufactures onshore and offshore drilling and production systems and equipment for floating production platforms and provides a full range of services related to onshore and offshore drilling activities.	

 	•	Turbomachinery & Process Solutions provides equipment and related services for mechanical-drive, compression and power-generation applications across the oil and gas industry as well as products and services to serve the downstream segments of the industry including refining, petrochemical, distributed gas, flow and process control and other industrial applications.  The Turbomachinery & Process Solutions portfolio includes drivers (aero-derivative gas turbines, heavy-duty gas turbines and synchronous and induction electric motors), compressors (centrifugal and axial, direct drive high speed, integrated, subsea compressors, turbo expanders and reciprocating), turn-key solutions (industrial modules and waste heat recovery), pumps, valves, and compressed natural gas (CNG) and small-scale liquefied natural gas (LNG) solutions used primarily for shale oil and gas field development.	

 	•	Digital Solutions provides equipment and services for a wide range of industries, including oil & gas, power generation, aerospace, metals, and transportation. The offerings include sensor-based measurement, non-destructive testing and inspection, turbine, generator and plant controls and condition monitoring, as well as pipeline integrity solutions.	

The years ended December 31, 2016 and 2015 were a challenging period for the oil and gas industry, primarily due to uncertainty and volatility in oil and gas prices. While there have been indications of positive trends in oil and gas prices, the industry generally continues to focus on cost rationalization and capital spending reductions to align its cost structure with current economic conditions. The challenging period continues and has led to lower capital spending across the oil and gas industry, which adversely affected GE O&G’s financial performance in 2016 and in 2015 as it experienced a reduction in volume and pricing pressure across most of its product lines.

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The Transactions

On October 30, 2016, GE and Baker Hughes entered into the Transaction Agreement and Plan of Merger, as amended by the Amendment to the Transaction Agreement and Plan of Merger, dated as of March 27, 2017, which provided for the combination of GE O&G and Baker Hughes as described above. The combined product portfolio of GE O&G and Baker Hughes in drilling, completions, production and midstream/downstream equipment and services created a leading equipment, technology, and service provider in the oil and gas industry operating in more than 120 countries.
 
Factors Affecting Results of Operations

Oil and Gas Prices

The sharp decline experienced in oil and gas prices since 2014 and the prospect of a continuation of prevailing low oil and gas prices has caused GE O&G’s business to experience declines in orders, some project commencement delays and pricing pressures as capital spending by customers has been diminished, deferred or cancelled. Outside North America, customer spending is most heavily influenced by Brent oil prices and by regional or oil-linked natural gas prices, while in North America, customer spending is highly driven by WTI oil prices and natural gas prices, as measured by the Henry Hub Natural Gas Spot Price. In response to this uncertain industry outlook, GE O&G continues to realize cost saving actions with an increased focus on execution and productivity.

The following table sets forth average oil prices for the years indicated.
 	 	 	 	 	 	 	
 	Average Daily Price	 	
Year Ended	WTI Crude	 	Brent Crude	 	Henry Hub
Natural Gas	 	
December 31, 2016	$	43.29	 	$	43.67	 	$	2.52	 	
December 31, 2015	 	48.66	 	 	52.32	 	 	2.62	 	
December 31, 2014	 	93.17	 	 	98.97	 	 	4.37	 	

(1)	Source: U.S. Energy Information Administration (EIA). As of May 19, 2017, WTI crude, Brent crude and natural gas traded at approximately $48.86 per barrel, $51.29 per barrel and $3.26 per mmBtu, respectively.	

Rig Counts and Contract Awards

The number of customer contracts awarded across key product lines in the calendar year is a key business barometer for GE O&G, as it is an indicator of the overall health of the oil and gas business. The number of contracts awarded is generally determined by the capital spending of our customers, which is directly influenced by oil and gas prices. The awards represent the amount of new business that was available for open bid within the industry and is a good indicator of customer spending over the period. These awards should not be the sole factor considered as there may be other conditions that impact the customer’s overall spending, particularly with respect to services. Rig counts are also a business barometer for GE O&G. When drilling rigs are active, they consume products and services. Rig count trends are governed by exploration and development spending by our customers, which in turn is influenced by current and future price expectations for oil and gas. Therefore, the counts may be reflective of the relative strength and stability of energy prices and overall market activity.

The following table sets forth rig counts and contract awards for the years indicated.
 	 	 	 	 	 	 	
 	Calendar year ending
December 31,	 	
 	2016	 	2015	 	2014	 	
LNG awards(1)	 	4	 	 	23	 	 	38	 	
Offshore blowout preventer awards(2)	 	-	 	 	-	 	 	8	 	
Subsea tree awards(3)	 	75	 	 	156	 	 	239	 	
U.S. onshore rigs(4)	 	490	 	 	948	 	 	1,804	 	
International onshore rigs(4)(5)	 	855	 	 	1,072	 	 	1,385	 	
 
(1)	Source: Internal GE database of publicly announced awards in million tons per annum.	

(2)	Source: IHS Petrodata April 2017.	

(3)	Source: WoodMac April 2017.	

(4)	Source: Baker Hughes Rig Count, www.bakerhughes.com.	

(5)	Does not include Russia, China or Central Asia.	
 
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Key Performance Indicators ($ millions)

Product services and backlog of product services

GE O&G’s Statement of Earnings displays sales and costs of sales in accordance with SEC regulations under which “goods” is required to include all sales of tangible products and “services” must include all other sales, including other service activities. For the amounts shown below, as well as in the orders and backlog charts included in the Business section in Exhibit 99.1 to this Current Report on Form 8-K and this Management’s Discussion and Analysis section, GE O&G distinguishes between “equipment” and “product services”, where product services refers to sales under product services agreements, including sales of both goods (such as spare parts and equipment upgrades) and related services (such as monitoring, maintenance and repairs), which is an important part of its operations. GE O&G refers to “product services” simply as “services” within the Business section in Exhibit 99.1 to this Current Report on Form 8-K and this Management’s Discussion and Analysis section.

Backlog is defined as unfilled customer orders for products and services believed to be firm. For product services, an amount is included for the expected life of the contract.
 
Historical orders and backlog by fiscal year ($ millions)

Orders	 	Backlog	

Orders: In 2016, GE O&G recognized orders of $11,273 million, a decrease of $4,112 million from 2015. Driven by broader market conditions, GE O&G continued to see delays in final investment decisions on projects and pricing pressure.
 
Backlog: GE O&G’s backlog represents unfilled customer orders for products and services, with the value being defined as the expected life of contract sales for product services. In 2016, GE O&G’s backlog was $21,697 million, a decrease of $2,244 million from 2015 primarily driven by the decrease in equipment backlog of 32% as well as the strengthening of the U.S. dollar, which accounted for a decrease of $309 million. GE O&G’s services backlog increased by 5% to $15,223 million. Backlog remains relatively strong and provides an indication of long term revenues within GE O&G.
 
GE O&G’s book-to-bill ratio utilized to analyze the relationship between orders received and revenue recognized. Due to the market conditions, our book-to-bill ratio was 0.8:1 and 0.9:1 for the years ending December 31, 2016 and 2015, respectively. These ratios and the resulting reduction in backlog were primarily driven by the long-cycle nature of our equipment businesses and the aforementioned market conditions. Based on improving industry conditions, GE O&G expects this trend to stabilize, specifically in the equipment businesses, and as a result we do not expect it to have a material effect on our operations. GE O&G continues to monitor conditions and act accordingly, as an example, executing further restructuring and product cost-out efforts. GE O&G expects approximately 30% of the total $21,697 million December  31, 2016 year-end backlog to be fulfilled within the following fiscal year with the remainder expected to be completed in future years.

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Results of Operations ($ millions)

The results of operations of GE O&G are evaluated by the chief executive officer of GE O&G on a combined and consolidated basis as well as at the segment level.

Revenue includes revenues related to the segment. Segment operating income is determined based on the internal performance measures used by the chief executive officer of GE O&G to assess the performance of each segment in a financial period. In assessing each segment’s performance, the chief executive officer of GE O&G may exclude certain items from the segment and include these items in the corporate items and eliminations line. The performance of our operating segments is evaluated based on segment operating income (loss), which is defined as income (loss) before income taxes and equity in loss of affiliate and before the following: net interest expense, net other non operating income (loss), corporate expenses, restructuring, impairment and other charges, inventory impairments, goodwill impairments, merger and related costs, and certain gains and losses not allocated to the operating segments.

In evaluating the segment performance, the chief executive officer of GE O&G uses the following metrics:
          
Volume & Price: Volume is the increase or decrease in products and/or services sold period-over-period excluding the impact of foreign exchange and price. The volume impact on profit is calculated by multiplying the prior period profit rate by the change in revenue volume between the current and prior period. Price is defined as the change in sales price for a comparable product or service period-over-period and is calculated as the period-over-period change in sales prices of comparable products and services.
                   
Foreign Exchange (“FX”): FX measures the translational foreign exchange impact, or the translation impact of the period-over-period change on sales and costs directly attributable to change in the foreign exchange rate compared to the U.S. dollar. FX impact is calculated by multiplying the functional currency amounts (revenue or profit) with the period-over-period FX rate variance, using the average exchange rate for the respective period.
                       
(Inflation)/Deflation: (Inflation)/deflation is defined as the increase or decrease in direct and indirect costs of the same type for an equal amount of volume. It is calculated as the year-over-year change in cost ( i.e. , price paid) of direct material, compensation & benefits and overhead costs.
                          
Productivity: Productivity is measured by the remaining variance in profit, after adjusting for the period-over-period impact of volume & price, foreign exchange and (inflation)/deflation as defined above. Improved or lower period-over-period cost productivity is the result of cost efficiencies or inefficiencies, such as cost decreasing or increasing more than volume, or cost increasing or decreasing less than volume, or changes in sales mix among segments. This also includes the period-over-period variance of transactional foreign exchange, aside from those foreign currency devaluations that are reported separately for business evaluation purposes.

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Revenue and Segment Operating Income (Loss) Before Tax

Revenue and segment operating income (loss) for each of our four operating segments is provided below. 
 	 	GE O&G
Fiscal Year Ending December 31,	 	
(in millions)	 	2016	 	 	2015	 	 	2014	 	
Revenue	 	 	 	 	 	 	 	 	 	
Oilfield Services	 	 	799	 	 	 	1,411	 	 	 	2,232	 	
Oilfield Equipment	 	 	3,547	 	 	 	5,060	 	 	 	5,927	 	
Turbomachinery & Process Solutions	 	 	6,837	 	 	 	7,985	 	 	 	8,647	 	
Digital Solutions	 	 	2,086	 	 	 	2,232	 	 	 	2,385	 	
Total segment revenue	 	 	13,269	 	 	 	16,688	 	 	 	19,191	 	
Segment operating income (loss)	 	 	 	 	 	 	 	 	 	 	 	 	
Oilfield Services	 	 	(204	)	 	 	(79	)	 	 	10	 	
Oilfield Equipment	 	 	320	 	 	 	677	 	 	 	764	 	
Turbomachinery & Process Solutions	 	 	1,255	 	 	 	1,684	 	 	 	1,562	 	
Digital Solutions	 	 	355	 	 	 	409	 	 	 	483	 	
Total segment operating income (loss)	 	 	1,726	 	 	 	2,691	 	 	 	2,819	 	
Corporate	 	 	(380	)	 	 	(260	)	 	 	(164	)	
Inventory impairment	 	 	(138	)	 	 	(51	)	 	 	(8	)	
Impairment of goodwill	 	 	-	 	 	 	(2,080	)	 	 	-	 	
Restructuring, impairment and other	 	 	(516	)	 	 	(411	)	 	 	(189	)	
Merger and related costs	 	 	(33	)	 	 	(27	)	 	 	(67	)	
Operating income (loss)	 	 	659	 	 	 	(138	)	 	 	2,391	 	
Other non operating income (loss), net	 	 	27	 	 	 	100	 	 	 	124	 	
Interest expense, net	 	 	(102	)	 	 	(120	)	 	 	(179	)	
Income (loss) before income taxes	 	 	584	 	 	 	(158	)	 	 	2,336	 	
Provision for Income Taxes	 	 	(250	)	 	 	(473	)	 	 	(484	)	
Net income (loss)	 	 	334	 	 	 	(631	)	 	 	1,852	 	

 
6

 

The following charts show historical segment revenues and segment operating income for each of our reportable segments for the years ended December 31, 2016, 2015 and 2014 as well as our revenues by geographic region for the year ended December 31, 2016:

Historical Segment Revenues and Segment Operating Income ($ millions)

Segment Revenues	 	Segment Operating Income	

2016 Geographic Revenues ($13,269 million)

Fiscal Year 2016 to Fiscal Year 2015 Consolidated Performance

Revenue in 2016 was $13,269 million, a decrease of $3,419 million, or 20%, from 2015. This decrease was primarily due to the continued decline in customer activity across all product lines due to the continued weakness in oil prices. Oilfield Equipment decreased $1,513 million, Turbomachinery & Process Solutions decreased $1,148 million, Oilfield Services decreased $612 million, and Digital Solutions decreased $146 million.
                 
Total segment operating income in 2016 was $1,726 million, a decrease of $965 million, or 36%, from 2015. This decrease was primarily driven by the combined impact of lower volume and pricing headwinds. Turbomachinery & Process Solutions decreased $429 million, Oilfield Equipment decreased $357 million, Oilfield Services decreased $125 million, and Digital Solutions decreased $54 million.

 
7

 

Oilfield Services

Oilfield Services 2016 revenue was $799 million, a decrease of $612 million, or 43%, from 2015. This decline was primarily driven by the impact of lower oil prices on customer purchasing decisions throughout the year.
                     
Oilfield Services 2016 segment operating loss was $204 million, compared to a loss of $79 million in 2015. This decline in profitability was mainly due to lower cost productivity, partially offset by cost deflation.
               
Oilfield Equipment

Oilfield Equipment 2016 revenue was $3,547 million, a decrease of $1,513 million, or 30%, from 2015. This decline was primarily due to customers’ activity reductions, and to a lesser extent the strengthening of the U.S. dollar.
                    
Oilfield Equipment 2016 segment operating income was $320 million, compared to $677 million in 2015. This decline in profitability was the result of lower revenues and negative pricing, as well as lower cost productivity, partially offset by deflation savings.

Turbomachinery & Process Solutions

Turbomachinery & Process Solutions 2016 revenue was $6,837 million, a decrease of $1,148 million, or 14%, from 2015. The decline was primarily attributable to decreases in volume and price driven by uncertainty in the broader market, and delays in equipment contracts.
                 
Turbomachinery & Process Solutions 2016 segment operating income was $1,255 million, compared to $1,684 million in 2015. This decline in profitability was primarily due to the impact of lower volume and negative pricing.
           
Digital Solutions

Digital Solutions 2016 revenue was $2,086 million, a decrease of $146 million, or 7%, from 2015. This decline was due to lower sales volume driven by the delay of capital spending projects in the oil and gas sector.
                  
Digital Solutions 2016 segment operating income was $355 million, compared to $409 million in 2015. This decline in profitability was driven by lower cost productivity and weaker sales volume.
          
Corporate

In 2016, Corporate expenses were $380 million, an increase of $120 million compared to 2015. This was primarily due to selective increases in R&D program investments and lower cost productivity.
            
Restructuring, Impairment and Other

In 2016, GE O&G recognized $516 million in restructuring and other charges, an increase of $105 million compared to 2015. This increase was driven by continued focus on cost rationalization to better align GE O&G’s operating structure to market conditions and significant currency devaluations in Angola and Nigeria.
 
Merger and Related Costs

GE O&G recorded $33 million of merger and related costs in 2016, an increase of $6 million from the prior year, primarily related to the acquisition of Baker Hughes.
        
Interest Expense, Net

In 2016, GE O&G incurred net interest expenses of $102 million, a decrease of $18 million from the prior year, primarily related to the factoring of accounts receivable, mainly with GE Capital.

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Income Tax

In 2016, GE O&G income tax expense decreased by $223 million, to $250 million from $473 million in 2015. This decrease was primarily due to a decline in profit excluding the impairment of non-deductible goodwill of $453 million, partially offset by a decrease in the benefit from global operations including foreign tax credit benefits of $132 million. The 2015 effective tax rate was unfavorably impacted by this goodwill impairment, which was non-deductible for tax purposes and increased the tax provision by $713 million relative to income tax expense had it been deductible.
                 
Fiscal Year 2015 to Fiscal Year 2014

Consolidated Performance

Revenue in 2015 was $16,688 million, a decrease of $2,503 million, or 13%, from 2014. This decrease was primarily due to the negative impact of the strengthening of the U.S. dollar on all segments along with lower volume due to weakness in oil prices. Oilfield Equipment decreased $867 million, Oilfield Services decreased $821 million, Turbomachinery & Process Solutions decreased by $662 million, and Digital Solutions decreased $153 million.
                               
Total segment operating income in 2015 was $2,691 million, a decrease of $128 million, or 5%, from 2014. This decline was primarily driven by the strengthening of the U.S. dollar in comparison to other currencies and the impact of lower volumes. Oilfield Services decreased $89 million, Oilfield Equipment decreased $87 million and Digital Solutions decreased $74 million, partially offset by an increase in Turbomachinery & Process Solutions of $122 million.
         
Oilfield Services

Oilfield Services 2015 revenue was $1,411 million, a decrease of $821 million, or 37%, compared to 2014. This decrease was primarily driven by lower volumes and weaker price on equipment and services product lines due to the decline in oil prices throughout the year.
                    
Oilfield Services 2015 segment operating loss was $79 million, compared to segment operating income of $10 million in 2014. This decline in profitability was mainly due to volume and price-related decreases.
               
Oilfield Equipment

Oilfield Equipment 2015 revenue was $5,060 million, a decrease of $867 million, or 15%, from 2014. The decrease was mainly attributable to the strengthening of the U.S. dollar.
                        
Oilfield Equipment 2015 segment operating income was $677 million, a decrease of $87 million from 2014. This decline in profitability was mainly due to the strengthening of the U.S. dollar and weaker volumes, partially offset by cost deflation and cost productivity.

Turbomachinery & Process Solutions

Turbomachinery & Process Solutions 2015 revenue was $7,985 million, a decrease of $662 million, or 8%, from 2014. The decrease was driven by the negative impact of the strengthening of the U.S. dollar, which offset volume and price-related increases.
                        
Turbomachinery & Process Solutions 2015 segment operating income was $1,684 million, an increase of $122 million from 2014. This increase in profitability was driven by strong cost productivity, volume and price increases and cost deflation.
         
Digital Solutions

Digital Solutions 2015 revenue was $2,232 million, a decrease of $153 million, or 6%, compared to 2014. This decrease was primarily driven by the impact of a stronger U.S. dollar and partially offset by an increase in volume.

9

 
 
Digital Solutions 2015 segment operating income was $409 million, compared to $483 million in 2014. The decline in profitability was mainly driven by the negative impact of the strengthening U.S. dollar, which more than offset strong cost productivity.
 
Corporate

In 2015, Corporate expenses were $260 million an increase of $96 million, compared to 2014. This increase was primarily due to selective increases in R&D program investments and localization efforts.
                  
Restructuring, Impairment and Other

In 2015, GE O&G implemented various restructuring programs designed to better align its cost structure to the change in economic conditions driven by a significant decline in oil prices. This combined with significant currency devaluations in Angola and Nigeria, resulted in restructuring and other charges of $411 million, an increase of $222 million compared to 2014.
 
Merger and Related Costs

GE O&G recorded $27 million of merger and related costs in 2015, a decrease of $40 million from the prior year. This reduction was primarily related to non-recurring trailing costs related to the acquisition of Lufkin Industries in 2014.
                  
Interest Expense, Net

In 2015, GE O&G incurred net interest expenses of $120 million, a decrease of $59 million from the prior year. This decrease was driven by an increase in interest income and a decrease in factoring expenses.
             
Income Tax

In 2015, GE O&G income tax expense decreased by $11 million, to $473 million from $484 million in 2014. This decrease was primarily due to a decrease in the benefit from global operations including foreign tax credit benefits of $174 million, partially offset by a decline in profit excluding the impairment of non-deductible goodwill of $160 million. The 2015 effective tax rate was unfavorably impacted by this goodwill impairment which was non-deductible for tax purposes and increased the tax provision by $713 million relative to income tax expense had it been deductible.
            
Financial Resources and Liquidity

GE O&G’s objective is to maintain sufficient liquidity and financial flexibility to fund its business operations. As of December 31, 2016, GE O&G had $981 million of cash and equivalents, compared to $1,432 million at December 31, 2015. As of December 31, 2016, approximately $878 million of the $981 million of cash and equivalents was held by GE O&G’s foreign subsidiaries and would be subject to United States tax if repatriated. GE O&G’s intent is to permanently reinvest these funds outside of the United States and current plans do not suggest a need to repatriate such funds to fund GE O&G’s United States operations.

GE O&G mainly generates its cash from its operating activities. Historically GE O&G has participated in GE’s cash pooling arrangements to access liquidity and fund its operations, the effect of which is treated as net parent investment for carve out financial statement purposes. GE O&G has accessed third party bank debt when needed to fill its short-term cash needs. GE O&G has not borrowed material amounts from third party banks or the capital markets to fund its operations.

GE O&G has committed credit lines of $200 million that have been extended to it by three banks as of December 31, 2016. As of December 31, 2016, $128 million of these credit facilities remained available for use.

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GE O&G has undertaken certain transactions with related parties, primarily GE Capital, through which it can monetize its accounts receivable through the sale of these receivable to GE Capital’s Working Capital Solutions. GE O&G monetizes receivables, as and when needed, to generate liquidity without the use of the capital markets. GE O&G pays commission and servicing fees to GE Capital’s Working Capital Solutions for these transactions when they are consummated.

GE O&G believes that cash on hand, cash flows generated from operations and the available credit facility will provide sufficient liquidity to manage its global cash needs.

As of December 31, 2016, $752 million of cash and equivalents were held in bank accounts and cannot be released, transferred or otherwise converted into a currency that is regularly transacted internationally, due to lack of market liquidity, capital controls or similar monetary or exchange limitations limiting the flow of capital out of the jurisdiction.
                     
Cash Flows

The following table summarizes cash flows generated from (used in) each type of activity for each period (in millions):
 	 	 	 	 	 	 	 	 	 	
 	GE O&G Fiscal Year Ending
December 31,	 	
 	2016	 	2015	 	2014	 	
Operating activities	 	$	262	 	 	$	1,277	 	 	$	1,887	 	
Investing activities	 	 	(472	)	 	 	(466	)	 	 	(836	)	
Financing activities	 	 	(102	)	 	 	(515	)	 	 	(388	)	

Operating Activities

GE O&G’s largest source of operating cash is payments from customers, of which the largest component is collecting cash related to product or services sales including advance payments or progress collections for work to be performed. The primary use of operating cash is to pay GE O&G’s suppliers, employees, tax authorities and others for a wide range of material and services.

Cash flows from operating activities generated $262 million and $1,277 million for the years ended December 31, 2016 and 2015, respectively. Cash flows from operating activities decreased $1,015 million in 2016 primarily due to the decrease in net income, partially offset by improvements in other working capital categories, due to improvements in the collection of past due receivables, improved inventory management and restructuring.
                        
Cash flows from operating activities generated $1,277 million and $1,887 million for the years ended December 31, 2015 and 2014, respectively. Cash flows from operating activities decreased $610 million in 2015 primarily due to a decrease in progress collections driven by market conditions. This was offset by an improvement in the other working capital categories, primarily receivables and inventory, due to an improvement in collections of past due receivables, improved inventory management and restructuring efforts.
           
Investing Activities

Cash flows from investing activities used $472 million and $466 million for the years ended December 31, 2016 and 2015, respectively. GE O&G’s principal recurring investing activity is the funding of capital expenditures, including property plant and equipment and software, to support operations. Expenditures for capital assets were $424 million in 2016 and $607 million in 2015. There were no material acquisitions or dispositions in 2016; however, in 2015 GE O&G generated approximately $181 million from business dispositions and utilized $86 million cash in business acquisitions.
                            
Cash flows from investing activities used $466 million and $836 million for the years ended December 31, 2015 and 2014, respectively. Expenditures for capital assets were $607 million and $686 million in 2015 and 2014, respectively. The decline in capital expenditures in 2015 is a result of GE O&G’s rationalization of investments aligned to the lower market activity. In 2014, $592 million was utilized to acquire businesses, primarily Cameron’s Reciprocating Compression division for $550 million. In addition, GE O&G recognized proceeds from the sale of assets of $441 million, primarily from the sale of the Wayne Fueling Systems business of $485 million.

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Financing Activities
 
Cash utilized in financing activities for 2016 was $102 million, a decrease of $413 million compared to 2015. This was primarily driven by a net contribution to GE as part of the cash pooling activity that is included in the net transfer (to)/from parent component on the Statement of Cash Flows.

Cash utilized in financing activities for 2015 was $515 million, an increase of $127 million compared to 2014. This was primarily driven by a net transfer to GE as part of the cash pooling activity that is included in the net transfer (to)/from parent component on the Statement of Cash Flows $960 million, partially offset by a change in borrowings of $797 million.
            
Contractual Obligations

The following table summarizes GE O&G’s significant contractual obligations and other long-term liabilities as of December 31, 2016 (in millions): 
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	Total	 	 	Less than
1 year	 	 	2-3 years	 	 	4-5 years	 	 	More than
5 years	 	
Long-Term Debt(a)	 	$	156	 	 	$	118	 	 	$	35	 	 	$	1	 	 	$	2	 	
Operating leases(b)	 	 	516	 	 	 	94	 	 	 	159	 	 	 	109	 	 	 	154	 	
Purchase obligations(c)	 	 	489	 	 	 	479	 	 	 	10	 	 	 	—	 	 	 	—	 	
Other long term liabilities(d)	 	 	540	 	 	 	48	 	 	 	44	 	 	 	28	 	 	 	420	 	

(a)	Represents principal amount of long-term debt, including current maturities. The interest on this debt is between $1-2 million per year and reflected in the table above in long-term debt.	

(b)	Amounts represent the future minimum payments under noncancelable operating leases with an initial term of one year or more. GE O&G does not include options unless exercise of that option is anticipated.	

(c)	Represents purchase orders for goods and services utilized in the normal course of business.	

(d)	Includes capital lease obligations, capital expenditures and pension funding obligations. The following non-current liabilities are excluded from the table above: derivatives, deferred revenue and other miscellaneous items. For further information on certain of these items, see Note 11, Borrowings, Note 13, All Other Liabilities, and Note 19, Commitments and Product Warranties to the GE O&G combined financial statements included in Exhibit 99.3 to this Current Report on Form 8-K. See Note 14, Income Taxes, to the GE O&G combined financial statements included in Exhibit 99.3 to this Current Report on Form 8-K for disclosures surrounding uncertain income tax positions. Additionally, liabilities for uncertain tax positions totaling $149 million, including interest and penalties, are not included in the table because the timing of their resolution cannot be estimated.	

Other Factors Affecting Liquidity

Customer receivables: In line with industry practice, GE O&G may bill its customers for services provided in arrears dependent upon contractual terms. In a challenging economic environment, GE O&G may experience delays in the payment of its invoices due to customers’ lower cash flow from operations or their more limited access to credit markets. While historically there have not been material non-payment events, GE O&G attempts to mitigate this risk through the sale of its receivables in monetization programs or working with its customers to restructure their debts; however, not all countries and programs allow monetization on a non-recourse basis. A customer’s failure or delay in payment could have a material adverse effect on GE O&G’s short-term liquidity and results from operations. As of December 31, 2016, GE O&G has no customer balances which exceed 10% of GE O&G’s net customer receivables.

12

 
International operations: GE O&G’s cash that is held outside the United States, which comprised 90% of the total cash balance as of December 31, 2016, is in certain circumstances subject to exchange or cash controls that could make it challenging to quickly access. As a result, GE O&G’s cash balance may not represent its ability to quickly and efficiently use this cash.
 
Off Balance Sheet Commitments

In addition to the above-referenced contractual obligations, GE O&G has additional contractual commitments and other commitments that are not necessarily reflected in GE O&G’s consolidated balance sheet. Such commitments as of December 31, 2016 are as follows:
 
Guarantees Related to Operating Activities

Commitments relate mainly to guarantees or counter-guarantees given by banks and insurance companies to various customers in connection with ongoing contracts to secure due and proper performance of the contracts or following the payment of retention guarantees and advance billings of $48 million as of December 31, 2016.
 
Quantitative and Qualitative Disclosures about Market Risk

Cash Flow Hedges

GE O&G’s business involves buying, manufacturing and selling components and products across global markets. These activities expose GE O&G to changes in foreign currency exchange rates, commodity prices and interest rates which can adversely affect revenues earned and costs of its operating businesses. When the currency in which equipment is sold differs from the primary currency of the legal entity and the exchange rate fluctuates, it will affect the revenue earned on the sale. These sales and purchase transactions also create receivables and payables denominated in foreign currencies and exposure to foreign currency gains and losses based on changes in exchange rates. Changes in the price of raw materials used in manufacturing can affect the cost of manufacturing. GE O&G uses derivatives to mitigate or eliminate these exposures, where appropriate.

GE O&G uses cash flow hedging primarily to reduce or eliminate the effects of foreign currency exchange rate changes on purchase and sale contracts. Accordingly, most derivative activity in this category consists of currency exchange contracts. GE O&G had outstanding foreign currency forward contracts with notional amounts aggregating $6,430 million and $8,017 million to hedge exposure to currency fluctuations in various foreign currencies at December 31, 2016 and 2015, respectively. Based on quoted market prices as of December 31, 2016 or 2015 for forward contracts with similar terms and maturity dates, GE O&G recorded losses, both realized and unrealized in nature, of $273 million and $117 million, respectively, to adjust these forward contracts to their fair market value. As at December 31, 2016 GE O&G estimates that a 1% appreciation or depreciation in the U.S. dollar would result in impact of approximately $10 million to the financial results of GE O&G, as GE O&G is generally able to mitigate its foreign exchange exposure, where there are liquid financial markets, through use of foreign currency derivative transactions.
 
Changes in and Disagreements with Accountants and Financial Disclosure

None.
 
Critical Accounting Estimates

Accounting estimates and assumptions discussed in this section are those considered to be the most critical to an understanding of GE O&G’s financial statements because they involve significant judgments and uncertainties. Many of these estimates include determining fair value. These estimates reflect GE O&G’s best judgment about current, and for some estimates future, economic and market conditions and their potential effects based on information available as of the date of these financial statements. If these conditions change from those expected, it is reasonably possible that the judgments and estimates described below could change, which may result in future impairments of goodwill, intangibles and long-lived assets, increases in reserves for contingencies, establishment of valuation allowances on deferred tax assets and increased tax liabilities, among other effects. Also, see Note 2, Accounting Policies to the consolidated financial statements, which discusses GE O&G’s most significant accounting policies.

13

 
 
Revenue Recognition on Long-Term Product Services Agreements

Revenue recognition on long-term product services agreements requires estimates of profits over the multiple-year terms of such agreements, considering factors such as the frequency and extent of future monitoring, maintenance and overhaul events, the amount of personnel, spare parts and other resources required to perform the services, and future billing rate, cost changes and customers’ utilization of assets. GE O&G routinely reviews estimates under product services agreements and regularly revises them to adjust for changes in the outlook for revenue recognition.

GE O&G also regularly assesses customer credit risk inherent in the carrying amounts of receivables, contract costs and estimated earnings, including the risk that contractual penalties may not be sufficient to offset its accumulated investment in the event of customer termination. GE O&G gains insight into future utilization and cost trends, as well as credit risk, through its knowledge of the installed base of equipment and the close interaction with its customers that comes with supplying critical services and parts over extended periods. Revisions, after applying the cumulative catch-up basis of accounting, may affect a product services agreement’s total estimated profitability, resulting in an adjustment of earnings; such adjustments increased earnings by $293 million, $256 million and $145 million in the years ending December 31, 2016, 2015 and 2014, respectively. GE O&G provides for probable losses when they become evident. GE O&G continues to evaluate the provisions of ASC 605-35, Revenue from Contracts with Customers, and the assessment of the impact, on GE O&G’s combined financial statements and related disclosures. Also, see Note 2 to the consolidated financial statements for additional information and disclosure.
 
Goodwill and Other Identified Intangible Assets

GE O&G tests goodwill for impairment annually using data as of July 1 of that year. The impairment test consists of two different steps: in step one, the carrying value of the reporting unit is compared with its fair value; in step two, which is applied when the carrying value is more than its fair value, the amount of goodwill impairment, if any, is derived by deducting the fair value of the reporting unit’s assets and liabilities from the fair value of its equity and comparing that amount with the carrying amount of goodwill. GE O&G determines fair values of each of the reporting units using the market approach, when available and appropriate, or the income approach, or a combination of both. GE O&G assesses the valuation methodology based upon the relevance and availability of the data at the time the valuation is performed.
 
Pension Assumptions

Pension benefits are calculated using significant inputs to the actuarial models that measure pension benefit obligations and related effects on operations. Two assumptions, discount rate and expected return on assets, are important elements of plan expense and asset/liability measurement. GE O&G evaluates these critical assumptions at least annually on a plan- and country-specific basis. GE O&G periodically evaluates other assumptions involving demographic factors such as retirement age, mortality and turnover, and updates them to reflect its experience and expectations for the future. Actual results in any given year will often differ from actuarial assumptions because of economic and other factors.

Projected benefit obligations are measured as the present value of expected payments discounted using the weighted average of market-observed yields for high-quality fixed-income securities with maturities that correspond to the payment of benefits; lower discount rates increase present values and subsequent-year pension expense and higher discount rates decrease present values and subsequent-year pension expense.
                           
GE O&G’s discount rates for principal pension plans at December 31, 2016, 2015 and 2014 were 3.41%, 3.83% and 3.69%, respectively, reflecting market interest rates. GE O&G’s expected return on assets at December 31, 2016, 2015 and 2014 were 6.86%, 6.91%, and 6.66%, respectively. The discount rate and expected return on assets have not changed significantly from our December 31, 2016 assumptions.

14

 
 
Income Taxes

We operate in more than 120 countries and our annual tax rate is based on our income, statutory tax rates and tax planning opportunities available to us in these various jurisdictions. Tax laws are complex and subject to different interpretations by the taxpayer and respective governmental taxing authorities. Our income tax rate is impacted by the tax rate on our global operations. In addition to local country tax laws and regulations, this rate depends on the extent earnings are indefinitely reinvested outside the United States. Indefinite reinvestment is determined by future operations of the Business. At December 31, 2016 and 2015, approximately $11,936 million and $11,204 million of earnings, respectively, have been indefinitely reinvested outside the United States. Most of these earnings have been reinvested in active non-U.S. business operations, and we do not intend to repatriate these earnings to fund U.S. operations. Because of the availability of U.S. foreign tax credits, it is not practicable to determine the U.S. federal income tax liability that would be payable if such earnings were not reinvested indefinitely.

Deferred income tax assets represent amounts available to reduce income taxes payable in future years. We evaluate the recoverability of these future deductions and credits by assessing the adequacy of future taxable income from all sources, including reversal of taxable temporary differences, forecasted operating earnings and available tax planning strategies. These sources of income rely heavily on estimates. We use our historical experience and short- and long-range business forecasts to provide insight. Further, our global business gives us the opportunity to employ various prudent and feasible tax planning strategies to facilitate the recoverability of future deductions.
                                                           
Our tax filings routinely are subject to audit by the tax authorities in the jurisdictions where we conduct business. These audits may result in assessments of additional taxes that are resolved with the tax authorities or through the courts. We have provided for the amounts we believe will ultimately result from these proceedings, but settlements of issues raised in these audits may affect our tax rate.
                                                           
GE O&G has $94 million of gross unrecognized tax benefits at December 31, 2016, of which an immaterial amount may require a cash payment. GE O&G is not able to reasonably estimate in which future periods these amounts ultimately will be settled and paid.
 
Derivatives and Hedging

GE O&G operates in more than 120 countries and are subject to market risks primarily associated with changes in foreign currency exchange rates. GE O&G maintains a foreign-currency risk management strategy that uses derivative instruments to protect its interests from unanticipated fluctuations in earnings and cash flows caused by volatility in currency exchange rates. Foreign currency forward contracts provide a hedge against currency fluctuations on monetary assets/liabilities and future committed cash flows denominated in other than a functional currency.

GE O&G had outstanding foreign currency forward contracts with notional amounts aggregating $6,430 million and $8,017 million to hedge exposure to currency fluctuations in various foreign currencies at December 31, 2016 and 2015, respectively. Based on quoted market prices as of December 31, 2016, 2015 and 2014, for forward contracts with similar terms and maturity dates, GE O&G records losses of $273 million, $117 million and $109 million, respectively, to adjust these forward contracts to their fair market value. Also, see Note 18, Derivatives to the consolidated financial statements, which has additional details on GE O&G’s strategy.
 
Other Loss Contingencies

Other loss contingencies are uncertain and unresolved matters that arise in the ordinary course of business and result from events or actions by others that have the potential to result in a future loss. Such contingencies include, but are not limited to, environmental obligations, litigation, regulatory proceedings, product quality and losses resulting from other events and developments.

When a loss is considered probable and reasonably estimable, a liability is recorded in the amount of GE O&G’s best estimate for the ultimate loss. When there appears to be a range of possible costs with equal likelihood, liabilities are based on the low end of such range. However, the likelihood of a loss, with respect to a contingency, is often difficult to predict and determining a meaningful estimate of the loss or a range of loss may not be practicable based on the information available and the potential effect of future events and decisions by third parties that will determine the ultimate resolution of the contingency.

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Moreover, it is not uncommon for such matters to be resolved over many years, during which time relevant developments and new information must be continuously evaluated to determine both the likelihood of potential loss and whether it is possible to reasonably estimate a range of possible loss. When a loss is probable but a reasonable estimate cannot be made, disclosure is provided.
                       
Disclosure is also provided when it is reasonably possible that a loss will be incurred or when it is reasonably possible that the amount of a loss will exceed the recorded provision. GE O&G regularly reviews all contingencies to determine whether the likelihood of loss has changed and to assess whether a reasonable estimate of the loss, or range of loss, can be made. As discussed above, development of a meaningful estimate of loss or a range of potential loss is complex when the outcome is directly dependent on negotiations with, or decisions by, third parties, such as regulatory agencies, the court system and other interested parties. Such factors bear directly on whether it is possible to reasonably estimate a range of potential loss and boundaries of high and low estimates.

 

 

 

 
16

 
Exhibit 99.3
 
INDEX TO FINANCIAL STATEMENTS

CONTENTS	 	

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM	3	
 	 	 	
COMBINED STATEMENT OF INCOME (LOSS)	4	
 	 	 	
COMBINED STATEMENT OF COMPREHENSIVE INCOME (LOSS)	5	
 	 	 	
COMBINED STATEMENT OF CHANGES IN EQUITY	6	
 	 	 	
COMBINED STATEMENT OF FINANCIAL POSITION	7	
 	 	 	
COMBINED STATEMENT OF CASH FLOWS	8	
 	 	 	
NOTES TO THE COMBINED FINANCIAL STATEMENTS	9	

NOTE 1	DESCRIPTION OF THE BUSINESS	9	
 	 	 	
NOTE 2	BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	9	
 	 	 	
NOTE 3	ACQUISITIONS AND DISPOSITIONS	23	
 	 	 	
NOTE 4	CURRENT RECEIVABLES	23	
 	 	 	
NOTE 5	INVENTORIES	24	
 	 	 	
NOTE 6	PROPERTY, PLANT AND EQUIPMENT	24	
 	 	 	
NOTE 7	GOODWILL	25	
 	 	 	
NOTE 8	OTHER INTANGIBLE ASSETS	26	
 	 	 	
NOTE 9	CONTRACT ASSETS	27	
 	 	 	
NOTE 10	ACCOUNTS PAYABLE	27	
 	 	 	
NOTE 11	BORROWINGS	28	
 	 	 	
NOTE 12	POSTRETIREMENT BENEFIT PLANS	29	
 	 	 	
NOTE 13	ALL OTHER LIABILITIES	37	
 	 	 	
NOTE 14	INCOME TAXES	38	
 	 	 	
NOTE 15	EQUITY	42	
 	 	 	
NOTE 16	EQUITY-ACCOUNTED INVESTMENTS	45	

1    GE O&G Annual FS

 

 	 	 	
NOTE 17	FAIR VALUE MEASUREMENTS	46	
 	 	 	
NOTE 18	DERIVATIVES	47	
 	 	 	
NOTE 19	COMMITMENTS, CONTINGENCIES AND PRODUCT WARRANTIES	51	
 	 	 	
NOTE 20	RELATED PARTIES	52	
 	 	 	
NOTE 21	SEGMENT INFORMATION	54	
 	 	 	
NOTE 22	STOCK BASED COMPENSATION	56	
 	 	 	
NOTE 23	RESTRUCTURING, IMPAIRMENT AND OTHER	60	
 	 	 	
NOTE 24	SUBSEQUENT EVENTS	61	

 

 

 

2    GE O&G Annual FS

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

Report of Independent Registered Public Accounting Firm

The Board of Directors of General Electric Company:

We have audited the accompanying combined statement of financial position of GE Oil & Gas (the “Company”, a business within General Electric Company) as of December 31, 2016 and 2015, and the related combined statements of income (loss), comprehensive income (loss), changes in equity, and cash flows for each of the years in the three-year period ended December 31, 2016. These combined financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these combined financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States) and in accordance with auditing standards generally accepted in the United States of America. 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 combined financial statements referred to above present fairly, in all material respects, the combined financial position of the Company as of December 31, 2016 and 2015, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2016, in conformity with U.S. generally accepted accounting principles.

/s/ KPMG S.p.A. Florence, Italy
March 16, 2017, except as to Note 21
which is as of December 4, 2017

 

 
 
3    GE O&G Annual FS

 
COMBINED STATEMENT OF INCOME (LOSS)
For the years ended December 31 (In millions)	 	2016	 	 	2015	 	 	2014	 	
Revenues	 	 	 	 	 	 	 	 	 	
Sales of goods	 	$	9,488	 	 	$	12,353	 	 	$	14,464	 	
Sales of services	 	 	3,781	 	 	 	4,335	 	 	 	4,727	 	
  Total revenues	 	 	13,269	 	 	 	16,688	 	 	 	19,191	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Costs and expenses	 	 	 	 	 	 	 	 	 	 	 	 	
Cost of goods sold	 	 	7,816	 	 	 	9,271	 	 	 	10,508	 	
Cost of services sold	 	 	2,307	 	 	 	2,922	 	 	 	3,748	 	
Selling, general and administrative expenses	 	 	1,938	 	 	 	2,115	 	 	 	2,288	 	
Impairment of goodwill	 	 	-	 	 	 	2,080	 	 	 	-	 	
Restructuring, impairment and other	 	 	516	 	 	 	411	 	 	 	189	 	
Merger and related costs	 	 	33	 	 	 	27	 	 	 	67	 	
  Total costs and expenses	 	 	12,610	 	 	 	16,826	 	 	 	16,800	 	
Operating income (loss)	 	 	659	 	 	 	(138	)	 	 	2,391	 	
Other non operating income (loss), net	 	 	27	 	 	 	100	 	 	 	124	 	
Interest expense, net	 	 	(102	)	 	 	(120	)	 	 	(179	)	
Income (loss) before income taxes	 	 	584	 	 	 	(158	)	 	 	2,336	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Provision for income taxes	 	 	(250	)	 	 	(473	)	 	 	(484	)	
Net income (loss)	 	 	334	 	 	 	(631	)	 	 	1,852	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Less net income (loss) attributable to noncontrolling interests	 	 	(69	)	 	 	(25	)	 	 	12	 	
Net income (loss) attributable to parent	 	$	403	 	 	$	(606	)	 	$	1,840	 	

See Notes to the Combined Financial Statements
 
4    GE O&G Annual FS

 
COMBINED STATEMENT OF COMPREHENSIVE INCOME (LOSS)
For the years ended December 31 (In millions)	 	2016	 	 	2015	 	 	2014	 	
Net income (loss)	 	$	334	 	 	$	(631	)	 	$	1,852	 	
Less net income (loss) attributable to noncontrolling interests	 	 	(69	)	 	 	(25	)	 	 	12	 	
Net income (loss) attributable to parent	 	 	403	 	 	 	(606	)	 	 	1,840	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Other comprehensive income (loss)	 	 	 	 	 	 	 	 	 	 	 	 	
    Currency translation adjustments	 	 	(422	)	 	 	(617	)	 	 	(129	)	
    Cash flow hedges	 	 	(8	)	 	 	(2	)	 	 	-	 	
    Benefit plans	 	 	54	 	 	 	40	 	 	 	(94	)	
Other comprehensive (loss)	 	 	(376	)	 	 	(579	)	 	 	(223	)	
Less other comprehensive (loss) attributable to noncontrolling interests	 	 	(14	)	 	 	(11	)	 	 	(8	)	
Other comprehensive (loss) attributable to parent	 	 	(362	)	 	 	(568	)	 	 	(215	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Comprehensive income (loss)	 	 	(42	)	 	 	(1,210	)	 	 	1,629	 	
Less comprehensive income (loss) attributable to noncontrolling interests	 	 	(83	)	 	 	(36	)	 	 	4	 	
Comprehensive income (loss) attributable to parent	 	$	41	 	 	$	(1,174	)	 	$	1,625	 	

Amounts presented net of taxes. See Note 15 for further information about other comprehensive income (loss) and noncontrolling interests.

See Notes to the Combined Financial Statements
 
5    GE O&G Annual FS

 
COMBINED STATEMENT OF CHANGES IN EQUITY
(In millions)	 	2016	 	 	2015	 	 	2014	 	
Equity balance at January 1	 	$	14,388	 	 	$	16,205	 	 	$	14,689	 	
Net income (loss) attributable to parent	 	 	403	 	 	 	(606	)	 	 	1,840	 	
Other comprehensive (loss) attributable to parent	 	 	(362	)	 	 	(568	)	 	 	(215	)	
Net transfers (to) / from parent	 	 	259	 	 	 	(643	)	 	 	(109	)	
Ending balance at December 31	 	 	14,688	 	 	 	14,388	 	 	 	16,205	 	
Noncontrolling interests	 	 	167	 	 	 	157	 	 	 	181	 	
Total equity balance at December 31	 	$	14,855	 	 	$	14,545	 	 	$	16,386	 	

See Notes to the Combined Financial Statements

 
6    GE O&G Annual FS

 
COMBINED STATEMENT OF FINANCIAL POSITION
December 31 (In millions)	 	2016	 	 	2015	 	
Current assets	 	 	 	 	 	 	
Cash and equivalents	 	$	981	 	 	$	1,432	 	
Current receivables (Note 4)	 	 	2,563	 	 	 	2,818	 	
Inventories (Note 5)	 	 	3,224	 	 	 	3,671	 	
Other current assets	 	 	633	 	 	 	488	 	
Total current assets	 	 	7,401	 	 	 	8,409	 	
 	 	 	 	 	 	 	 	 	
Property, plant & equipment-net (Note 6)	 	 	2,325	 	 	 	2,554	 	
Goodwill (Note 7)	 	 	6,680	 	 	 	6,867	 	
Other intangible assets - net (Note 8)	 	 	2,449	 	 	 	2,676	 	
Contract assets (Note 9)	 	 	1,967	 	 	 	1,666	 	
All other assets	 	 	573	 	 	 	627	 	
Deferred income taxes (Note 14)	 	 	326	 	 	 	334	 	
Total assets	 	$	21,721	 	 	$	23,133	 	
 	 	 	 	 	 	 	 	 	
Current liabilities	 	 	 	 	 	 	 	 	
Short-term borrowings (Note 11)	 	 	239	 	 	 	384	 	
Accounts payable, principally trade accounts (Note 10)	 	 	1,898	 	 	 	2,222	 	
Current compensation and benefits	 	 	10	 	 	 	10	 	
Progress collections	 	 	1,596	 	 	 	2,310	 	
All other current liabilities (Note 13)	 	 	1,191	 	 	 	1,631	 	
Total current liabilities	 	 	4,934	 	 	 	6,557	 	
 	 	 	 	 	 	 	 	 	
Long-term borrowings (Note 11)	 	 	38	 	 	 	13	 	
Non-current compensation and benefits	 	 	519	 	 	 	641	 	
All other non-current  liabilities (Note 13)	 	 	495	 	 	 	523	 	
Deferred income taxes (Note 14)	 	 	880	 	 	 	854	 	
Total liabilities	 	$	6,866	 	 	$	8,588	 	
 Equity	 	 	 	 	 	 	 	 	
Accumulated other comprehensive (loss) – net attributable to parent (Note 15)	 	 	 	 	 	 	 	 	
   Currency translation adjustments	 	 	(1,801	)	 	 	(1,384	)	
   Cash flow hedges	 	 	(10	)	 	 	(2	)	
   Benefit plans	 	 	(83	)	 	 	(146	)	
Net parent investment	 	 	16,582	 	 	 	15,920	 	
Total equity attributable to parent	 	 	14,688	 	 	 	14,388	 	
Noncontrolling interests (a)	 	 	167	 	 	 	157	 	
Total equity	 	 	14,855	 	 	 	14,545	 	
Total liabilities and equity	 	$	21,721	 	 	$	23,133	 	

(a) Included AOCI attributable to noncontrolling interests of $(51) million and $(37) million at December 31, 2016 and December 31, 2015, respectively.

See Notes to the Combined Financial Statements
 
7    GE O&G Annual FS

 
COMBINED STATEMENT OF CASH FLOWS
For the years ended December 31 (In millions)	 	2016	 	 	2015	 	 	2014	 	
Cash flows - operating activities	 	 	 	 	 	 	 	 	 	
Net income (loss)	 	$	334	 	 	$	(631	)	 	$	1,852	 	
Less net income (loss) attributable to noncontrolling interests	 	 	(69	)	 	 	(25	)	 	 	12	 	
Net income (loss) attributable to parent	 	 	403	 	 	 	(606	)	 	 	1,840	 	
Adjustments to reconcile net income (loss) attributable to parent to cash	 	 	 	 	 	 	 	 	 	 	 	 	
   provided by operating activities:	 	 	 	 	 	 	 	 	 	 	 	 	
   Depreciation and amortization	 	 	550	 	 	 	530	 	 	 	443	 	
   Goodwill impairment	 	 	-	 	 	 	2,080	 	 	 	-	 	
   Deferred income taxes	 	 	39	 	 	 	(96	)	 	 	(246	)	
   Decrease (increase) in current receivables	 	 	278	 	 	 	469	 	 	 	(102	)	
   Decrease (increase) in inventories	 	 	345	 	 	 	442	 	 	 	(231	)	
   (Decrease) in accounts payable	 	 	(256	)	 	 	(450	)	 	 	(131	)	
   Increase (decrease) in progress collections	 	 	(714	)	 	 	(867	)	 	 	(18	)	
   Deferred charges	 	 	(292	)	 	 	(87	)	 	 	(46	)	
   All other operating activities	 	 	(91	)	 	 	(138	)	 	 	378	 	
Cash from operating activities	 	 	262	 	 	 	1,277	 	 	 	1,887	 	
Cash flows - investing activities	 	 	 	 	 	 	 	 	 	 	 	 	
Expenditure for capital assets	 	 	(424	)	 	 	(607	)	 	 	(686	)	
Proceeds from disposal of assets	 	 	20	 	 	 	30	 	 	 	26	 	
Proceeds from principal business dispositions	 	 	-	 	 	 	181	 	 	 	441	 	
Net cash from (payments for) principal businesses purchased	 	 	(1	)	 	 	(86	)	 	 	(592	)	
All other investing activities	 	 	(67	)	 	 	16	 	 	 	(25	)	
Cash (used for) investing activities	 	 	(472	)	 	 	(466	)	 	 	(836	)	
Cash flows - financing activities	 	 	 	 	 	 	 	 	 	 	 	 	
Net increase (decrease) in borrowings (maturities of 90 days or less)	 	 	(78	)	 	 	105	 	 	 	(606	)	
Repayments and other reductions (maturities longer than 90 days)	 	 	(235	)	 	 	(18	)	 	 	(107	)	
Newly issued debt (maturities longer than 90 days)	 	 	157	 	 	 	90	 	 	 	93	 	
Net transfer (to) / from parent	 	 	191	 	 	 	(708	)	 	 	252	 	
All other financing activities	 	 	(137	)	 	 	16	 	 	 	(20	)	
Cash (used for) financing activities	 	 	(102	)	 	 	(515	)	 	 	(388	)	
Effect of currency exchange rate changes on cash and equivalents	 	 	(139	)	 	 	(254	)	 	 	(53	)	
Increase (decrease) in cash and equivalents	 	 	(451	)	 	 	42	 	 	 	610	 	
Cash and equivalents at beginning of year	 	 	1,432	 	 	 	1,390	 	 	 	780	 	
Cash and equivalents at end of year	 	$	981	 	 	$	1,432	 	 	$	1,390	 	
Supplemental disclosure of cash flow information	 	 	 	 	 	 	 	 	 	 	 	 	
Cash paid during the year for interest	 	$	55	 	 	$	52	 	 	$	68	 	
Cash paid for taxes	 	 	317	 	 	 	264	 	 	 	205	 	

See Notes to the Combined Financial Statements
 
8    GE O&G Annual FS

 
NOTES TO THE COMBINED FINANCIAL STATEMENTS
NOTE 1	DESCRIPTION OF THE BUSINESS	
GE Oil and Gas (the “Business,” “GE O&G,” “we,” “our,” or “us”) offers its customers a leading portfolio of advanced technology and optimization support across the oil and gas value chain.  With its operational headquarters in London, United Kingdom, the Business is comprised of assets, liabilities, and results of operations of certain dedicated legal entities within General Electric Company (“GE”), a U.S. listed company, as well as certain non-GE O&G legal entities, which are shared legal entities within GE.
We have global operations with a presence in North America, Europe, Asia, Africa, Australia and Latin America and generate approximately 76% of our revenue from outside of the United States of America. The Business has approximately 34,500 employees in more than 120 countries and has four operating segments: Oilfield Services (OFS), Oilfield Equipment (OFE), Turbomachinery & Process Solutions (TPS) and Digital Solutions (DS).
 
NOTE 2	BASIS OF PRESENTATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	

BASIS OF PRESENTATION
These combined financial statements were prepared on a stand-alone basis derived from the consolidated financial statements and accounting records of GE. These combined financial statements as of December 31, 2016 and 2015 and for each of the years ended December 31, 2016, 2015 and 2014 are presented as carve-out financial statements and reflect the combined historical results of operations, financial position and cash flows of GE O&G, in conformity with U.S. generally accepted accounting principles (“GAAP”).

All significant intercompany balances and transactions within the Business have been eliminated in these combined financial statements. As described in Note 20, certain transactions between the Business and GE have been included in the combined financial statements.

The combined financial statements reflect the attribution of the specifically identifiable assets and liabilities of the Business, including goodwill and other identifiable intangible assets arising from the historical acquisitions of businesses comprising GE O&G. Where a business included within the scope of GE O&G as of December 31, 2016 was historically acquired and operated within another GE business unit, the combined financial statements reflect the assets, liabilities and results of operations of those businesses on a fully retrospective basis (in accordance with the guidance applicable to transactions between entities under common control) based on their carrying values, as reflected in the accounting records of GE.

GE uses a centralized approach to cash management and financing of its operations. This arrangement is not reflective of the manner in which the Business would have financed its operations had it been a stand-alone business separate from GE during the periods presented. Long-term intercompany financing, including strategic financing, and cash pooling arrangements, which are used to fund expansion or certain working capital needs, are excluded from the asset and liability balances in the Combined Statement of Financial Position. These amounts have instead been reported as “Net parent investment” as a component of equity.

GE and its affiliates provide a variety of services to the Business. Certain services, such as employee payroll, administering employee benefits plans and paying related claims, provision of voice and data networking, facility rent, outsourcing of certain functions, and other corporate services and overhead (including costs for executive compensation and stock options), are charged to the Business. In circumstances where charges were not historically billed to the Business by GE (or charges billed were not reflective of the full costs of doing business), those charges have been allocated to the Business and are reflected as Selling, general and administrative expenses in the Combined Statement of Income (Loss). Where specific identification of charges was not practicable, a reasonable method of allocation was applied to those charges based on either a proportional share of operating revenues, headcount, personnel costs, or estimates of use and the resulting allocation to the Business is recorded in Selling, general and administrative expenses in the Combined Statement of Income (Loss).

9    GE O&G Annual FS

 
The Business believes the allocations of these amounts were determined on a reasonable basis and the methods were applied consistently for the periods presented and reflect all of the costs of GE O&G. These allocated amounts, however, are not necessarily indicative of the actual amounts that might have been incurred or realized had GE O&G operated as a separate stand-alone entity during the periods presented. Consequently, the combined financial statements do not necessarily represent the results the Business would have achieved if the Business had operated as a separate stand-alone entity during the periods presented.

Certain columns and rows may not add due to the use of rounded numbers.

ACCOUNTING POLICIES
FOREIGN CURRENCY
Assets and liabilities of non-U.S. operations with a functional currency other than the U.S. dollar have been translated into U.S. dollars at the quarterly exchange rates, and revenues, expenses, and cash flows have been translated at average rates for the respective periods.  Any resulting translation gains and losses are included in Other comprehensive income (loss).

Gains and losses from foreign currency transactions, such as those resulting from the settlement of receivables or payables in the non-functional currency and those resulting from remeasurements of monetary items, are included in the Combined Statement of Income (Loss). A loss of $40 million and gains of $26 million, and $68 million were incurred for each of the years ended December 31, 2016, 2015 and 2014, respectively.

USE OF ESTIMATES

The preparation of combined financial statements in conformity with GAAP requires management to make estimates and judgments that affect the reported amounts of assets and liabilities, disclosure of any contingent assets or liabilities at the date of the combined financial statements and the reported amounts of revenue and expenses during the reporting period. We base our estimates and judgments on historical experience and on various other assumptions and information that we believe to be reasonable under the circumstances. Estimates and assumptions about future events and their effects cannot be perceived with certainty, and accordingly, these estimates may change as new events occur, as more experience is acquired, as additional information is obtained and as our operating environment changes. While the Business believes that the estimates and assumptions used in the preparation of the combined financial statements are appropriate, actual results could differ from those estimates. Estimates are used for, but are not limited to, determining the following: allowance for doubtful accounts and inventory valuation reserves; recoverability of long-lived assets, including revenue recognition on long term contracts, valuation of goodwill; useful lives used in depreciation and amortization; income taxes and related valuation allowances; accruals for contingencies; actuarial assumptions to determine costs and liabilities related to employee benefit plans; stock-based compensation expense, valuation of derivatives and the fair value of assets acquired and liabilities assumed in acquisitions.

COST AND EQUITY-ACCOUNTED INVESTMENTS

Investments in privately held companies in which we do not have the ability to exercise significant influence, most often because we hold a voting interest of 0% to 20% are accounted for using the cost method. The carrying values of these investments as of December 31, 2016 and 2015 are $53 million and $13 million.

Associated companies are entities in which we do not have a controlling financial interest, but over which we have significant influence, most often because we hold a voting interest of 20% to 50%. Associated companies are accounted for as equity method investments. Results of associated companies are presented on a one-line basis. Investments in, and advances to, associated companies are presented on a one-line basis in the caption “All other assets” in our Combined Statement of Financial Position. See Note 16 for additional information.

10    GE O&G Annual FS

 

RESTRUCTURING COSTS

Costs of restructuring are accounted for according to FASB Accounting Standards Codification (“ASC”) 420,  Exit or Disposal Cost Obligations,  and other related pronouncements. ASC 420 requires that a liability for costs associated with an exit or disposal activity be recognized when the liability is incurred.

SEGMENT REPORTING

We conduct our operations through several business segments, which are organized based on the nature of markets and customers. Pursuant to ASC 280,  Segment Reporting , operating segments represent components of an enterprise for which separate financial information is available that is regularly evaluated by the chief operating decision maker in determining how to allocate resources and in assessing performance. The chief operating decision maker uses a variety of measures to assess the performance of the Business as a whole, depending on the nature of the activity. Operating activities are managed through four operating segments: Oilfield Services (OFS), Oilfield Equipment (OFE), Turbomachinery & Process Solutions (TPS) and Digital Solutions (DS). The performance of these four segments is principally measured based on revenues and operating profit.

SALES OF GOODS AND SERVICES

We record all sales of goods and services only when a firm sales agreement is in place, delivery has occurred or services have been rendered and collectability of the fixed or determinable sales price is reasonably assured.

Except for goods sold under long-term construction type contracts and service agreements, we recognize sales of goods under the provisions of U.S. Securities and Exchange Commission (SEC) Staff Accounting Bulletin (SAB) 104, Revenue Recognition .  In situations where arrangements include customer acceptance provisions based on seller or customer-specified objective criteria, we recognize revenue when we have reliably demonstrated that all specified acceptance criteria have been met or when formal acceptance occurs, respectively. We do not provide for anticipated losses before we record sales.

We recognize revenue on larger construction and equipment contracts using long-term construction accounting. We estimate total long-term contract revenue net of price concessions as well as total contract costs. For larger construction and equipment contracts, we recognize sales based on our progress toward contract completion measured by actual costs incurred in relation to our estimate of total expected costs. We routinely update our estimates of future costs for agreements in process and report any cumulative effects of such adjustments in current operations. We provide for any loss that we expect to incur on these agreements when that loss is probable.

We sell product services under long-term product maintenance agreements, where costs of performing services are incurred on other than a straight-line basis. We recognize related sales based on the extent of our progress toward completion measured by actual costs incurred in relation to our estimate of total expected costs. We routinely update our estimates of future costs for agreements in process and report any cumulative effects of such adjustments in current operations.

For our long term product maintenance agreements, we regularly assess customer credit risk inherent in the carrying amounts of receivables and contract costs and estimated earnings, including the risk that contractual penalties may not be sufficient to offset our accumulated investment in the event of customer termination. We gain insight into future utilization and cost trends, as well as credit risk, through our knowledge of the installed base of equipment and the close interaction with our customers that comes with supplying critical services and parts over extended periods. Revisions, after applying the cumulative catch up basis of accounting, may affect a product services agreement’s total estimated profitability resulting in an adjustment of earnings; such adjustments increased earnings by $293 million, $256 million and $145 million in 2016, 2015 and 2014, respectively. We provide for probable losses when they become evident.

11    GE O&G Annual FS

 
Arrangements for the sale of goods and services sometimes include multiple components. Our arrangements with multiple components usually involve an upfront deliverable of equipment and future service deliverables such as installation, commissioning, training or the future delivery of ancillary products. In most cases, the relative values of the undelivered components are not significant to the overall arrangement and are typically delivered within three to six months after the core product has been delivered. In such agreements, selling price is determined for each component and any difference between the total of the separate selling prices and total contract consideration (i.e., discount) is allocated pro rata across each of the components in the arrangement. The value assigned to each component is objectively determined and obtained primarily from sources such as the separate selling price for that or a similar item or from competitor prices for similar items. If such evidence is not available, we use our best estimate of selling price, which is established consistent with the pricing strategy of the Business and considers product configuration, geography, customer type, and other market specific factors

RESEARCH AND DEVELOPMENT

Research and development expenses are expensed as incurred and relate to the research and development of new products and services. These costs amounted to $352 million, $408 million and $420 million for the years ended December 31, 2016, 2015 and 2014, respectively.

SHIPPING AND HANDLING COSTS

Shipping and handling costs are presented gross. Amounts billed to a customer in a sale transaction related to shipping and handling, if any, represent revenues earned for the goods provided and the respective costs are expensed as incurred. These costs amounted to $182   million, $277   million, and $290   million in 2016, 2015 and 2014, respectively.

CASH AND EQUIVALENTS

Money market instruments with original maturities of three months or less are included in cash equivalents unless designated as available-for-sale and classified as investment securities.

As of December 31, 2016, $752 million of cash and equivalents were held in bank accounts and cannot be released, transferred or otherwise converted into a currency that is regularly transacted internationally, due to lack of market liquidity, capital controls or similar monetary or exchange limitations limiting the flow of capital out of the jurisdiction.

ALLOWANCE FOR DOUBTFUL ACCOUNTS

We establish an allowance for doubtful accounts based on various factors including the payment history and financial condition of our debtors and the economic environment. Provisions for doubtful accounts are recorded based on the aging status of the debtor accounts or when it becomes evident that the debtor will not make the required payments at either contractual due dates or in the future. The provision for doubtful accounts recorded was equal to $119 million, $102   million and $65 million for the years ended December 31, 2016, 2015 and 2014, respectively.

CONCENTRATION OF CREDIT RISK

We grant credit to our customers who primarily operate in the oil and natural gas industry. Although this concentration affects our overall exposure to credit risk, our current receivables are spread over a diverse group of customers across many countries, which mitigates this risk. We perform periodic credit evaluations of our customers’ financial conditions, including monitoring our customers’ payment history and current credit worthiness to manage this risk. We do not generally require collateral in support of our current receivables, but we may require payment in advance or security in the form of a letter of credit or a bank guarantee. As of December 31, 2016 and 2015, GE O&G had no customer balances that exceed 10% of GE O&G net customer receivables.

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INVENTORIES

All inventories are stated at the lower of cost or realizable values and they are measured on a first-in, first-out (FIFO) basis. As necessary, we record provisions and maintain reserves for excess, slow moving and obsolete inventory. To determine these reserve amounts, we regularly review inventory quantities on hand and compare them to estimates of future product demand, market conditions, production requirements and technological developments.

PROPERTY, PLANT AND EQUIPMENT (PP&E)

Property, plant and equipment is initially stated at cost and is depreciated over its estimated economic life. Subsequently, property, plant and equipment is measured at cost less accumulated depreciation and impairment losses. In 2015, we changed the method of depreciating our U.S. assets from an accelerated method based on a sum-of-the-years digits formula to a straight-line basis in order to align and harmonize our methodology for manufacturing plant and equipment. This change in estimate was made prospectively as of October 1, 2015, and had an immaterial impact for 2015. Since this date, our manufacturing plant and equipment is generally depreciated on a straight-line basis.

OTHER INTANGIBLE ASSETS

We amortize the cost of other intangible assets over their estimated useful lives unless such lives are deemed indefinite. The cost of intangible assets is generally amortized on a straight-line basis over the asset’s estimated economic life. Amortizable intangible assets are reviewed for impairment whenever events or changes in circumstances indicate that the related carrying amounts may not be recoverable. In these circumstances, they are tested for impairment based on undiscounted cash flows and, if impaired, written down to fair value based on either discounted cash flows or appraised values. Intangible assets with indefinite lives are tested annually for impairment and written down to fair value as required. Refer to the  Impairment of Goodwill and Other Long-Lived Assets accounting   policy.

IMPAIRMENT OF GOODWILL AND OTHER LONG-LIVED ASSETS

We perform an annual impairment test of goodwill on a qualitative or quantitative basis for each of our reporting units as of July 1 of each year, or more frequently when circumstances indicate an impairment may exist at the reporting unit level. When performing the annual impairment test we have the option of performing a qualitative or quantitative assessment to determine if an impairment has occurred. If a qualitative assessment indicates that it is more likely than not that the fair value of a reporting unit is less than its carrying amount, then we perform a quantitative impairment test for goodwill.

The quantitative impairment test consists of two different steps: in step one, the carrying value of the reporting unit is compared with its fair value; in step two, which is applied when the carrying value is more than its fair value, the amount of goodwill impairment, if any, is derived by deducting the fair value of the reporting unit’s assets and liabilities from the fair value of its equity, and comparing that amount with the carrying amount of goodwill. We determine fair values of each of the reporting units using the market approach, when available and appropriate, or the income approach, or a combination of both. We assess the valuation methodology based upon the relevance and availability of the data at the time we perform the valuation.

Valuations using the market approach are derived from metrics of publicly-traded companies or historically completed transactions of comparable businesses. The selection of comparable businesses is based on the markets in which the reporting units operate considering risk profiles, size, geography, and diversity of products and services.

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Under the income approach, fair value is determined based on the present value of estimated future cash flows, discounted at an appropriate risk-adjusted rate. We use our internal forecasts to estimate future cash flows and include an estimate of long-term future growth rate based on our most recent views of the long-term outlook for each business. Actual results may differ from those assumed in our forecasts. We derive our discount rates using a capital asset pricing model and analyzing published rates for industries relevant to our reporting units to estimate the cost of equity financing. We use discount rates that are commensurate with the risk and uncertainty inherent in the respective reporting units and in our internally developed forecast. 

We review PP&E, intangible assets and certain other long-lived assets for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable and at least annually for indefinite-lived intangible assets. When testing for impairment, we group our long-lived assets with other assets and liabilities at the lowest level for which identifiable cash flows are largely independent of the cash flows of other assets and liabilities (or asset group). The determination of recoverability is made based upon the estimated undiscounted future net cash flows. The amount of impairment loss, if any, is determined by comparing the fair value, as determined by a discounted cash flow analysis, with the carrying value of the related assets.

FINANCIAL INSTRUMENTS

Our financial instruments include cash and equivalents, current receivables, investments, trade payables, short and long-term debt, and derivative financial instruments. Except for long-term debt, the estimated fair value of our financial instruments at December 31, 2016 and 2015 approximates their carrying value as reflected in our Combined Statement of Financial Position. For further information on the fair value of our debt, see Note 17 .

We monitor our exposure to various business risks including commodity prices and foreign currency exchange rates and we regularly use derivative financial instruments to manage these risks. Although GE policies do not permit the use of derivative financial instruments for speculative purposes, derivative financial instruments may be classified as trading for accounting purposes. At the inception of a new derivative, we designate the derivative as a hedge or we determine the derivative to be undesignated as a hedging instrument. We document the relationships between the hedging instruments and the hedged items, as well as our risk management objectives and strategy for undertaking various hedge transactions. We assess whether the derivatives that are used in hedging transactions are highly effective in offsetting changes in cash flows of the hedged item at both the inception of the hedge and on an ongoing basis.

We have a program that utilizes foreign currency forward contracts to reduce the risks associated with the effects of certain foreign currency exposures. Under this program, our strategy is to have gains or losses on the foreign currency forward contracts mitigate the foreign currency transaction and translation gains or losses to the extent practical. These foreign currency exposures typically arise from changes in the value of assets (for example, current receivables) and liabilities (for example, current payables) which are denominated in currencies other than the functional currency. We record all derivatives as of the end of our reporting period in our Combined Statement of Financial Position at fair value. For the forward contracts held as undesignated hedging instruments, we record the changes in fair value of the forward contracts in our Combined Statements of Income along with the change in the fair value, related to foreign exchange movements, of the hedged item. Changes in the fair value of forward contracts designated as cash flow hedging instruments are recognized in other comprehensive income (loss) until the hedged item is recognized in earnings. If derivatives designated as a cash flow hedge are determined to be ineffective, the ineffective portion of that derivative’s change in fair value is recognized in earnings.

We had outstanding foreign currency forward contracts with notional amounts aggregating $6,430 million and $8,017 million at December 31, 2016 and 2015, respectively, to hedge exposure to currency fluctuation in various foreign currencies. We also have embedded derivatives with notional amounts aggregating $620   million and $891   million at December 31, 2016 and December 2015, respectively. Based on quoted market prices as of December 31, 2016, 2015 and 2014 for forward contracts with similar terms and maturity dates, we recorded losses, both realized and unrealized, of $273 million, $117 million and $109 million, respectively, to adjust these forward contracts to their fair market value. The impact of commodity forward contracts on earnings was immaterial for the years ended December 31, 2016, 2015 and 2014.

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FAIR VALUE MEASUREMENTS

The following sections describe the valuation methodologies we use to measure financial instruments and non-financial instruments within pension plans accounted for at fair value.

For financial assets and liabilities measured at fair value on a recurring basis, fair value is the price we would receive to sell an asset or pay to transfer a liability in an orderly transaction with a market participant at the measurement date. In the absence of active markets for the identical assets or liabilities, such measurements involve developing assumptions based on market observable data and, in the absence of such data, internal information that is consistent with what market participants would use in a hypothetical transaction that occurs at the measurement date.

Observable inputs reflect market data obtained from independent sources, while unobservable inputs reflect our market assumptions. Preference is given to observable inputs. These two types of inputs create the following fair value hierarchy:

 	Level 1 -	Quoted prices for identical instruments in active markets.	

 	Level 2 -	Quoted prices for similar instruments in active markets; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations whose inputs are observable or whose significant value drivers are observable.	

 	Level 3 -	Significant inputs to the valuation model are unobservable.	

We maintain policies and procedures to value instruments using the best and most relevant data available. In addition, we perform reviews to assess the reasonableness of the valuations. With regard to Level 3 valuations (including instruments valued by third parties), we perform a variety of procedures to assess the reasonableness of the valuations. Such reviews include an evaluation of instruments whose fair value change exceeds predefined thresholds (and/or does not change) and consider the current interest rate, currency and credit environment, as well as other published data, such as rating agency market reports and current appraisals. These reviews are performed by risk manager. A detailed review of methodologies and assumptions is performed by individuals independent of the business for individual measurements with a fair value exceeding predefined thresholds. This detailed review may include the use of a third-party valuation firm.

RECURRING FAIR VALUE MEASUREMENTS

The following sections describe the valuation methodologies we use to measure different financial instruments at fair value on a recurring basis.

Investments in Debt and Equity Securities within Pension Plan Assets

When available, we use quoted market prices to determine the fair value of investment securities, which form part of our pension plan assets, and they are included in Level 1. Level 1 securities primarily include publicly traded equity securities.

For large numbers of investment securities for which market prices are observable for identical or similar investment securities but not readily accessible for each of those investments individually (that is, it is difficult to obtain pricing information for each individual investment security at the measurement date), we obtain pricing information from our independent pricing vendors. The independent pricing vendors use various pricing models for each asset class that are consistent with what other market participants would use. The inputs and assumptions to the model of the pricing vendors are derived from market observable sources including: benchmark yields, reported trades, broker/dealer quotes, issuer spreads, benchmark securities, bids, offers, and other market-related data. Since many fixed income securities do not trade on a daily basis, the methodology of the pricing vendors use available information as applicable such as benchmark curves, benchmarking of like securities, sector groupings, and matrix pricing. The pricing vendors consider available market observable inputs in determining the evaluation for a security. Thus, certain securities may not be priced using quoted prices, but rather determined from market observable information. These investments are included in Level 2 and primarily comprise our portfolio of corporate fixed income, and government, mortgage and asset-backed securities. In infrequent circumstances, an independent pricing vendor may provide us with valuations that are based on significant unobservable inputs, and in those circumstances we classify the investment securities in Level 3.

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Annually, we conduct reviews of independent pricing vendors to validate that the inputs used in that vendor’s pricing process are deemed to be market observable as defined in the applicable standard. While we are not provided access to proprietary models of the vendor, our reviews have included on-site walk-throughs of the pricing process, methodologies and control procedures for each asset class and level for which prices are provided. Our reviews also include an examination of the underlying inputs and assumptions for a sample of individual securities across asset classes, credit rating levels and various durations. In addition, the pricing vendors have an established challenge process in place for all security valuations, which facilitates identification and resolution of potentially erroneous prices. We believe that the prices received from pricing vendors are representative of prices that would be received to sell the assets at the measurement date (exit prices) and are classified appropriately in the hierarchy.

We use non-binding broker quotes and other third-party pricing services as our primary basis for valuation when there is limited, or no, relevant market activity for a specific instrument or for other instruments that share similar characteristics. We have not adjusted the prices we have obtained. Investment securities priced using non-binding broker quotes and other third-party pricing services are included in Level 3. As is the case with the independent pricing vendor, third-party brokers and other third-party pricing services do not provide access to their proprietary valuation models, inputs and assumptions. Accordingly, our risk management personnel conduct reviews of vendors, as applicable, similar to the reviews performed of the independent pricing vendor. In addition, we conduct internal reviews of pricing for all such investment securities quarterly to ensure reasonableness of valuations used in our combined financial statements. These reviews are designed to identify prices that appear stale, those that have changed significantly from prior valuations, and other anomalies that may indicate that a price may not be accurate. Based on the information available, we believe that the fair values provided by the brokers and other third-party pricing services are representative of prices that would be received to sell the assets at the measurement date (exit prices).

Investments in private equity, real estate and collective funds held within our pension plans, are generally valued using the net asset value (NAV) per share as a practical expedient for fair value provided certain criteria are met. The NAVs are determined based on the fair values of the underlying investments in the funds. On January 1, 2016, we adopted guidance whereby investments that are measured at fair value using the NAV practical expedient are no longer classified in the fair value hierarchy.

Derivatives

We use closing prices for derivatives included in Level 1, which are traded either on exchanges or liquid over-the-counter markets.

The majority of our derivatives are valued using internal models. The models maximize the use of market observable inputs including interest rate curves and both forward and spot prices for currencies and commodities. Derivative assets and liabilities included in Level 2 primarily represent foreign currency and commodity forward contracts for the Business.

NON-RECURRING FAIR VALUE MEASUREMENTS

Certain assets are measured at fair value on a non-recurring basis within the pension plans. These assets are not measured at fair value on an ongoing basis, but are subject to fair value adjustments only in certain circumstances. These assets can include long-lived assets that have been reduced to fair value when they are held for sale, cost and equity method investments and long-lived assets that are written down to fair value when they are impaired and the remeasurement of retained investments in formerly consolidated subsidiaries upon a change in control that results in deconsolidation of a subsidiary, if we sell a controlling interest and retain a noncontrolling stake in the entity. Assets that are written down to fair value when impaired and retained investments are not subsequently adjusted to fair value unless further impairment occurs.

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Cost and Equity Method Investments

Cost and equity method investments are valued using market observable data such as quoted prices when available. When market observable data is unavailable, investments are valued using a discounted cash flow model, comparative market multiples or a combination of both approaches as appropriate and other third-party pricing sources.

Long-lived Assets

Fair values of long-lived assets, including real estate, are primarily derived internally and are based on observed sales transactions for similar assets. In other instances, for example, collateral types for which we do not have comparable observed sales transaction data, collateral values are developed internally and corroborated by external appraisal information. Adjustments to third-party valuations may be performed in circumstances where market comparables are not specific to the attributes of the specific collateral or appraisal information may not be reflective of current market conditions due to the passage of time and the occurrence of market events since receipt of the information.

INCOME TAXES

The Business is included in the consolidated U.S. federal, foreign and state income tax returns of GE, where allowable by law. The Business determines its current and deferred taxes based on the separate return method (i.e., as if the Business were a taxpayer separate from GE). All income taxes due to or due from the Business’ parent that have not been settled or recovered by the end of the period are reflected in Note 14 as such balances will be maintained and settled. Any differences between actual amounts paid or received by the Business and taxes accrued under the separate return method have been reflected in the GE net investment account.
The Business accounts for taxes under the asset and liability method. Under this method, deferred income taxes are recognized for temporary differences between the financial statement and tax return bases of assets and liabilities as well as from net operating losses and tax credit carryforwards, based on enacted tax rates expected to be in effect when taxes actually are paid or recovered and other provisions of the tax law. The effect of a change in tax laws or rates on deferred tax assets and liabilities is recognized in income in the period in which such change is enacted. Future tax benefits are recognized to the extent that realization of such benefits is more likely than not, and a valuation allowance is established for any portion of a deferred tax asset that management believes may not be realized.
We currently intend to indefinitely reinvest substantially all earnings of our foreign subsidiaries with operations outside the U.S. and, accordingly, have not provided U.S. income tax on such income.
Significant judgment is required in determining our tax expense and in evaluating our tax positions, including evaluating uncertainties. We operate in more than 120 countries and our tax filings are subject to audit by the tax authorities in the jurisdictions where we conduct business. These audits may result in assessments of additional taxes that are resolved with the tax authorities or through the courts. We have provided for the amounts we believe will ultimately result from these proceedings. The Business recognizes uncertain tax positions that are “more likely than not” to be sustained if the relevant tax authority were to audit the position with full knowledge of all the relevant facts and other information. For those tax positions that meet this threshold, the Business measures the amount of tax benefit based on the largest amount of tax benefit that the Business has a greater than 50% chance of realizing in a final settlement with the relevant authority. The Business classifies interest and penalties associated with uncertain tax positions as interest expense and provision for income taxes, respectively, on the Combined Statement of Income (Loss). The effects of tax adjustments and settlements from taxing authorities are presented in the combined financial statements in the period they are recorded.
POSTRETIREMENT BENEFITS

Certain employees and retirees of the Business participate in postretirement benefit plans, sponsored by either the Business or GE:

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Multiemployer Plans (sponsored by GE)

These plans are accounted in accordance with ASC Subtopic 715-80 Compensation—Retirement Benefits—Multiemployer Plans  (see Note 12).

Pension Benefits (sponsored by the Business)

These plans are accounted for under the provisions of ASC Subtopic 715-20, Compensation – Retirement   Benefits: Defined Benefit Plans  (see Note 12). In accordance with ASC 715-20, management categorizes plan assets for disclosure purposes in accordance with the fair value hierarchy as set forth in ASC 820,  Fair Value Measurements and Disclosures.

Pension benefits are calculated using significant inputs to the actuarial models that measure pension benefit obligations and related effects on operations. Two assumptions, discount rate and expected return on assets, are important elements of plan expense and asset/liability measurement. We evaluate these critical assumptions at least annually on a plan and country-specific basis. We periodically evaluate other assumptions involving demographic factors such as retirement age, mortality and turnover, and update them to reflect our experience and expectations for the future. Actual results in any given year will often differ from actuarial assumptions because of economic and other factors.
Projected benefit obligations are measured as the present value of expected payments. We discount those cash payments using the weighted average of market-observed yields for high-quality fixed-income securities with maturities that correspond to the payment of benefits. Lower discount rates increase present values and generally subsequent-year pension expense; higher discount rates decrease present values and generally subsequent-year pension expense.
The weighted average discount rates for our pension plans at December 31, 2016, 2015 and 2014 were equal to 3.41%, 3.83% and 3.69%, respectively, reflecting market interest rates.
To determine the expected long-term rate of return on pension plan assets, we consider current and target asset allocations, as well as historical and expected returns on various categories of plan assets. In developing future long-term return expectations for our principal benefit plans’ assets, we formulate views on the future economic environment, both in the US and abroad. We evaluate general market trends and historical relationships among a number of key variables that impact asset class returns such as expected earnings growth, inflation, valuations, yields and spreads, using both internal and external sources. We also take into account expected volatility by asset class and diversification across classes to determine expected overall portfolio results given current and target allocations.
Based on our analysis of future expectations of asset performance, past return results, and our current and target asset allocations, we have assumed a weighted average 6.98% long-term expected return on those assets for cost recognition in 2017 compared to 6.86% in 2016 and 6.91% in 2015.
Changes in key assumptions for our pension plans would have the following effects:
 	·	Discount rate - A 25 basis point increase in discount rate would decrease pension cost in the following year by $2 million and would decrease the pension benefit obligation at year-end by about $30 million.	

 	·	Expected return on assets - A 50 basis point decrease in the expected return on assets would increase pension cost in the following year by $3   million.	

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ACCOUNTING CHANGES
 
On September 30, 2016, we adopted ASU 2016-09, Improvements to Employee Share-Based Payment Accounting, which was intended to simplify several aspects of the accounting for employee share-based payment transactions including the accounting for income taxes, forfeitures, and statutory tax withholding requirements, as well as classification in the Combined Statement of Cash Flows.  Application of the requirements from January 1, 2016 resulted in an immaterial impact to the combined financial statements.

On January 1, 2016, we adopted ASU No. 2015-17, Balance Sheet Classification of Deferred Taxes, which amends existing guidance on income taxes to require the classification of all deferred tax assets and liabilities as non-current on the statement of financial position.  The adoption of ASU 2015-17 did not result in an impact to the combined financial statements.

On January 1, 2016, we adopted ASU 2015-16, Simplifying the Accounting for Measurement-Period Adjustments, which eliminated the requirement for an acquirer in a business combination to account for measurement-period adjustments retrospectively. See Note 3 for further discussion of the purchase accounting effects of recent acquisitions.
 
On January 1, 2016, we adopted ASU 2015-02, Amendments to the Consolidation Analysis. The ASU amended the consolidation guidance for VIEs and general partners’ investment in limited partnerships and modified the evaluation of whether limited partnerships and similar legal entities are VIEs or voting interest entities. The adoption of ASU 2015-02 did not result in an impact to the combined financial statements.

In the second quarter of 2014, the Business adopted Accounting Standards Update (ASU) 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity , which raised the threshold for a disposal to qualify as a discontinued operation and expanded the disclosure requirements for those transactions that meet the new criteria to be classified as discontinued operations. To be classified as a discontinued operation, the disposal of a component or group of components must represent a strategic shift that has, or will have, a major effect on an entity’s operations and financial results. The ASU also expands the disclosure requirements for those transactions that meet the new criteria to be classified as discontinued operations. The revised accounting guidance applies prospectively to all disposals (or classifications as held for sale) of components of an entity and for businesses that, upon acquisition, are classified as held for sale on or after adoption. Early adoption is permitted for disposals (or classifications as held for sale) that have not been previously reported in financial statements. The effects of applying the revised guidance will vary based upon the nature and size of future disposal transactions.
 
On January 1, 2014, we adopted ASU 2013-11, Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists . Under the new guidance, an unrecognized tax benefit is required to be presented as a reduction to a deferred tax asset if the disallowance of the tax position would reduce the available tax loss or tax credit carryforward instead of resulting in a cash tax liability. The adoption of ASU 2013-11 resulted in an immaterial impact to the combined financial statements.

On January 1, 2014, we adopted ASU 2013-05, Foreign Currency Matters (Topic 830): Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity . Under the revised guidance, the entire amount of the cumulative translation adjustment associated with the foreign entity will be released into income in the following circumstances: (a) the sale of a subsidiary or group of net assets within a foreign entity that represents a complete or substantially complete liquidation of that entity, (b) the loss of a controlling financial interest in an investment in a foreign entity, or (c) when the accounting for an investment in a foreign entity changes from the equity method to full consolidation. The revised guidance applies prospectively to transactions or events occurring on or after January 1, 2014.

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NEW ACCOUNTING STANDARDS UPDATE

In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers.  The ASU will supersede most of the existing revenue recognition requirements in U.S. GAAP and will require entities to recognize revenue at an amount that reflects the consideration to which the Company expects to be entitled in exchange for transferring goods or services to a customer.  The new standard also requires significantly expanded disclosures regarding the qualitative and quantitative information of an entity’s nature, amount, timing, and uncertainty of revenue and cash flows arising from contracts with customers.  The pronouncement is effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period.

The standard permits either a full retrospective method of adoption, in which the standard is applied to all the periods presented, or a modified retrospective method of adoption, in which the standard is applied only to the current period with a cumulative-effect adjustment reflected in retained earnings.  We will adopt the standard on January 1, 2018, will apply it retrospectively to all periods presented, and will elect the practical expedient for contract modifications.
The new standard requires companies to identify contractual performance obligations and determine whether revenue should be recognized at a point in time or over time based on when control of goods and services transfer to a customer.  As a result, we expect changes in the presentation of our financial statements, including: (1) timing of revenue recognition, and (2) changes in classification between revenue and costs.  The new standard will have no cash impact and, as such, does not affect the economics of our underlying customer contracts.  The effect of applying the new guidance to our existing book of contracts will result in lower reported earnings in 2018 (and comparative periods previously reported) and in the early years after adoption.  However, we expect to experience an increase in reported earnings, on that existing book of contracts, as they mature.

We expect that the timing of revenue recognition on our long-term product service agreements will be significantly affected.  Although we expect to continue to recognize revenue over time on these contracts, we also expect that there will be changes to how contract modifications, termination clauses and purchase options are accounted for by us.  In particular, under our existing processes, the cumulative impact from a contract modification on revenue already recorded is recognized in the period in which the modification is agreed.  Under the new standard, we expect the impact from certain types of modifications to be recognized over the remaining life of the contract.

In February 2016, the FASB issued ASU No. 2016-02, Leases.  The new standard establishes a right-of-use (ROU) model that requires a lessee to record a ROU asset and a lease liability on the balance sheet for all leases with terms longer than 12 months.  Leases will be classified as either finance or operating, with classification affecting the pattern of expense recognition.  Similarly, lessors will be required to classify leases as sales-type, finance or operating, with classification affecting the pattern of income recognition.  Classification for both lessees and lessors will be based on an assessment of whether risks and rewards as well as substantive control have been transferred through a lease contract.  The new standard is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years, with early adoption permitted.  A modified retrospective transition approach is required for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements, with certain practical expedients available.  While we continue to evaluate the effect of the standard on our ongoing financial reporting, we anticipate that the adoption of the ASU may materially affect our consolidated and combined financial statements.

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In October 2016, the FASB issued ASU No. 2016-16, Accounting for Income Taxes: Intra-Entity Asset Transfers of Assets Other than Inventory.  The ASU eliminates the deferral of tax effects of intra-entity asset transfers other than inventory.  As a result, the tax expense from the intercompany sale of assets, other than inventory, and associated changes to deferred taxes will be recognized when the sale occurs even though the pre-tax effects of the transaction have not been recognized. The new standard is effective for annual periods beginning after December 15, 2017, and interim periods within those annual periods. The effect of the adoption of the standard will depend on the nature and amount of future transactions but is currently expected as an increase to retained earnings of approximately $300 million.  Future earnings will be reduced in total by this amount.  The effect of the change on future transactions will depend on the nature and amount of future transactions as it will affect the timing of recognition of both tax expenses and tax benefits, with no change in the associated cash flows.
In March 2017, the FASB issued ASU No. 2017-07, Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost, which changes the income statement presentation of net periodic benefit cost by requiring separation between the service cost component and all other components.  The service cost component is required to be presented as an operating expense with other similar compensation costs arising for services rendered by the pertinent employees during the period.  The non-operating components must be presented outside of income from operations.  This pronouncement is effective for annual reporting periods beginning after December 15, 2017, and the presentation disclosure should be applied using a retrospective approach.  Early adoption is permitted.  We will adopt this standard on January 1, 2018.

All other new accounting pronouncements that have been issued but not yet effective are currently being evaluated and at this time are not expected to have a material impact on our financial position or results of operations.

 

 

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NOTE 3	ACQUISITIONS AND DISPOSITIONS	
ACQUISITIONS
On June 2, 2014, we acquired 100% ownership of Cameron’s Reciprocating Compression division (“ Cameron ”) for $550 million. Cameron provides reciprocating compression equipment and aftermarket services for oil and gas production, gas processing, gas distribution and independent power industries. Cameron is included in our TPS segment. The purchase price allocation resulted in goodwill of $280 million and amortizable intangible assets of $95 million.

DISPOSITIONS
On June 30, 2015, we completed the sale of the Industrial Air & Gas Technology (“IAGT”) business for a selling price of $185 million and a pre-tax gain of $71 million. IAGT primarily sells to the industrial space focused on the movement of liquids/hydrocarbons through pipe either through blower or compression equipment. IAGT was included in our TPS segment.

On June 20, 2014, we completed the sale of the Wayne Fueling Systems (“Wayne”) business, a manufacturer of retail fuel dispensers, payment devices, forecourt control systems and peripheral equipment for a selling price of $485 million, recording a pre-tax gain of $53 million. Wayne Fueling Systems was included in our DS segment.

The pre-tax gains from the sale of these businesses have been recognized as part of “Other expenses / (income), net” in the Combined Statement of Income (Loss).
NOTE 4	CURRENT RECEIVABLES	

December 31 (In millions)	 	2016	 	 	2015	 	
Customer receivables	 	$	1,699	 	 	$	2,011	 	
Related parties	 	 	236	 	 	 	233	 	
Sundry receivables	 	 	814	 	 	 	751	 	
 	 	 	2,749	 	 	 	2,995	 	
Less allowance for losses	 	 	(186	)	 	 	(177	)	
Total	 	$	2,563	 	 	$	2,818	 	

Customer receivables are recorded at the invoiced amount less an allowance for doubtful accounts. Beyond factoring activities with related parties (as described in Note 20), the Business also sells certain current receivables externally, which are accounted for in accordance with  ASC 860, Transfers and Servicing .  Sundry receivables primarily consist of advance payments to suppliers and value added tax receivables.

December 31 (In millions)	 	2016	 	 	2015	 	
Receivables syndicated externally	 	$	257	 	 	$	330	 	

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NOTE 5	INVENTORIES	
Inventories, net of reserves of $260 million and $274 million in 2016 and 2015, respectively, are comprised of the following at December 31:

December 31 (In millions)	 	2016	 	 	2015	 	
 	 	 	 	 	 	 	
Raw materials and work in process	 	$	1,639	 	 	$	1,978	 	
Finished goods	 	 	1,585	 	 	 	1,693	 	
Total	 	$	3,224	 	 	$	3,671	 	

NOTE 6	PROPERTY, PLANT AND EQUIPMENT	
                  
 	 	Depreciable lives
(in years)	 	 	Original Cost	 	 	Net Carrying Value	 	
December 31 (Dollars in millions)	 	 	 	 	2016	 	 	2015	 	 	2016	 	 	2015	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Land and improvements	 	 	8(a	)	 	$	130	 	 	$	164	 	 	$	125	 	 	$	160	 	
Buildings, structures and related equipment	 	 	8-40	 	 	 	995	 	 	 	526	 	 	 	878	 	 	 	462	 	
Machinery and equipment	 	 	4-20	 	 	 	2,916	 	 	 	3,266	 	 	 	1,054	 	 	 	1,414	 	
Leasehold costs and manufacturing plant under construction	 	 	1-10	 	 	 	349	 	 	 	581	 	 	 	268	 	 	 	518	 	
Total	 	 	 	 	 	$	4,390	 	 	$	4,537	 	 	$	2,325	 	 	$	2,554	 	
(a) Depreciable lives exclude land.

23    GE O&G Annual FS

 

NOTE 7	GOODWILL	
After initial recognition, goodwill is measured net of any accumulated impairment losses. Changes in the carrying amount of goodwill for the fiscal year ended December 31, 2016 and December 31, 2015, by operating segment, are as follows:

(In millions)	 	OFS	 	 	OFE	 	 	TPS	 	 	DS	 	 	Total	 	
Balance at December 31, 2014 - gross	 	$	2,907	 	 	$	3,947	 	 	$	1,891	 	 	$	2,166	 	 	$	10,911	 	
Accumulated impairments at December 31, 2014	 	 	(553	)	 	 	(867	)	 	 	-	 	 	 	(254	)	 	 	(1,674	)	
Balance at December 31, 2014	 	$	2,354	 	 	$	3,080	 	 	$	1,891	 	 	$	1,912	 	 	$	9,237	 	
Acquisitions and purchase accounting adjustments	 	 	-	 	 	 	22	 	 	 	32	 	 	 	-	 	 	 	54	 	
Dispositions	 	 	-	 	 	 	-	 	 	 	(42	)	 	 	-	 	 	 	(42	)	
Currency translation	 	 	(22	)	 	 	(129	)	 	 	(28	)	 	 	(123	)	 	 	(302	)	
Impairments	 	 	(2,080	)	 	 	-	 	 	 	-	 	 	 	-	 	 	 	(2,080	)	
Balance at December 31, 2015	 	 	252	 	 	 	2,973	 	 	$	1,853	 	 	$	1,789	 	 	$	6,867	 	
Acquisitions and purchase accounting adjustments	 	 	-	 	 	 	19	 	 	 	(1	)	 	 	-	 	 	 	18	 	
Currency translation	 	 	(106	)	 	 	(7	)	 	 	(38	)	 	 	(54	)	 	 	(205	)	
Balance at December 31, 2016	 	$	146	 	 	$	2,985	 	 	$	1,814	 	 	$	1,735	 	 	$	6,680	 	

In performing the annual impairment test for goodwill in the third quarter of 2015 using data as of July 1 of that year, we determined that a step two test was required for a reporting unit within our OFS operating segment. As a consequence of the continued pressure on oil prices, the revised expected cash flows for this reporting unit resulted in a goodwill impairment charge of $2,080 million. The impairment charge has been included as part of “Impairment of goodwill” in the Combined Statement of Income (Loss).  As of December 31, 2016, we believe that the goodwill is recoverable for all of the reporting units; however, there can be no assurance that the goodwill will not be impaired in future periods.

 
24    GE O&G Annual FS

 

NOTE 8	OTHER INTANGIBLE ASSETS	

DEFINITE LIVES INTANGIBLES	 	 	2016	 	 	2015	 	
December 31
(Dollars in millions)	 	Useful life (in years)	 	 	Gross carrying amount	 	 	Accumulated amortization	 	 	Net	 	 	Gross carrying amount	 	 	Accumulated amortization	 	 	Net	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Customer-related	 	 	15-25	 	 	$	1,920	 	 	$	(660	)	 	$	1,260	 	 	$	1,959	 	 	$	(585	)	 	$	1,374	 	
Patents & technology	 	 	14-25	 	 	 	596	 	 	 	(371	)	 	 	225	 	 	 	634	 	 	 	(348	)	 	 	286	 	
Capitalized software	 	 	4-5	 	 	 	896	 	 	 	(535	)	 	 	361	 	 	 	804	 	 	 	(432	)	 	 	372	 	
Trademarks	 	 	18-30	 	 	 	681	 	 	 	(130	)	 	 	551	 	 	 	698	 	 	 	(108	)	 	 	590	 	
Other	 	 	 	 	 	 	1	 	 	 	(1	)	 	 	-	 	 	 	3	 	 	 	(1	)	 	 	2	 	
Total	 	 	 	 	 	$	4,094	 	 	$	(1,697	)	 	$	2,397	 	 	$	4,098	 	 	$	(1,474	)	 	$	2,624	 	

During 2016 and 2015, we recorded additions to intangible assets subject to amortization of $153 million and $226 million, respectively, primarily driven by capitalized software.

Oil & Gas amortization expense related to intangible assets subject to amortization amounted to $272 million, $245 million and $251 million in 2016, 2015 and 2014, respectively.

Estimated amortization expense for each of the subsequent five fiscal years is expected to be as follows:

(In millions)	 	2017	 	 	2018	 	 	2019	 	 	2020	 	 	2021	 	
Estimated amortization expense	 	$	234	 	 	$	225	 	 	$	200	 	 	$	164	 	 	$	148	 	

INDEFINITE LIVED INTANGIBLES	2016	 	2015	 	
December 31 (In millions)	Gross carrying amount	 	Gross carrying amount	 	
Indefinite lived intangible assets	 	$	52	 	 	$	52	 	

Indefinite-lived intangible assets as of December 31, 2016 and 2015 comprise trademarks acquired in previous years (Vetco and Bently Nevada trademarks for $42 million and $10 million, respectively).

 
25    GE O&G Annual FS

 

NOTE 9	CONTRACT ASSETS	

December 31 (In millions)	 	2016	 	 	2015	 	
   Long-term product service agreements (a)	 	$	1,046	 	 	$	928	 	
   Long-term equipment contract revenue (b)	 	 	703	 	 	 	502	 	
Total revenue in excess of billings	 	 	1,749	 	 	 	1,430	 	
   Deferred inventory costs (c)	 	 	218	 	 	 	236	 	
Contract Assets	 	$	1,967	 	 	$	1,666	 	

(a) Reflects revenues earned in excess of billings on our long-term product service agreements.
(b) Reflects revenues earned in excess of billings on our long-term contracts to construct technically complex equipment.
(c) Represents cost deferral for shipped goods and other costs for which the criteria for revenue recognition has not yet been met.

NOTE 10	ACCOUNTS PAYABLE	

December 31 (In millions)	 	2016	 	 	2015	 	
Trade payables	 	$	1,368	 	 	$	1,583	 	
Related parties (a)	 	 	530	 	 	 	639	 	
Total	 	$	1,898	 	 	$	2,222	 	

(a) Refer to Note 20 for further information.

 
26    GE O&G Annual FS

 

NOTE 11	BORROWINGS	

December 31 (Dollars in millions)	 	 	 	2016	 	 	2015	 	
Short-term borrowings	 	 	 	Amount	 	 	Weighted
Average Rate(a)	 	 	Amount	 	 	Weighted
Average Rate(a)	 	
Short-term bank borrowings	 	 	 	 	$	79	 	 	 	9.1	%	 	$	237	 	 	 	16.8	%	
Intercompany borrowings (b)	 	 	 	 	 	121	 	 	 	 	 	 	 	134	 	 	 	 	 	
Current portion of long term borrowings	 	 	 	 	 	34	 	 	 	1.3	 	 	 	2	 	 	 	1.1	 	
Other	 	 	 	 	 	5	 	 	 	1.3	 	 	 	11	 	 	 	2.7	 	
Total short-term borrowings	 	 	 	 	$	239	 	 	 	 	 	 	$	384	 	 	 	 	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Long-term borrowings	 	Maturities	 	Amount	 	 	Weighted
Average Rate(a)	 	 	Amount	 	 	Weighted
Average Rate(a)	 	
Long-term bank borrowings	 	 	2018-2024	 	 	$	2	 	 	 	4.1	%	 	$	3	 	 	 	2.9	%	
Capital leases	 	 	 	 	 	 	1	 	 	 	4.5	 	 	 	2	 	 	 	4.5	 	
Notes payable	 	 	 	 	 	 	35	 	 	 	1.0	 	 	 	8	 	 	 	4.8	 	
Total long-term borrowings	 	 	 	 	 	$	38	 	 	 	 	 	 	$	13	 	 	 	 	 	

(a)	Based on year-end balances and year-end local currency effective interest rates, including the effects from hedging.	

(b)	Refer to Note 20 for further information.	

The estimated fair value of the bank borrowings at December 31, 2016 and 2015 was equal to $183 million and $254 million, respectively. We estimate fair values based on valuation methodologies using current market interest rate data that are comparable to market quotes adjusted for our non-performance risk.

Liquidity is affected by debt maturities and our ability to repay or refinance such debt. External debt maturities, which include bank borrowings and notes payable, over the next five years follows:

(In millions)	 	2017	 	 	2018	 	 	2019	 	 	2020	 	 	2021	 	
External debt maturities	 	$	113	 	 	$	6	 	 	$	24	 	 	$	-	 	 	$	-	 	

 

27    GE O&G Annual FS

 
NOTE 12	POSTRETIREMENT BENEFIT PLANS	
Certain U.S. employees are covered under various U.S. GE employee benefit plans, including GE’s retirement plans (pension, retiree health and life insurance, and savings benefit plans). In addition, certain UK employees participate in the GE UK Pension Plan.
We are allocated relevant participation costs for these GE employee benefit plans. As such, we have not recorded any liabilities associated with our participation in these plans in our Combined Statement of Financial Position as of December 31, 2016 and 2015. Expenses associated with our employees’ participation in the U.S. GE postretirement benefit plans were equal to $133 million, $134 million, $160 million for the years ended December 31, 2016, 2015 and 2014, respectively.

During 2016, two UK pension plans sponsored by the Business, the 1987 Vetco Gray Hughes Pension Plan and the UK Dresser Pension Scheme, were merged into the GE UK Pension Plan. The Business has agreed to pay deficit contributions for the next 10 years.  The estimated present value of these payments is $32 million and is recorded in the Combined Statement of Financial Position in “All other liabilities.”  Subsequent to that merger, plan participants in these respective plans participate in the GE UK Pension Plan. In addition, certain other business employees also participate in the GE UK Pension Plan. Expenses associated with our employees’ participation in the GE UK Pension Plan were equal to $7 million, $14 million, and $15 million for the years ended December 31, 2016, 2015 and 2014, respectively.

PENSION PLANS

In addition to these GE plans, certain of our employees are also covered by pension plans sponsored by the Business. Our pension plans in 2016 included eight U.S. and non-U.S. pension plans with pension assets or obligations greater than $20 million. We use a December 31 measurement date for these plans. These defined benefit plans generally provide benefits to employees based on formulas recognizing length of service and earnings.

PENSION PLAN PARTICIPANTS AS OF DECEMBER 31, 2016
 	 	 	 	
Active employees	 	 	2,210	 	
Vested former employees	 	 	2,710	 	
Retirees and beneficiaries	 	 	4,515	 	
Total	 	 	9,435	 	

The amount we report in our income as pension cost consists of the following components:
 	·	Service cost - the cost of benefits earned by active employees who participate in the plan.	

 	·	Prior service cost amortization – the cost of changes to our benefit plans (plan amendments) related to prior service performed.	

 	·	Expected return on plan assets – the return we expect to earn on plan investments used to pay future benefits.	

 	·	Interest cost – the accrual of interest on the pension obligations due to the passage of time.	

 	·	Net actuarial loss (gain) amortization – differences between our estimates (for example, discount rate, expected return on plan assets) and our actual experience which are initially recorded in equity and amortized into income.	

 	·	Curtailment gain/loss – income effects of amounts previously deferred that have been accelerated because of an event that shortens future service or eliminates future benefits (for example, a sale of a business).	

 

28    GE O&G Annual FS

COST OF PENSION PLANS

(In millions)	 	2016	 	2015	 	 	 	2014	 	
Service cost for benefits earned	 	$	18	 	 	 	$	24	 	 	 	$	21	 	
Expected return on plan assets	 	 	(46	)	 	 	 	(65	)	 	 	 	(61	)	
Interest cost on benefit obligations	 	 	34	 	 	 	 	49	 	 	 	 	55	 	
Net actuarial loss amortization	 	 	14	 	 	 	 	21	 	 	 	 	9	 	
Net settlement / curtailment loss (gain)	 	 	(26	)	(b)	 	 	4	 	(a)	 	 	-	 	
Pension cost	 	$	(6	)	 	 	$	33	 	 	 	$	24	 	

(a) Primarily associated with two facility closures and accelerated vesting for certain participants.
(b) Primarily associated with two UK plans merging into the GE UK Pension Plan.

ASSUMPTIONS USED IN PENSION CALCULATION

Accounting requirements necessitate the use of assumptions to reflect the uncertainties and the length of time over which the pension obligations will be paid. The actual amount of future benefit payments will depend upon when participants retire, the amount of their benefit at retirement and how long they live. To reflect the obligation in today’s dollars, we discount the future payments using a rate that matches the time frame over which the payments will be made. We also need to assume a long-term rate of return that will be earned on investments used to fund these payments.

The assumptions at December 31 used to measure the year-end benefit obligations and pension cost follow.

Assumptions used to measure pension benefit obligations:

December 31	 	2016	 	 	2015	 	 	2014	 	
Discount rate	 	 	3.41	%	 	 	3.83	%	 	 	3.69	%	
Compensation increases	 	 	4.09	 	 	 	4.36	 	 	 	4.36	 	

Assumptions used to measure pension cost

December 31	 	2016	 	 	2015	 	 	2014	 	
Discount rate	 	 	3.83	%	 	 	3.69	%	 	 	4.51	%	
Expected return on assets	 	 	6.86	 	 	 	6.91	 	 	 	6.66	 	

We evaluate these assumptions annually. We evaluate other assumptions periodically, such as retirement age, mortality and turnover, and update them as necessary to reflect our actual experience and expectations for the future.

We determine the discount rate using the weighted average yields on high-quality fixed-income securities that have maturities consistent with the timing of benefit payments. Lower discount rates increase the size of the benefit obligations and pension expense in the following year; higher discount rates reduce the size of the benefit obligation and subsequent-year pension expense.

The expected return on plan assets is the estimated long-term rate of return that will be earned on the investments used to fund the pension obligations. To determine this rate, we consider the current and target composition of plan investments, our historical returns earned, and our expectations about the future.

29    GE O&G Annual FS

 

The compensation assumption is used to estimate the annual rate at which pay of plan participants will grow. If the rate of growth assumed increases, the size of the pension obligations will increase, as will the amount recorded in equity attributable to parent and amortized to income in subsequent periods.
We amortize experience gains and losses, as well as the effects of changes in actuarial assumptions and plan provisions, over a period no longer than the average future service of employees.

FUNDING POLICY

The funding policy for our pension plans is to contribute amounts sufficient to meet minimum funding requirements as set forth in employee benefit and tax laws plus such additional amounts as we may determine to be appropriate. We expect to contribute approximately $41 million to our pension plans in 2017. In 2016, we contributed $50 million.

BENEFIT OBLIGATIONS

Benefit obligations are described in the following tables. Accumulated and projected benefit obligations (ABO and PBO) represent the obligations of a pension plan for past service as of the measurement date. ABO is the present value of benefits earned to date with benefits computed based on current compensation levels. PBO is ABO increased to reflect expected future compensation.

PROJECTED BENEFIT OBLIGATIONS (PBO)

(In millions)	 	2016	 	 	 	2015	 	
Balance at January 1	 	$	1,290	 	 	 	$	1,400	 	
Service cost for benefits earned	 	 	18	 	 	 	 	24	 	
Interest cost on benefit obligations	 	 	34	 	 	 	 	49	 	
Actuarial loss (gain) (a)	 	 	39	 	 	 	 	(66	)	
Benefits paid	 	 	(39	)	 	 	 	(48	)	
Disposition	 	 	-	 	 	 	 	(31	)	
Merger into GE plan	 	 	(460	)	(b)	 	 	-	 	
Exchange rate adjustments	 	 	(62	)	 	 	 	(38	)	
Balance at December 31	 	$	820	 	 	 	$	1,290	 	

(a) Primarily associated with discount rate changes.
(b) Two UK pension plans merged into the GE UK Pension Plan.

(In millions)	 	2016	 	 	2015	 	
Accumulated benefit obligations	 	$	803	 	 	$	1,238	 	

PLANS WITH ASSETS LESS THAN ABO

(In millions)	 	2016	 	 	2015	 	
Funded plans with assets less than ABO	 	 	 	 	 	 	
    Plan assets	 	$	567	 	 	$	915	 	
    Accumulated benefit obligations	 	 	685	 	 	 	1,126	 	
    Projected benefit obligations	 	 	697	 	 	 	1,173	 	
Unfunded plans	 	 	 	 	 	 	 	 	
    Accumulated benefit obligations	 	 	118	 	 	 	112	 	
    Projected benefit obligations	 	 	123	 	 	 	117	 	

 

30    GE O&G Annual FS

PLAN ASSETS

The fair value of the pension plans’ investments is presented below. The inputs and valuation techniques used to measure the fair value of the assets are consistently applied and described in Note 2 .

2016 ASSET ALLOCATION
 	 	Weighted Average
Target allocation %	 	 	Weighted Average
Actual allocation %	 	
Equity securities	 	 	18-58	 	 	 	48	 	
Debt securities (including cash equivalents)	 	 	11-61	 	 	 	35	 	
Private equities	 	 	6-16	 	 	 	8	 	
Real estate	 	 	3-13	 	 	 	6	 	
Other investments	 	 	3-13	 	 	 	3	 	

Plan fiduciaries of our pension plans set investment policies and strategies for the assets held in trust and oversee investment allocation, which includes selecting investment managers, commissioning periodic asset-liability studies and setting long-term strategic targets. Long-term strategic investment objectives take into consideration a number of factors, including the funded status of the plan, a balance between risk and return and the plan’s liquidity needs. Target allocation percentages are established at an asset class level by plan fiduciaries. Target allocation ranges are guidelines, not limitations, and occasionally plan fiduciaries will approve allocations above or below a target range.

COMPOSITION OF OUR PLAN ASSETS

The fair value of our pension plans’ investments is presented below:

(In millions)	 	2016	 	 	2015	 	
Equity securities	 	 	 	 	 	 	
    U.S. equity securities (a)	 	$	122	 	 	$	115	 	
    Non-U.S. equity securities (a)	 	 	149	 	 	 	359	 	
Debt securities	 	 	 	 	 	 	 	 	
    Fixed income and cash investment funds	 	 	49	 	 	 	200	 	
    U.S. corporate	 	 	53	 	 	 	51	 	
    Other debt securities	 	 	99	 	 	 	94	 	
Private equities	 	 	45	 	 	 	45	 	
Real estate	 	 	32	 	 	 	29	 	
Other investments (b)	 	 	18	 	 	 	22	 	
Total plan assets	 	$	567	 	 	$	915	 	

(a) Included direct investments and investment funds.
(b) Substantially all represented hedge fund investments.

Plan assets valued using NAV as a practical expedient amounted to $228 million and $258 million as of December 31, 2016 and 2015, respectively. The percentages of plan assets valued using NAV by investment fund type for equity securities, fixed income and cash, and alternative investments were 20%, 7% and 13% as of December 31, 2016, respectively, and 17%, 4% and 8% as of December 31, 2015, respectively.

31    GE O&G Annual FS

 

Those investments that were measured at fair values using the practical expedient were excluded from the fair value hierarchy. The practical expedient was not applied for investments with a fair value of $25 million and $23 million in 2016 and 2015, respectively and those investments were classified within Level 3. The remaining investments were substantially all considered Level 1 and 2.

FAIR VALUE OF PLAN ASSETS

(In millions)	 	2016	 	 	2015	 	
Balance at January 1	 	$	915	 	 	$	973	 	
Actual gain on plan assets	 	 	43	 	 	 	1	 	
Employer contributions	 	 	50	 	 	 	33	 	
Benefits paid	 	 	(39	)	 	 	(48	)	
Dispositions	 	 	-	 	 	 	(28	)	
Merger into GE plan (a)	 	 	(358	)	 	 	-	 	
Exchange rate adjustments	 	 	(44	)	 	 	(16	)	
Balance at December 31	 	$	567	 	 	$	915	 	

(a) Two UK pension plans were merged into the GE UK Pension Plan.

PENSION ASSET (LIABILITY)

(In millions)	 	2016	 	 	2015	 	
Funded status (a)	 	$	(253	)	 	$	(375	)	
Pension liability recorded in the Statement of Financial Position	 	 	 	 	 	 	 	 	
    Pension liabilities	 	 	 	 	 	 	 	 	
        Due within one year	 	 	(4	)	 	 	(4	)	
        Due after one year	 	 	(249	)	 	 	(371	)	
Net amount recognized	 	$	(253	)	 	$	(375	)	
Amounts recorded in equity attributable to parent (unamortized)	 	 	 	 	 	 	 	 	
    Prior service cost	 	 	-	 	 	 	-	 	
    Net actuarial loss	 	 	149	 	 	 	211	 	
Total	 	$	149	 	 	$	211	 	

(a) Fair value of assets less PBO, as shown in the preceding tables.

In 2017, we estimate that we will amortize an immaterial amount of prior service cost and $12 million of net actuarial loss from equity attributable to parent and into pension cost. Comparable amortized amounts in 2016 were an immaterial amount of prior service cost and $14 million of net actuarial loss from equity attributable to parent.

(In millions)	 	2017	 	 	2018	 	 	2019	 	 	2020	 	 	2021	 	 	 	2022 - 2026	 	
Estimated future benefit payments	 	$	38	 	 	$	38	 	 	$	39	 	 	$	40	 	 	$	41	 	 	$	212	 	

 

32    GE O&G Annual FS

 
RETIREE HEALTH AND LIFE INSURANCE BENEFITS

We sponsor a retiree health and life insurance benefit plan (retiree benefit plan) for certain eligible U.S. participants and use a December 31 measurement date. The plan is closed to new entrants and participants share in the cost of this retiree benefit plan. This plan covers approximately 270 active employees and 1,395 retirees and dependents. GE Power also participates in this retiree benefit plan. We allocated costs (credits) of $2 million, an immaterial amount and $5 million to GE Power for their employees’ participation in these plans, for the years ended December 31, 2016, 2015 and 2014, respectively.

COST OF RETIREE BENEFIT PLAN

(In millions)	 	2016	 	 	 	2015	 	 	 	2014	 	
Service cost for benefits earned	 	$	2	 	 	 	$	3	 	 	 	$	2	 	
Prior service credit amortization	 	 	(2	)	 	 	 	(1	)	 	 	 	(1	)	
Interest cost on benefit obligations	 	 	5	 	 	 	 	6	 	 	 	 	7	 	
Net actuarial loss amortization	 	 	-	 	 	 	 	1	 	 	 	 	1	 	
Curtailment / settlement gain	 	 	(2	)	(a)	 	 	(11	)	(b)	 	 	-	 	
Benefit plans cost	 	$	3	 	 	 	$	(2	)	 	 	$	9	 	

(a)	Primarily related to the closure of a facility.	

(b)	Primarily associated with restructuring and a facility disposition.	

ASSUMPTIONS USED IN BENEFIT CALCULATIONS

The actuarial assumptions at December 31 used to measure the year-end benefit obligations and retiree benefit plan cost for the subsequent year are as follows:

ASSUMPTIONS USED TO MEASURE RETIREE BENEFIT OBLIGATIONS

 	 	2016	 	 	2015	 	 	2014	 	
Discount rate	 	 	4.00	%	 	 	4.25	%	 	 	4.00	%	
Initial healthcare trend rate	 	 	6.75	 	 	 	7.00	 	 	 	7.00	 	

ASSUMPTIONS USED TO MEASURE RETIREE BENEFIT COSTS

 	 	2016	 	 	2015	 	 	2014	 	
Discount rate	 	 	4.25	%	 	 	4.00	%	 	 	4.75	%	

We amortize experience gains and losses, as well as the effects of changes in actuarial assumptions and plan provisions, over a period no longer than the average future service of employees.

FUNDING POLICY

We fund our retiree benefit plan on a pay-as-you-go basis. We expect to contribute approximately $6 million in 2017 to fund such benefits. In 2016, we contributed $6 million for this plan.

 

33    GE O&G Annual FS

Changes in the accumulated postretirement benefit obligation (APBO) for the retiree benefit plan follow:

(In millions)	 	2016	 	 	 	2015	 	 	
Balance at January 1	 	$	136	 	 	 	$	152	 	 	
Service cost for benefits earned	 	 	2	 	 	 	 	3	 	 	
Interest cost on benefit obligations	 	 	5	 	 	 	 	6	 	 	
Participant contributions	 	 	-	 	 	 	 	1	 	 	
Plan amendment	 	 	(5	)	 	 	 	-	 	 	
Actuarial gain	 	 	(14	)	 	 	 	(12	)	 	
Benefits paid	 	 	(6	)	 	 	 	(5	)	 	
Curtailment / settlement gain	 	 	(1	)	(a)	 	 	(9	)	(b)	
Balance at December 31	 	$	117	 	 	 	$	136	 	 	

(a)  Primarily related to the closure of a facility.
(b) Primarily associated with restructuring and a facility disposition.

A one percentage point change in the assumed healthcare cost trend rate would have the following effects:

(In millions)	 	1% increase	 	 	1% decrease	 	
APBO at December 31, 2016	 	$	15	 	 	$	(13	)	
Service and interest cost in 2016	 	 	1	 	 	 	(1	)	

PLAN ASSETS

The fair value of our retiree benefit plan assets is presented below.

FAIR VALUE OF PLAN ASSETS

(In millions)	 	2016	 	 	2015	 	
Balance at January 1	 	$	-	 	 	$	-	 	
Employer contributions	 	 	6	 	 	 	4	 	
Participant contributions	 	 	-	 	 	 	1	 	
Benefits paid	 	 	(6	)	 	 	(5	)	
Balance at December 31	 	$	-	 	 	$	-	 	

34    GE O&G Annual FS

 
RETIREE BENEFIT PLAN ASSET (LIABILITY)

(In millions)	 	2016	 	 	2015	 	
Funded status (a)	 	$	(117	)	 	$	(136	)	
Liability recorded in the Statement of Financial Position	 	 	 	 	 	 	 	 	
    Retiree benefit plan	 	 	 	 	 	 	 	 	
        Due within one year	 	 	(6	)	 	 	(6	)	
        Due after one year	 	 	(111	)	 	 	(130	)	
Net amount recognized	 	 	(117	)	 	 	(136	)	
Amounts recorded in equity attributable to parent (unamortized)	 	 	 	 	 	 	 	 	
    Prior service credit	 	 	(8	)	 	 	(6	)	
    Net actuarial gain	 	 	(15	)	 	 	(1	)	
Total	 	$	(23	)	 	$	(7	)	

(a) Fair value of assets less APBO, as shown in the preceding tables.

In 2017, we estimate that we will amortize $2 million of prior service credit and $2 million of net actuarial gain from equity attributable to parent into our retiree benefit plan cost. Comparable amortized amounts in 2016 were $2 million of prior service credit and an immaterial amount of net actuarial loss.

(In millions)	 	2017	 	 	2018	 	 	2019	 	 	2020	 	 	2021	 	 	 	2022 - 2026	 	
Estimated future benefit payments	 	$	6	 	 	$	6	 	 	$	6	 	 	$	6	 	 	$	7	 	 	$	33	 	

2016 COST OF POSTRETIREMENT BENEFIT PLANS AND CHANGES IN OTHER COMPREHENSIVE INCOME (LOSS)

(In millions)	 	Total postretirement
benefit plans	 	 	Pension
plans	 	 	Retiree benefit
plan	 	
Cost (income) of postretirement benefit plans	 	$	(3	)	 	$	(6	)	 	$	3	 	
Changes in other comprehensive income (loss)	 	 	 	 	 	 	 	 	 	 	 	 	
     Prior service (credit) – current year	 	 	(5	)	 	 	-	 	 	 	(5	)	
     Net actuarial loss (gain) – current year	 	 	14	 	 	 	28	 	 	 	(14	)	
     Net settlement / curtailment gain (loss)	 	 	(75	)	 	 	(76	)	 	 	1	 	
     Prior service credit amortization	 	 	2	 	 	 	-	 	 	 	2	 	
     Net actuarial (loss) amortization	 	 	(14	)	 	 	(14	)	 	 	-	 	
Total changes in other comprehensive (loss)	 	 	(78	)	 	 	(62	)	 	 	(16	)	
Cost of postretirement benefit plans and changes in other comprehensive (loss)	 	$	(81	)	 	$	(68	)	 	$	(13	)	

35    GE O&G Annual FS

 
NOTE 13	ALL OTHER LIABILITIES	

This caption includes liabilities for various items including deferred income, interest on tax liabilities, unrecognized tax benefits, environmental remediation, legal reserves, asset retirement obligations, derivative instruments, product warranties and a variety of sundry items.
 
December 31 (In millions)	 	2016	 	 	2015	 	
Other current liabilities	 	 	 	 	 	 	
Income taxes payable	 	$	-	 	 	$	305	 	
Derivatives	 	 	330	 	 	 	256	 	
Payroll accruals	 	 	294	 	 	 	455	 	
Other current liabilities	 	 	567	 	 	 	615	 	
Total other current liabilities	 	$	1,191	 	 	$	1,631	 	
Other non-current liabilities	 	 	 	 	 	 	 	 	
Income taxes payable	 	 	139	 	 	 	152	 	
Environmental liabilities	 	 	39	 	 	 	34	 	
Other non-current liabilities	 	 	317	 	 	 	337	 	
Total other non-current liabilities	 	$	495	 	 	$	523	 	

ENVIRONMENTAL MATTERS

We are involved in numerous remediation actions to clean up hazardous wastes as required by federal and state laws. Liabilities for remediation costs exclude possible insurance recoveries and, when dates and amounts of such costs are not known, are not discounted. When there appears to be a range of possible costs with equal likelihood, liabilities are based on the low end of such range. It is reasonably possible that our environmental remediation exposure will exceed amounts accrued. However, due to uncertainties about the status of laws, regulations, technology and information related to individual sites, such amounts are not reasonably estimable.  The determination of the required accruals for remediation costs is subject to uncertainty, including the evolving nature of environmental regulations and the difficulty in estimating the extent and type of remediation activity that is necessary.

 
 
36    GE O&G Annual FS

 

NOTE 14	INCOME TAXES	
The tax provisions have been prepared on a separate return basis as if the Business is a separate group of companies under common ownership.  The operations have been combined as if the Business was filing on a consolidated basis for U.S., state and Non-U.S. income tax purposes, where allowable by law. The Business is subject to regulation under a wide variety of U.S. federal, state and foreign tax laws, regulations and policies. Changes to these laws or regulations may affect our tax liability, return on investments and business operations.

COMBINED INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES

(In millions)	 	2016	 	 	2015	 	 	2014	 	
U.S.  (losses)	 	$	(440	)	 	$	(2,006	)	 	$	1,030	 	
Non-U.S. income	 	 	1,024	 	 	 	1,848	 	 	 	1,306	 	
Total income (loss)	 	$	584	 	 	$	(158	)	 	$	2,336	 	

COMBINED (BENEFIT) PROVISION FOR INCOME TAXES

(In millions)	 	2016	 	 	2015	 	 	2014	 	
Current	 	 	 	 	 	 	 	 	 	
U.S. Federal	 	$	(112	)	 	$	155	 	 	$	318	 	
U.S. State and Local	 	 	(2	)	 	 	3	 	 	 	31	 	
Non-U.S.	 	 	310	 	 	 	395	 	 	 	375	 	
Deferred	 	 	 	 	 	 	 	 	 	 	 	 	
U.S. Federal	 	 	13	 	 	 	(26	)	 	 	(113	)	
U.S. State and Local	 	 	-	 	 	 	5	 	 	 	(17	)	
Non-U.S.	 	 	41	 	 	 	(59	)	 	 	(110	)	
Total	 	$	250	 	 	$	473	 	 	$	484	 	

 
 
37    GE O&G Annual FS

 
RECONCILIATION OF U.S. FEDERAL STATUTORY INCOME TAX RATE TO ACTUAL INCOME TAX RATE

 (In millions)	 	2016	 	 	2015	 	 	2014	 	
Income (loss) before taxes	 	$	584	 	 	$	(158	)	 	$	2,336	 	
Tax expected at 35% (a)	 	 	205	 	 	 	(55	)	 	 	818	 	
Foreign operations and FTCs (b)	 	 	(5	)	 	 	(137	)	 	 	(311	)	
State taxes	 	 	(2	)	 	 	8	 	 	 	14	 	
Tax Impact of Dispositions	 	 	1	 	 	 	(26	)	 	 	(61	)	
Nondeductible goodwill	 	 	-	 	 	 	713	 	 	 	-	 	
Valuation allowance	 	 	28	 	 	 	9	 	 	 	-	 	
Other	 	 	23	 	 	 	(39	)	 	 	24	 	
Total income tax	 	$	250	 	 	$	473	 	 	$	484	 	
Actual Income tax rate	 	 	42.8	%	 	 	-299.4	%	 	 	20.7	%	

(a) Although our operational headquarters are in London, the Business has an ultimate U.S. parent; therefore, we reconcile our effective tax rate to the U.S. federal statutory rate of 35%.
(b) Primarily relates to differences between the U.S. statutory rate and the statuary rates where the Business operates, including the impact of foreign tax credits. The tax expense in 2016, 2015 and 2014 includes a net benefit of $36 million, $36 million, and $42 million, respectively, related to tax amortization in our European operations.

UNRECOGNIZED TAX POSITIONS

The Business is under continuous examination by the Internal Revenue Service, various U.S. state taxing authorities, and Non-U.S. taxing authorities as part of the audit of GE’s tax returns. The Business is under examination or engaged in tax litigation in many of these jurisdictions. During 2015, the Internal Revenue Service (IRS) completed the audit of GE’s consolidated U.S. income tax returns for 2010-2011, except for certain issues that remain under examination. During 2013, the IRS completed the audit of GE’s consolidated U.S. income tax returns for 2008-2009, except for certain issues that remain under examination. For our most significant Italian operations our earliest open tax year is 2012. We believe that there are no jurisdictions in which the outcome of unresolved issues or claims is likely to be material to our results of operations, financial position or cash flows.  We further believe that we have made adequate provisions for all income tax uncertainties.

The balance of unrecognized tax benefits, the amount of related interest and penalties we have provided and what we believe to be the range of reasonably possible changes in the next 12 months were as follows:
UNRECOGNIZED TAX BENEFITS

Asset / (Liability) (In millions)	 	2016	 	 	2015	 	
Unrecognized tax benefits	 	$	(94	)	 	$	(100	)	
Accrued interest on unrecognized tax benefits	 	 	(33	)	 	 	(27	)	
Accrued penalties on unrecognized tax benefits	 	 	(22	)	 	 	(31	)	
Reasonably possible reduction to the balance of unrecognized tax benefits	 	 	 	 	 	 	 	 	
in succeeding 12 months	 	 	(9	)	 	 	(4	)	
Portion that, if recognized, would reduce tax expense and effective tax rate	 	 	(94	)	 	 	(100	)	

38    GE O&G Annual FS

 
UNRECOGNIZED TAX BENEFITS RECONCILIATION
(In millions)	 	2016	 	 	2015	 	
Balance at January 1	 	$	(100	)	 	$	(122	)	
Additions for tax positions of the current year	 	 	(4	)	 	 	(16	)	
Additions for tax positions of prior years	 	 	-	 	 	 	-	 	
Reductions for tax positions of prior years	 	 	5	 	 	 	13	 	
Settlements with tax authorities	 	 	-	 	 	 	-	 	
Expiration of the statute of limitations	 	 	5	 	 	 	25	 	
Balance at December 31	 	$	(94	)	 	$	(100	)	

At December 31, 2016, we had $94 million of unrecognized tax benefits. In addition, we have accrued interest and penalties of $33 million and $22 million, respectively. The amount of unrecognized tax benefits which would impact the effective tax rate would be $94 million. Additionally, $9 million is the amount of unrecognized tax benefits which could change in the next twelve months due to expiring statutes, audit activity, tax payments, and competent authority proceedings related to transfer pricing or final decisions in matters that are the subject of litigation in various taxing jurisdictions in which we operate. We classify interest on tax deficiencies as interest expense; we classify income tax penalties as a provision for income taxes.

DEFERRED INCOME TAXES

Deferred income tax balances reflect the effects of temporary differences between the carrying amounts of assets and liabilities and their tax bases, as well as from net operating loss and tax credit carryforwards, and are stated at enacted tax rates expected to be in effect when taxes are actually paid or recovered. Deferred income tax assets represent amounts available to reduce income taxes payable on taxable income in future years. GE Oil & Gas did not operate as a standalone entity in the past and, accordingly, tax losses, receivables and other tax attributes included in the combined carve-out financial statements on a separate return basis may not be available upon separation of the Business from GE.

We regularly evaluate the recoverability of our deferred tax assets and establish a valuation allowance, if necessary, to reduce the deferred tax assets to an amount that is more likely than not to be realized (a likelihood of more than 50 percent). Significant judgment is required to determine whether a valuation allowance is necessary and the amount of such valuation allowance.
In assessing the recoverability of our deferred tax assets at December 31, 2016, we considered all available evidence, including the nature of financial statement losses as adjusted for permanent differences between financial statement income and taxable income, reversing taxable temporary differences and future operating profits.

Aggregated deferred income tax amounts are summarized below.

DEFERRED INCOME TAX AMOUNTS

(In millions)	 	2016	 	 	2015	 	
Assets	 	$	326	 	 	$	334	 	
Liabilities	 	 	(880	)	 	 	(854	)	
Net deferred income tax (liability)	 	$	(554	)	 	$	(520	)	

39    GE O&G Annual FS

 
COMPONENTS OF THE NET DEFERRED INCOME TAX ASSET (LIABILITY)
(In millions)	 	2016	 	 	2015	 	
Deferred tax assets	 	 	 	 	 	 	
Inventory	 	$	71	 	 	$	(78	)	
Employee benefits	 	 	154	 	 	 	203	 	
Other accrued expenses	 	 	121	 	 	 	130	 	
Operating loss carryforwards	 	 	142	 	 	 	142	 	
Tax credit carryforwards	 	 	5	 	 	 	-	 	
Other	 	 	-	 	 	 	10	 	
Total deferred income tax asset	 	 	493	 	 	 	407	 	
Valuation allowances	 	 	(87	)	 	 	(53	)	
Total deferred income tax asset after valuation allowance	 	 	406	 	 	 	354	 	
 	 	 	 	 	 	 	 	 	
Deferred tax liabilities	 	 	 	 	 	 	 	 	
Goodwill & other intangibles	 	$	(845	)	 	$	(813	)	
Property, plant and equipment	 	 	(62	)	 	 	(5	)	
Undistributed income of foreign subsidiaries	 	 	(46	)	 	 	(56	)	
Other	 	 	(9	)	 	 	-	 	
Total deferred income tax liability	 	 	(962	)	 	 	(874	)	
Net deferred income tax (liability)	 	$	(554	)	 	$	(520	)	

NET OPERATING LOSSES

At December 31, 2016 and 2015, the Business had net operating loss carryforwards of approximately $460 million and $458 million, respectively. The net operating loss carryforwards result in a deferred tax asset of $142 million and $142 million at December 31, 2016 and 2015. The net operating losses expire beginning in 2019, with some not having any expiration date. Out of the $142 million of net operating losses in 2016, $22 million will expire in 2019 and $89 million have no expiration. The losses expiring in 2019 have been fully valued.  We believe that we will not be able to utilize these losses before their expiration.

CREDIT CARRYFORWARD

At December 31, 2016, the Business had approximately $5 million of foreign tax credits that are available for carryforward. The carryforward period for foreign tax credits is 10 years. A valuation allowance had not been established due to future foreign source income that would allow the Business to utilize the credit.

40    GE O&G Annual FS

 
 
UNDISTRIBUTED EARNINGS

We have not provided U.S. deferred taxes on cumulative earnings of non-U.S. affiliates and associated companies that have been reinvested indefinitely.  The basis difference is primarily comprised of the unremitted retained earnings related to these ongoing operations, which were approximately $11,936 million and $11,204 million, at December 31, 2016 and 2015, respectively. Substantially all of these earnings have been reinvested in active non-U.S. business operations and we do not intend to repatriate these earnings to fund U.S. operations. These earnings would be subject to tax upon repatriation to the U.S.; however, because of the availability of U.S. foreign tax credits, it is not practicable to determine the U.S. federal income tax liability that would be payable if such earnings were not reinvested indefinitely.
NOTE 15	EQUITY	

(In millions)	 	2016	 	 	2015	 	 	2014	 	
 	 	 	 	 	 	 	 	 	 	
Accumulated other comprehensive income (loss)	 	 	 	 	 	 	 	 	 	
Balance at January 1	 	$	(1,532	)	 	$	(964	)	 	$	(749	)	
Other comprehensive (loss) before reclassifications	 	 	(459	)	 	 	(594	)	 	 	(255	)	
Reclassifications from other comprehensive income (loss)	 	 	97	 	 	 	26	 	 	 	40	 	
Other comprehensive (loss), net, attributable to parent	 	 	(362	)	 	 	(568	)	 	 	(215	)	
Balance at December 31	 	$	(1,894	)	 	$	(1,532	)	 	$	(964	)	
Net parent investment	 	 	 	 	 	 	 	 	 	 	 	 	
Balance at January 1	 	$	15,920	 	 	$	17,169	 	 	$	15,438	 	
Net income / (loss) attributable to parent	 	 	403	 	 	 	(606	)	 	 	1,840	 	
Net transfers (to) / from parent	 	 	259	 	 	 	(643	)	 	 	(109	)	
Balance at December 31	 	$	16,582	 	 	$	15,920	 	 	$	17,169	 	
Total equity	 	 	 	 	 	 	 	 	 	 	 	 	
Total equity attributable to parent at December 31	 	$	14,688	 	 	$	14,388	 	 	$	16,205	 	
Noncontrolling interests balance at December 31	 	 	167	 	 	 	157	 	 	 	181	 	
Total equity balance at December 31	 	$	14,855	 	 	$	14,545	 	 	$	16,386	 	

 
41    GE O&G Annual FS

 
ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) “AOCI”

The breakdown of accumulated other comprehensive income (loss) is provided below:
(In millions)	 	2016	 	 	2015	 	 	2014	 	
Currency translation adjustments (CTA)	 	 	 	 	 	 	 	 	 	
Balance at January 1	 	$	(1,384	)	 	$	(775	)	 	$	(655	)	
Other comprehensive (loss) before reclassifications -
  net of deferred taxes of $ 11, $ 13, and $ (14)	 	 	(423	)	 	 	(617	)	 	 	(163	)	
Reclassifications from OCI -
  net of deferred taxes of $ 0, $ 0, and $ 0	 	 	1	 	 	 	-	 	 	 	34	 	
Other comprehensive (loss) (a)	 	 	(422	)	 	 	(617	)	 	 	(129	)	
Less OCI attributable to noncontrolling interests	 	 	(5	)	 	 	(8	)	 	 	(9	)	
Balance at December 31	 	$	(1,801	)	 	$	(1,384	)	 	$	(775	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Cash flow hedges	 	 	 	 	 	 	 	 	 	 	 	 	
Balance at January 1	 	$	(2	)	 	$	-	 	 	$	-	 	
Other comprehensive (loss) before reclassifications net of deferred
taxes of $ 8, $ 3, and $ 0	 	 	(38	)	 	 	(9	)	 	 	-	 	
Reclassifications from OCI net of deferred taxes of $ (7), $ (2), and $ 0	 	 	30	 	 	 	7	 	 	 	-	 	
Other comprehensive (loss) (a)	 	 	(8	)	 	 	(2	)	 	 	-	 	
Less OCI attributable to noncontrolling interests	 	 	-	 	 	 	-	 	 	 	-	 	
Balance at December 31	 	$	(10	)	 	$	(2	)	 	$	-	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Benefit plans	 	 	 	 	 	 	 	 	 	 	 	 	
Balance at January 1	 	$	(146	)	 	$	(189	)	 	$	(94	)	
Other comprehensive income (loss) before reclassifications net of
deferred taxes of $ (1), $ (16), and $ 47	 	 	(12	)	 	 	21	 	 	 	(100	)	
Reclassifications from OCI net of deferred taxes of $ (22), $ (5), and $ (3)	 	 	66	 	 	 	19	 	 	 	6	 	
Other comprehensive income (loss) (a)	 	 	54	 	 	 	40	 	 	 	(94	)	
Less OCI attributable to noncontrolling interests	 	 	(9	)	 	 	(3	)	 	 	1	 	
Balance at December 31	 	$	(83	)	 	$	(146	)	 	$	(189	)	
Accumulated other comprehensive (loss) at December 31	 	$	(1,894	)	 	$	(1,532	)	 	$	(964	)	

(a) Total Other comprehensive (loss) attributable to parent was ($376) million, ($579) million and ($223) million in 2016, 2015 and 2014, respectively.

42    GE O&G Annual FS

 

RECLASSIFICATION OUT OF AOCI
(In millions)	 	2016	 	 	2015	 	 	2014	 	Combined Statement of Income (Loss) caption	
Currency translation adjustments	 	 	 	 	  	
Gains on dispositions	 	$	1	 	 	$	-	 	 	$	34	 	Total revenues and other income	
Income taxes	 	 	-	 	 	 	-	 	 	 	-	 	Benefit (provision) for income taxes	
Net of tax	 	$	1	 	 	$	-	 	 	$	34	 	 	
Cash flow hedges	 	 	 	 	 	 	 	 	 	 	 	 	       	
Foreign exchange contracts	 	$	37	 	 	$	9	 	 	$	-	 	(a)	
Income taxes	 	 	(7	)	 	 	(2	)	 	 	-	 	(Provision) for income taxes	
Net of tax	 	$	30	 	 	$	7	 	 	$	-	 	 	
Benefit plan items	 	 	 	 	 	 	 	 	 	 	 	 	       	
Net settlement / curtailment loss	 	$	75	 	 	$	2	 	 	$	-	 	(b)	
Amortization of prior service credits	 	 	(2	)	 	 	(1	)	 	 	(1	)	(b)	
Amortization of actuarial loss	 	 	15	 	 	 	23	 	 	 	10	 	(b)	
Total before tax	 	 	88	 	 	 	24	 	 	 	9	 	 	
Income taxes	 	 	(22	)	 	 	(5	)	 	 	(3	)	(Provision) for income taxes	
Net of tax	 	$	66	 	 	$	19	 	 	$	6	 	 	
Total reclassification adjustments (net of tax)	 	$	97	 	 	$	26	 	 	$	40	 	 	

(a) Please see Note 18 for respective Combined Statement of Income (Loss) captions.
(b) Curtailment gain (loss), amortization of prior service costs and actuarial gains and losses reclassified out of AOCI are included in the computation of net periodic pension costs. Refer to Note 12 for further information.  Net periodic pension cost is recorded across the various cost and expense line items within the Combined Statement of Income (Loss).

 
43    GE O&G Annual FS

 

NOTE 16	EQUITY-ACCOUNTED INVESTMENTS	

Our equity in income of GE O&G uncombined associated companies was $5 million, $9 million and $19 million for the years ended December 31, 2016, 2015 and 2014, respectively.  Our investments in associated companies was $88 million and $95 million as of December 31, 2016, and 2015, respectively.

 

 

44    GE O&G Annual FS

 

NOTE 17	FAIR VALUE MEASUREMENTS	

RECURRING FAIR VALUE MEASUREMENTS
Our assets and liabilities measured at FV on a recurring basis consists of our derivative instruments.  All of these derivatives were valued using Level 2 for 2016 and 2015.
There were no transfers between Level 1, 2 and 3 during the years ended December 31, 2016 and 2015.

 

 
 
45    GE O&G Annual FS

 

NOTE 18	DERIVATIVES	
In this section, we explain how we use derivatives to manage our risks and how these financial instruments are reflected in our combined financial statements. Our use of derivatives relates solely to risk management; we do not use derivatives for speculation.

The table below summarizes the fair value of all derivatives, including hedging instruments and embedded derivatives.

 	 	2016	 	 	2015	 	
December 31 (In millions)	 	Assets	 	 	(Liabilities)	 	 	Assets	 	 	(Liabilities)	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Derivatives accounted for as hedges	 	 	 	 	 	 	 	 	 	 	 	 	
Currency exchange contracts	 	$	2	 	 	$	(9	)	 	$	1	 	 	$	(7	)	
 	 	$	2	 	 	$	(9	)	 	$	1	 	 	$	(7	)	
Derivatives not accounted for as hedges	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Currency exchange contracts	 	$	225	 	 	$	(364	)	 	$	247	 	 	$	(282	)	
Embedded derivatives	 	 	91	 	 	 	(2	)	 	 	91	 	 	 	(9	)	
 	 	$	316	 	 	$	(366	)	 	$	338	 	 	$	(291	)	
 Total	 	$	318	 	 	$	(375	)	 	$	339	 	 	$	(298	)	

Derivatives are classified in the captions “Other current assets,” “All other assets,” Other current liabilities,” and “All other liabilities” depending on their respective maturity date.

RISK MANAGEMENT STRATEGY

We buy, manufacture and sell components and products across global markets. These activities expose us to changes in foreign currency exchange rates and commodity prices, which can adversely affect revenues earned and costs of operating our business. When the currency in which we sell equipment differs from the primary currency (known as its functional currency) and the exchange rate fluctuates, it will affect the revenue we earn on the sale. These sales and purchase transactions also create receivables and payables denominated in foreign currencies, which expose us to foreign currency gains and losses based on changes in exchange rates. Changes in the price of a raw material that we use in manufacturing can affect the cost of manufacturing. We use derivatives to mitigate or eliminate these exposures.

FORMS OF HEDGING

In this section we explain the hedging methods we use and their effects on our combined financial statements.
CASH FLOW HEDGES

We use cash flow hedging primarily to reduce or eliminate the effects of foreign exchange rate changes on purchase and sale contracts. Accordingly, the vast majority of our derivative activity in this category consists of currency exchange contracts. We also use commodity derivatives to reduce or eliminate price risk on materials purchased for use in manufacturing.

 
46    GE O&G Annual FS

 

Under hedge accounting, the derivative carrying amount is measured at fair value each period and any resulting gain or loss is recorded in a separate component of equity. Differences between the derivative and the hedged item may cause changes in their fair values to not offset completely, which is referred to as ineffectiveness. When the hedged transaction occurs, these amounts are released from equity, in order that the transaction will be reflected in income at the rate locked in by the derivative. The effect of the hedge is reported in the same combined financial statement line item as the income effects of the hedged transaction. The table below summarizes how the derivative is reflected in the Combined Statement of Financial Position and in income under hedge accounting. The effect of the hedged forecasted transaction is not presented in this table but offsets the income effect of the derivative.

Financial Statement Effects – Cash Flow Hedges
(In millions)	 	2016	 	 	2015	 	 	2014	 	
 	 	 	 	 	 	 	 	 	 	
Combined Statement of Financial Position changes	 	 	 	 	 	 	 	 	 	
Fair value of derivatives (decrease)	 	$	(1	)	 	$	(5	)	 	$	(1	)	
Equity (increase) decrease	 	 	 	 	 	 	 	 	 	 	 	 	
-          Current year AOCI movement	 	 	47	 	 	 	11	 	 	 	-	 	
-          Reclassification from AOCI to the statement of income (loss) (a)	 	 	(37	)	 	 	(9	)	 	 	-	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Income (loss) related to ineffectiveness	 	 	-	 	 	 	-	 	 	 	-	 	

(a) Classified as “Other expenses / (income), net”, “Costs of goods sold” or “Selling, general and administrative expenses” depending on the purpose of the hedging instrument.
The following table explains the effect of changes in market rates on the fair value of derivatives we use most commonly in cash flow hedging arrangements.

Currency forwards/swaps	U.S. dollar strengthens	U.S. dollar weakens	
Pay U.S. dollars/receive foreign currency	Fair value decreases	Fair value increases	

We expect to transfer $12 million to income as an expense in the next 12 months contemporaneously with the income effects of the related forecasted transactions. At December 31, 2016 and 2015, the maximum term of derivative instruments that hedge forecasted transactions was 3 years and 4 years, respectively. See Note 15 for additional information about reclassification out of AOCI.

For cash flow hedges, the amount of ineffectiveness in the hedging relationship and amount of the changes in fair value of the derivatives that are not included in the measurement of ineffective were insignificant for each reporting period.
ECONOMIC HEDGES

These derivatives, which also include embedded derivatives, are not designated as hedges from an accounting standpoint (and therefore we do not apply hedge accounting to the relationship) but otherwise serve the same economic purpose as other hedging arrangements. Economic hedges are used when changes in the carrying amount of the hedged item are already recorded in income in the same period as the derivative, making hedge accounting unnecessary. They are also used when we have exposures to currency exchange risk for which we are unable to meet the requirements for hedge accounting. For these types of economic hedges, changes in the fair value of the derivative are recorded in income currently but changes in the value of the forecasted foreign currency cash flows are only recognized in income when they occur. As a result, even though the derivative is an effective economic hedge, there is a net effect on income in each period due to differences in the timing of income recognition between the derivative and the hedged item. Embedded derivatives are recognized separately from their host contracts.

47    GE O&G Annual FS

 
 
The table below provides information about the income effects of all derivatives that serve as economic hedges. These derivatives are marked to fair value through income each period. The effects are reported in “Selling, general and administration expenses” in the Combined Statement of Income (Loss). The offsetting income effects associated with hedged assets and liabilities are also displayed in the table below. In general, the income effects of the hedged item are recorded in the same combined financial statement line as the derivative.

Financial Statement Effects – Economic Hedges (a)
(In millions)	 	2016	 	 	2015	 	 	2014	 	
Combined Statement of Financial Position changes	 	 	 	 	 	 	 	 	 	
Change in fair value of economic hedge (decrease) (b)	 	$	(272	)	 	$	(118	)	 	$	(109	)	
Change in carrying amount of item being hedged increase	 	 	136	 	 	 	93	 	 	 	69	 	
Income (loss) effect of economic hedges (c)	 	$	(136	)	 	$	(25	)	 	$	40	 	

(a)	Include both the realized and unrealized movements, as well as those which cover future cash flows yet to be recognized on the Combined Statement of Financial Position.	

(b)	Include fair value changes in embedded derivatives.	

(c)	Offset by the future earnings effects of economically hedged item. Classified as “Other expense / (income), net”, “Costs of goods sold” or “Selling, general and administrative expenses” depending on the purpose of the hedging instrument.	

The table below explains the effects of market rate changes on the fair value of derivatives we use most commonly as economic hedges.
Currency forwards/swaps	 	U.S. dollar strengthens	 	U.S. dollar weakens	
Pay U.S. dollars/receive foreign currency	 	Fair value decreases	 	Fair value increases	
Receive U.S. dollars/pay foreign currency	 	Fair value increases	 	Fair value decreases	
Commodity derivatives	 	Price increases	 	Price decreases	
Receive commodity/ pay fixed price	 	Fair value increases	 	Fair value decreases	

NOTIONAL AMOUNT OF DERIVATIVES

The notional amount of a derivative is the number of units of the underlying (for example, the notional billing amount of the foreign currency sales in a foreign exchange hedge). We generally disclose derivative notional amounts on a gross basis. A substantial majority of the outstanding notional amount of $7,053 million and $8,915 million at December 31, 2016 and 2015, respectively, relates to hedges of anticipated sales and purchases in foreign currency, commodity purchases and contractual terms in contracts that are considered embedded derivatives. The remaining derivative notional primarily relates to hedges of anticipated sales and purchases in foreign currency, commodity purchases and contractual terms in contracts that are considered embedded derivatives.

The table below provides additional information about how derivatives are reflected in our combined financial statements.
Carrying Amounts Related to Derivatives

December 31 (In millions)	 	2016	 	 	2015	 	
Derivative assets	 	$	318	 	 	$	339	 	
Derivative liabilities	 	 	(375	)	 	 	(298	)	
Net carrying amount	 	$	(57	)	 	$	41	 	

48    GE O&G Annual FS

 
EFFECTS OF DERIVATIVES ON INCOME
All derivatives are marked to fair value on our Combined Statement of Financial Position, whether they are designated in a hedging relationship for accounting purposes or are used as economic hedges. As discussed in the previous sections, each type of hedge affects the combined financial statements differently. In economic hedges, both the hedged item and the hedging derivative largely offset in earnings each period. In cash flow hedges, the effective portion of the hedging derivative is offset in separate components of equity and ineffectiveness is recognized in income.

Note 15 provides additional information.

COUNTERPARTY CREDIT RISK

Fair value of our derivatives can change significantly from period to period based on, among other factors, market movements and changes in our positions. We manage counterparty credit risk (the risk that counterparties will default and not make payments to us according to the terms of our agreements) on an individual counterparty basis.

 

 

 

49    GE O&G Annual FS

 
NOTE 19	COMMITMENTS, CONTINGENCIES AND PRODUCT WARRANTIES	
LEASES

At December 31, 2016, we had long-term noncancellable operating leases covering certain facilities and equipment. The minimum annual property rental commitments, net of amounts due under subleases, for each of the five years in the period ending December 31, 2021 are $94 million, $86 million, $73 million, $61 million and $48 million, respectively, and $154 million in the aggregate thereafter. Rent expense, which includes rental of property, computer equipment and other such items, was $200 million, $206 million and $243 million for the years ended December 31, 2016, 2015 and 2014, respectively. We did not enter into any significant capital leases during the three years ended December 31, 2016.
LEGAL MATTERS

GE O&G is subject to a variety of legal proceedings and legal compliance risks in all parts of the world where the Business operates or buys or sells its equipment and services, including the matters described below. GE O&G has adopted appropriate risk management and compliance programs to address these and other matters that may arise from time to time. The global and diverse nature of GE O&G’s business, and the changing enforcement environments in which it operates, means the Business will continue to face legal and compliance risks, the nature and outcome of which cannot be predicted with certainty.  No material provisions have been accrued currently for litigation settlements as of December 31, 2016.
OTHER CONTRACTUAL COMMITMENTS

We also had commitments outstanding for purchase obligations, which include capital expenditures, inventory and services under contracts, for each of the five years in the period ending December 31, 2021 consisting of $479 million as of December 31, 2017, $10 million as of December 31, 2018 and no additional amounts for each subsequent period until December 31, 2021.

PRODUCT WARRANTIES

We provide for estimated product warranty expenses when we sell the related products. Because warranty estimates are forecasts that are based on the best available information, primarily historical claims experience, claims costs may differ from amounts provided. An analysis of changes in the liability for product warranties are as follows:

(In millions)	 	2016	 	 	2015	 	 	2014	 	
Balance at January 1	 	$	100	 	 	$	112	 	 	$	106	 	
Current-year provisions	 	 	29	 	 	 	60	 	 	 	37	 	
Expenditures	 	 	(49	)	 	 	(65	)	 	 	(28	)	
Other charges	 	 	(6	)	 	 	(7	)	 	 	(3	)	
Balance at December 31	 	$	74	 	 	$	100	 	 	$	112	 	

 

50    GE O&G Annual FS

 
NOTE 20	RELATED PARTIES	
RELATED PARTY TRANSACTIONS

As discussed in Note 2, GE provides us with a number of services. Some of these services are provided directly by GE, and others are managed by GE through third-party service providers. The cost of certain of these services is either (a) recognized through our allocated portion of GE’s corporate overhead; or (b) billed directly to us (such as most of our employee benefit costs). The cost of other services is included within the service itself, and the incremental cost for GE to provide the service is not discernible (such as payroll processing services included within the cost of payroll). In addition, we and our affiliates obtain a variety of goods (such as supplies and equipment) and services under various master purchasing and service agreements to which GE (and not GE O&G) is a party.

We receive an allocated share of GE’s corporate overhead for certain services that GE provides to us, but which are not specifically billed to us, such as public relations, investor relations, treasury and internal audit services. Costs of $210 million, $180 million and $189 million for the years ended December 31, 2016, 2015 and 2014, respectively, were recorded in our Combined Statement of Income (Loss) for our allocated share of GE’s corporate overhead.

EMPLOYEE BENEFITS

Our employees are covered under various U.S. GE employee benefit plans, including GE’s retirement plans (pension, retiree health and life insurance, and savings benefit plans) and active health and life insurance benefit plans. Further details are provided in Note 12.

RELATED PARTY BALANCES

The table below presents amounts due to and due from GE and its affiliates, which have been reflected in our Combined Statement of Financial Position.
 	 	2016	 	 	2015	 	
Amounts due from GE and its affiliates	 	 	 	 	 	 	
Current receivables	 	$	236	 	 	$	233	 	
Loan receivable	 	 	3	 	 	 	9	 	
Amounts due to GE and its affiliates	 	 	 	 	 	 	 	 	
Accounts payable (a)	 	$	(426	)	 	$	(525	)	
Accounts payable amounts factored through monetization program (b)	 	 	(104	)	 	 	(114	)	
Borrowings	 	 	(121	)	 	 	(134	)	

(a) Relates to cash collected on current receivables to be paid to GE under our monetization program and other services provided by GE, and are recorded in accounts payable in our Combined Statement of Financial Position.
(b) Relates to cash due to GE under our payables monetization program.
RECEIVABLES MONETIZATION

We monetize a portion of our current receivables through programs established for GE and various GE subsidiaries. We account for receivables monetized as sales in accordance with  ASC 860, Transfers and Servicing .

 
51    GE O&G Annual FS

 

GE O&G’s current receivables are legally transferred through receivable factoring programs established for GE and various GE subsidiaries administered by Working Capital Solutions (WCS), an operating unit of GE Capital.

The Business factors U.S. and non-U.S. receivables to GE Capital on a recourse and nonrecourse basis pursuant to various factoring and services agreements, purchased directly by WCS, GE Capital or sold to external investors through WCS agent arranger or buy/sell structures. Under the factoring programs, GE Capital performs a risk analysis and allocates a nonrecourse credit limit for each customer. If the portfolio exceeds this credit limit, then the receivable is factored with recourse. The evaluation of whether recourse transactions qualify for accounting derecognition is based, in part, upon the legal jurisdiction of the sales;as such, the majority of recourse transactions outside the U.S. qualify for sale treatment.

In addition, GE O&G participates in the GE Accounts Receivable (GEAR) program, in which the Business transfers its receivables into a securitization structure administered by GE Capital through the GE Receivables and Sale Contribution Agreement.

Transfers of receivables under WCS administered programs are generally accounted for as sales.

 	 	2016	 	 	2015	 	 	2014	 	
Transfers of receivables accounted for as sales	 	$	2,168	 	 	$	2,321	 	 	$	2,756	 	

Under the programs, we retain the responsibility for servicing the receivables and remitting collections to the owner and the lenders for a fee equal to the prevailing market rate for such services. We have outsourced our servicing responsibilities to GE Capital for a market-based fee and accordingly, no servicing asset or liability has been recorded on the Combined Statements of Financial Position as of December 31, 2016 and 2015. Under the programs, we incurred interest expense and finance charges of $91 million, $93 million, and $103 million for the years ended December 31, 2016, 2015 and 2014, respectively, which is reflected on the Combined Statements of Income.

Trade Payables Accelerated Payment Program

The Business’s North American operations participate in accounts payable programs with GE Capital.  The Business settles invoices with vendors to obtain cash discounts.  GE Capital provides funding for the period from the date at which an invoice is eligible for cash discount through the final termination date for invoice settlement. The Business’s liability associated with the funded participation in the accounts payable programs, which is presented as accounts payable within the Combined Statement of Financial Position, was $104 million and $114 million as of December 31, 2016 and 2015, respectively.

OTHER

From time to time, GE provides guarantees, letters of credit, and other support arrangements on our behalf.

GE also grants stock options, restricted stock units and performance share units to its group employees, including those of GE O&G as discussed in Note 22.

 
52    GE O&G Annual FS

NOTE 21	SEGMENT INFORMATION	
BASIS OF PRESENTATION

Our operating segments are organized based on the nature of markets and customers. Following the Transactions, we revised our segment structure and began to manage and report our operating results through four operating segments as defined below. We have reflected this revised structure for all historical periods presented.

OILFIELD SERVICES

Oilfield Services provides equipment and services ranging from well evaluation to decommissioning. Products and services include diamond and tri-cone drill bits, drilling services (including directional drilling technology, measurement while drilling & logging while drilling), downhole completion tools and systems, wellbore intervention tools and services, wireline services, drilling and completions fluids, oilfield and industrial chemicals, pressure pumping, and artificial lift technologies (including electrical submersible pumps).

OILFIELD EQUIPMENT

Oilfield Equipment provides a broad portfolio of products and services required to facilitate the safe and reliable flow of hydrocarbons from the subsea wellhead to the surface. Products and services include pressure control equipment and services, Subsea production systems and services, drilling equipment, and flexible pipeline systems. Oilfield Equipment operation designs and manufactures onshore and offshore drilling and production systems and equipment for floating production platforms and provides a full range of services related to onshore and offshore drilling activities.

TURBOMACHINERY & PROCESS SOLUTIONS

Turbomachinery & Process Solutions provides equipment and related services for mechanical-drive, compression and power-generation applications across the oil and gas industry as well as products and services to serve the downstream segments of the industry including refining, petrochemical, distributed gas, flow and process control and other industrial applications. The Turbomachinery & Process Solutions portfolio includes drivers (aero-derivative gas turbines, heavy-duty gas turbines and synchronous and induction electric motors), compressors (centrifugal and axial, direct drive high speed, integrated, subsea compressors, turbo expanders and reciprocating), turn-key solutions (industrial modules and waste heat recovery), pumps, valves, and compressed natural gas (CNG) and small-scale liquefied natural gas (LNG) solutions used primarily for shale oil and gas field development.

DIGITAL SOLUTIONS

Digital Solutions provides equipment and services for a wide range of industries, including oil & gas, power generation, aerospace, metals, and transportation. The offerings include sensor-based measurement, non-destructive testing and inspection, turbine, generator and plant controls and condition monitoring, as well as pipeline integrity solutions.Our operating segments are organized based on the nature of markets and customers. Segment accounting policies are the same as described and referenced in Note 2.

Certain information concerning our segments for the years ended December 31, 2016, 2015 and 2014 is presented in the following tables. Consistent accounting policies have been applied by all segments within the Business, within all reporting periods.
The performance of our operating segments is evaluated based on segment operating income (loss), which is defined as income (loss) before income taxes and equity in loss of affiliate and before the following: net interest expense, net other non operating income (loss), corporate expenses, restructuring, impairment and other charges, inventory impairments, merger and related costs, and certain gains and losses not allocated to the operating segments.

 
53    GE O&G Annual FS

 
 
 	 	Total revenues	 	
 	 	For the years ended December 31,	 	
(In millions)	 	2016	 	 	2015	 	 	2014	 	
 	 	 	 	 	 	 	 	 	 	
OFS	 	$	799	 	 	$	1,411	 	 	$	2,232	 	
OFE	 	 	3,547	 	 	 	5,060	 	 	 	5,927	 	
TPS	 	 	6,837	 	 	 	7,985	 	 	 	8,647	 	
DS	 	 	2,086	 	 	 	2,232	 	 	 	2,385	 	
Total	 	$	13,269	 	 	$	16,688	 	 	$	19,191	 	

Revenues from customers located in the United States were $3,164 million, $4,334 million and $4,580 million for the years ending December 31, 2016, 2015 and 2014, respectively. Revenues from customers located outside the United States were $10,105 million, $12,354 million and $14,611 million for the years ended December 31, 2016, 2015 and 2014, respectively.

 	 	Total pre-tax income / (loss)	 	
 	 	For the years ended December 31,	 	
(In millions)	 	2016	 	 	2015	 	 	2014	 	
OFS	 	$	(204	)	 	$	(79	)	 	$	10	 	
OFE	 	 	320	 	 	 	677	 	 	 	764	 	
TPS	 	$	1,255	 	 	$	1,684	 	 	 	1,562	 	
DS	 	 	355	 	 	 	409	 	 	 	483	 	
Total segment	 	$	1,726	 	 	$	2,691	 	 	$	2,819	 	
Corporate items and eliminations (a)	 	 	(380	)	 	 	(260	)	 	 	(164	)	
Inventory impairment	 	 	(138	)	 	 	(51	)	 	 	(8	)	
Impairment of goodwill	 	 	-	 	 	 	(2,080	)	 	 	-	 	
Restructuring, impairment and other	 	 	(516	)	 	 	(411	)	 	 	(189	)	
Merger and related costs	 	 	(33	)	 	 	(27	)	 	 	(67	)	
Other non operating income (loss), net	 	 	27	 	 	 	100	 	 	 	124	 	
Interest expense, net	 	 	(102	)	 	 	(120	)	 	 	(179	)	
Total	 	$	584	 	 	$	(158	)	 	$	2,336	 	

(a) Corporate items and eliminations is a caption used to reconcile the aggregated results of our segments to the combined results of the Business. As such, it includes the unallocated portion of costs related to corporate overheads and corporate initiatives.

 
54    GE O&G Annual FS

 
OTHER SEGMENT INFORMATION

 	 	Total Assets	 	 	Depreciation	 	
 	 	At December 31,	 	 	For the years ended December 31,	 	
(In millions)	 	2016	 	 	2015	 	 	2016	 	 	2015	 	 	2014	 	
OFS	 	$	4,046	 	 	$	4,826	 	 	$	71	 	 	$	101	 	 	$	85	 	
OFE	 	 	8,744	 	 	 	10,186	 	 	 	101	 	 	 	116	 	 	 	109	 	
TPS	 	 	8,565	 	 	 	9,944	 	 	 	101	 	 	 	102	 	 	 	111	 	
DS	 	 	3,113	 	 	 	3,205	 	 	 	38	 	 	 	32	 	 	 	30	 	
Total	 	$	24,468	 	 	$	28,161	 	 	$	311	 	 	$	351	 	 	$	335	 	
Headquarters and eliminations (a)	 	 	(2,747	)	 	 	(5,028	)	 	 	-	 	 	 	-	 	 	 	-	 	
Total	 	$	21,721	 	 	$	23,133	 	 	$	311	 	 	$	351	 	 	$	335	 	

(a) Headquarters and eliminations in total segment assets include adjustments of intercompany investments and receivables that are reflected within the total assets of the four operating segments. 

Property, plant and equipment - net associated with operations based in the United States were $833 million, $954 million and $1,027 million at December 31, 2016, 2015 and 2014, respectively. Property, plant and equipment - net associated with operations based outside the United States were $1,492 million, $1,600 million and $1,752 million at December 31, 2016, 2015 and 2014, respectively.

NOTE 22	STOCK BASED COMPENSATION	
GE grants stock options, restricted stock units and performance share units to its group employees, including those of GE O&G, under the GE Long-Term Incentive Plan. Grants made under all plans must be approved by the Management Development and Compensation Committee of GE’s Board of Directors, which is composed entirely of independent directors.

STOCK OPTIONS

Under GE’s stock option program, an employee receives an award that provides the opportunity in the future to purchase GE shares at the market price of GE’s stock on the date the award is granted (the strike price). The options become exercisable in equal amounts over a five-year vesting period and expire 10 years from the grant date if they are not exercised. Stock options have no combined financial statement effect on the date they are granted but rather are reflected over time through recording compensation expense and increasing equity. GE records compensation expense based on the estimated fair value of the awards expected to vest, and that amount is amortized as compensation expense on a straight-line basis over the five-year vesting period. Accordingly, total expense related to the award is reduced by the fair value of options that are expected to be forfeited by employees that leave GE O&G prior to vesting.

GE estimates forfeitures based on its experience and adjusts the expense to reflect actual forfeitures over the vesting period. The offset to the expense GE records is reflected as an increase in equity.

(In millions)	 	2016	 	 	2015	 	 	2014	 	
Compensation expense	 	$	$16	 	 	$	$18	 	 	$	$20	 	

The fair value of each stock option award is estimated on the date of grant using a Black-Scholes option pricing model. The table below provides the weighted average grant date fair values, key assumptions and other inputs into the pricing model. With the exception of the dividend yield assumption, an increase in any individual assumption will increase the estimated fair value of the option, all other things being equal.
 
55    GE O&G Annual FS

 
 	 	2016	 	 	2015	 	 	2014	 	
Weighted average grant-date fair value of stock options	 	$	3.61	 	 	$	4.64	 	 	$	5.26	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	
Stock option valuation assumptions:	 	 	 	 	 	 	 	 	 	 	 	 	
   Risk-free interest rate	 	 	1.4	%	 	 	2.0	%	 	 	2.3	%	
   Dividend yield	 	 	3.4	%	 	 	3.4	%	 	 	3.1	%	
   Expected volatility	 	 	20.0	%	 	 	25.0	%	 	 	26.0	%	
   Expected option life (in years)	 	 	6.5	 	 	 	6.8	 	 	 	7.3	 	
Other pricing model inputs:	 	 	 	 	 	 	 	 	 	 	 	 	
   Weighted average grant-date market price of
   GE stock (strike price)	 	$	29.63	 	 	$	25.79	 	 	$	26.11	 	

 

 

56    GE O&G Annual FS

 
The table below shows the amount and weighted average strike price of options granted during 2016, as well as those outstanding and exercisable at year-end 2016.
As of December 31, 2016 unless, otherwise stated
 (in thousands, except option data)	 	Number of
options	 	 	Weighted average
exercise price per option	 	
Outstanding at December 31, 2015	 	 	24,556,731	 	 	$	22.04	 	
Granted	 	 	2,111,300	 	 	 	29.68	 	
Exercised	 	 	(2,802,534	)	 	 	19.70	 	
Forfeited	 	 	(517,683	)	 	 	25.15	 	
Expired	 	 	(426,444	)	 	 	32.84	 	
Outstanding at December 31, 2016	 	 	22,921,370	 	 	$	22.76	 	
Exercisable at December 31, 2016	 	 	13,989,953	 	 	$	20.61	 	

The weighted average remaining contractual term for options outstanding and options exercisable at December 31, 2016 were 5.4 years and 4.4 years, respectively.
When an employee exercises an option, GE issues treasury shares to satisfy the requirements of the option.
 	 	2016	 	 	2015	 	 	2014	 	
Stock options exercised	 	 	2,802,534	 	 	 	4,160,871	 	 	 	1,612,566	 	
Cash received from stock options exercised (in millions)	 	$	55	 	 	$	76	 	 	$	26	 	

As of December 31, 2016, there was $33 million of unrecognized compensation expense related to unvested options, which will be amortized over the remaining vesting period (the weighted average period is approximately 2 years). Of that total, approximately $9 million, after tax, is estimated to be recorded as compensation expense in 2017.
RESTRICTED STOCK
A restricted stock award provides an employee with the right to receive shares of GE when the restrictions lapse, which occurs in equal amounts over the vesting period. Upon vesting, each unit of restricted stock is converted into GE common stock on a one for one basis using treasury stock shares. The expense to be recognized on restricted stock is based upon the market price on the grant date (which is its fair value) times the number of units expected to vest. Accordingly, total expense related to the award is reduced by the fair value of restricted stock units that are expected to be forfeited by employees that leave GE O&G prior to lapse of the restrictions. That amount is amortized as compensation expense on a straight-line basis over the five-year vesting period. We estimate forfeitures based on our experience and adjust the expense to reflect actual forfeitures over the vesting period. The offset to compensation expense is an increase in equity.

(In millions, after tax)	 	2016	 	 	2015	 	 	2014	 	
Compensation expense	 	$	8	 	 	$	6	 	 	$	7	 	

 
57    GE O&G Annual FS

 
The fair value of a restricted stock unit at the grant date is equal to the market price of our stock on the grant date.
 	 	2016	 	 	2015	 	 	2014	 	
Weighted average grant-date fair value of restricted stock awards	 	$	30.20	 	 	$	26.74	 	 	$	26.08	 	

As of December 31, 2016, unless otherwise stated (in thousands, except per share data)	 	Number of awards	 	 	Weighted Average
Grant Date Fair Value Per Award/Unit	 	
Non-vested at December 31, 2015	 	 	979,349	 	 	$	24.26	 	
Granted	 	 	752,300	 	 	 	30.00	 	
Vested	 	 	(232,510	)	 	 	24.46	 	
Forfeited	 	 	(32,558	)	 	 	26.32	 	
Non-vested at December 31, 2016	 	 	1,466,581	 	 	$	27.13	 	

The table below provides information about the units of restricted stock that vested for each of the years presented.
 	 	2016	 	 	2015	 	 	2014	 	
Restricted stock vested during the year ended	 	 	232,510	 	 	 	265,065	 	 	 	244,718	 	

As of December 31, 2016, there was $29 million of total unrecognized compensation expense related to unvested restricted stock, which will be amortized over the remaining vesting period (the weighted average period is approximately 2 years). Of that total, approximately $6 million, after tax, is estimated to be recorded as compensation expense in 2017.
OTHER INFORMATION
When options are exercised and restricted stock vests, GE issues shares from treasury stock, which increases their shares outstanding. Equity is adjusted for differences between the strike price of GE stock and the average cost of the treasury stock. We also record the difference between the tax benefits assumed (based on the fair value of the award on the grant date) and the actual tax benefit in our provision for income taxes. Any excess tax benefit is recorded as a cash flow from operating activities in our Combined Statement of Cash Flows. The table below provides information about tax benefits related to all share-based compensation arrangements.
(In millions)	 	2016	 	 	2015	 	 	2014	 	
Income tax benefit recognized in income	 	$	13	 	 	$	8	 	 	$	9	 	
Excess of actual tax deductions over amounts assumed recognized
in equity (a)	 	 	-	 	 	 	9	 	 	 	3	 	

(a) We adopted ASU 2016-09 in September 2016. The primary effects of adoption were the recognition of excess tax benefits in our provision for income taxes rather than paid-in capital and the reclassification of cash flows related to excess tax benefits from a financing activity to an operating activity for the periods beginning January 1, 2016. See Note 2 for further information.

 
58    GE O&G Annual FS

Share based compensation programs serve as a means to attract and retain talented employees and are an important element of their total compensation. The intrinsic value of a stock option award is the amount by which the award is in the money and represents the potential value to the employee upon exercise of the option. The intrinsic value of restricted stock is the value of the shares awarded at the current market price. The table below provides information about the intrinsic value of option and restricted stock awards.
As of December 31, 2016, unless otherwise stated (In millions)	 	Aggregate intrinsic value	 	
Stock options outstanding	 	$	205	 	
Stock options exercised in 2016	 	 	31	 	
Non-vested restricted stock outstanding	 	 	46	 	
Restricted stock vested in 2016	 	 	7	 	
             
NOTE 23	RESTRUCTURING, IMPAIRMENT AND OTHER	

During 2016, 2015 and 2014, we approved various restructuring plans globally, mainly to consolidate manufacturing and service facilities, rationalize product lines and rooftops, and reduce headcount across various functions. As a result, we recognized a charge of $293 million, $314 million $105 million for the periods ended December 31, 2016, 2015 and 2014, respectively. These restructuring initiatives will generate charges post 2016, and the related estimated remaining charges are approximately $66 million.

These expenses are included as part of “Restructuring, impairment and other” in the Combined Statement of Income (Loss).
The amount of costs not included in the reported segment results is as follows:
(in millions)	 	2016	 	 	2015	 	 	2014	 	
OFS	 	$	122	 	 	$	183	 	 	$	9	 	
OFE	 	 	52	 	 	 	32	 	 	 	22	 	
TPS	 	 	58	 	 	 	54	 	 	 	9	 	
DS	 	 	34	 	 	 	26	 	 	 	41	 	
GE O&G Headquarters	 	 	27	 	 	 	19	 	 	 	24	 	
Total	 	$	293	 	 	$	314	 	 	$	105	 	
 
59    GE O&G Annual FS

 
These costs were primarily related to product line terminations, plant closures and related expenses such as property, plant and equipment impairments, contract terminations and costs of assets’ and employees’ relocation, employee-related termination benefits, and other incremental costs that were a direct result of the plans.
(in millions)	 	2016	 	 	2015	 	 	2014	 	
Property, plant & equipment, net	 	$	93	 	 	$	137	 	 	$	7	 	
Employee-related termination expenses	 	 	111	 	 	 	103	 	 	 	54	 	
Asset relocation costs	 	 	17	 	 	 	14	 	 	 	-	 	
EHS remediation costs	 	 	20	 	 	 	17	 	 	 	1	 	
Contract termination fees	 	 	37	 	 	 	26	 	 	 	11	 	
Other incremental costs	 	 	15	 	 	 	17	 	 	 	32	 	
Total	 	$	293	 	 	$	314	 	 	$	105	 	

Other charges included in “Restructuring, impairment and other” caption of the condensed consolidated and combined statements of income (loss) was $223 million, $97 million and $84 million in 2016, 2015 and 2014, respectively. Other charges include currency devaluation charges of $138 million, $63 million and $20 million in 2016, 2015 and 2014, respectively, largely driven by significant currency devaluations in Angola and Nigeria. These markets have minimal currency derivative liquidity which limits our ability to offset these exposures.

NOTE 24	SUBSEQUENT EVENTS	
 
On July 3, 2017, GE O&G and Baker Hughes Incorporated (Baker Hughes) combined to create a fullstream oilfield technology provider that has a unique mix of equipment and service capabilities. The business combination was executed using a partnership structure, pursuant to which GE O&G and Baker Hughes each contributed their operating assets to Baker Hughes, a GE Company, LLC, a Delaware limited liability company and the successor to Baker Hughes. At close GE owned an approximate 62.5% interest in BHGE LLC and former Baker Hughes shareholders owned the remaining approximate 37.5% interest.

 

 

60    GE O&G Annual FS

 
Exhibit 99.4
UNAUDITED PRO FORMA CONDENSED COMBINED FINANCIAL STATEMENTS
The following Unaudited Pro Forma Condensed Combined Financial Statements of Baker Hughes, a GE company, LLC (“BHGE LLC”) present the combination of the historical financial information of General Electric Company’s (“GE”) Oil & Gas business (“GE O&G”) and Baker Hughes Incorporated (“Baker Hughes”) adjusted to give effect to the Transactions, as defined in “Description of Transactions” in the notes to the Unaudited Pro Forma Condensed Combined Financial Statements, to be accounted for under the acquisition method of accounting in accordance with Accounting Standards Codification 805, Business Combinations (“ASC 805”).
The Unaudited Pro Forma Condensed Combined Statement of Income (Loss) for the nine-month period ended September 30, 2017 and for the fiscal year ended December 31, 2016 combines the historical Combined Statement of Income (Loss) of BHGE LLC and the Consolidated Statement of Income (Loss) for Baker Hughes, giving effect to the Transactions as if their consummation (“Closing”) had occurred on January 1, 2016.
The Unaudited Pro Forma Condensed Combined Financial Statements were prepared using the acquisition method of accounting with GE O&G considered the accounting acquirer of Baker Hughes. Under the acquisition method of accounting, the purchase price is allocated to the identifiable tangible and intangible assets acquired and liabilities assumed based on their respective fair values with any excess purchase price allocated to goodwill. The pro forma purchase price allocation is preliminary and was based on an estimate of the fair values of the tangible and intangible assets and liabilities related to Baker Hughes and the closing price of Baker Hughes common stock of $57.68 on July 3, 2017. BHGE LLC expects to complete the purchase price allocation after considering the appraisal of Baker Hughes’ assets at the level of detail necessary to finalize the required purchase price allocation, which will be no later than one year from Closing. The pro forma adjustments included herein may be revised as additional information becomes available and as additional analyses are performed. The final purchase price allocation may be different than that reflected in the preliminary pro forma purchase price allocation presented herein, and this difference may be material.
The Unaudited Pro Forma Condensed Combined Financial Statements do not reflect the costs of any integration activities or benefits that may result from the realization of future cost savings from operating efficiencies or revenue synergies that may result from the Transactions.
The Unaudited Pro Forma Condensed Combined Financial Statements should be read in conjunction with:

 	•	the accompanying notes to the Unaudited Pro Forma Condensed Combined Financial Statements;	

 	•	the unaudited condensed combined historical financial statements of BHGE LLC as of and for the nine-month period ended September 30, 2017 and related notes (as filed with the SEC on October 31, 2017 in BHGE LLC’s Quarterly Report on Form 10-Q), and the audited historical combined financial statements of GE O&G as of and for the fiscal year ended December 31, 2016 and related notes (included as Exhibit 99.3 to this Current Report on Form 8-K).	

 	•	the unaudited historical consolidated condensed financial statements of Baker Hughes as of and for the six-month period ended June 30, 2017 and related notes (as filed with the SEC on July 28, 2017 in BHGE LLC’s Quarterly Report on Form 10-Q for the six-months ended June 30, 2017), and the audited historical consolidated financial statements of Baker Hughes as of and for the fiscal year ended December 31, 2016 and related notes (as filed with the SEC on February 8, 2017 in Baker Hughes’ Annual Report on Form 10-K for the fiscal year ended December 31, 2016).	

 

1

 

BAKER HUGHES, A GE COMPANY, LLC
 UNAUDITED PRO FORMA CONDENSED COMBINED STATEMENT OF INCOME (LOSS)
For the nine-month period ended September 30, 2017
(in millions)

 	 	BHGE LLC
September 30,
2017	 	 	BHI
June 30,
2017	 	 	Acquisition
Adjustments
(Note 3)	 	 	 	 	 	Other Merger
Related
Adjustments
(Note 4)	 	 	 	 	 	Items not
allocable to
BHGE LLC
(Note 5)	 	 	 	 	 	Pro Forma
Condensed
Combined	 	
Revenues and other income	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Sales of goods	 	$	7,541	 	 	$	1,957	 	 	$	-	 	 	 	 	 	$	(4	)	 	4(a)	 	 	$	-	 	 	 	 	 	$	9,494	 	
Sales of services	 	 	3,955	 	 	 	2,709	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	6,664	 	
Total revenue	 	$	11,496	 	 	$	4,666	 	 	$	-	 	 	 	 	 	$	(4	)	 	 	 	 	$	-	 	 	 	 	 	$	16,158	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Cost and expenses	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Cost of goods sold	 	 	6,341	 	 	 	1,668	 	 	 	-	 	 	 	 	 	 	84	 	 	4(b)	 	 	 	-	 	 	 	 	 	 	8,093	 	
Cost of services sold	 	 	2,818	 	 	 	2,304	 	 	 	-	 	 	 	 	 	 	117	 	 	4(b)	 	 	 	-	 	 	 	 	 	 	5,239	 	
Research and engineering	 	 	-	 	 	 	201	 	 	 	-	 	 	 	 	 	 	(201	)	 	4(b)	 	 	 	-	 	 	 	 	 	 	-	 	
Selling, general and administrative expenses	 	 	1,750	 	 	 	409	 	 	 	71	 	 	3(a)	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	2,230	 	
Restructuring, impairment and other	 	 	292	 	 	 	90	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	382	 	
Merger and related costs	 	 	310	 	 	 	80	 	 	 	-	 	 	 	 	 	 	(390	)	 	4(c)	 	 	 	-	 	 	 	 	 	 	-	 	
Total cost and expenses	 	 	11,511	 	 	 	4,752	 	 	 	71	 	 	 	 	 	 	(390	)	 	 	 	 	 	-	 	 	 	 	 	 	15,944	 	
Operating income (loss)	 	 	(15	)	 	 	(86	)	 	 	(71	)	 	 	 	 	 	386	 	 	 	 	 	 	-	 	 	 	 	 	 	214	 	
Other non operating income (loss), net	 	 	65	 	 	 	-	 	 	 	-	 	 	 	 	 	 	4	 	 	4(a)	 	 	 	-	 	 	 	 	 	 	69	 	
Interest expense, net	 	 	(75	)	 	 	(65	)	 	 	22	 	 	3(b)	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	(118	)	
Income (loss) before income taxes and equity in loss of affiliate	 	 	(25	)	 	 	(151	)	 	 	(49	)	 	 	 	 	 	390	 	 	 	 	 	 	-	 	 	 	 	 	 	165	 	
Equity in loss of affiliate	 	 	(13	)	 	 	(39	)	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	(52	)	
Benefit (provision) for income taxes	 	 	(125	)	 	 	(119	)	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	(181	)	 	5(a)	 	 	 	(425	)	
Net income (loss)	 	 	(163	)	 	 	(309	)	 	 	(49	)	 	 	 	 	 	390	 	 	 	 	 	 	(181	)	 	 	 	 	 	(312	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Less: net income (loss) attributable to noncontrolling interests	 	 	5	 	 	 	(1	)	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	4	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Net income (loss) attributable to the Business	 	$	(168	)	 	$	(308	)	 	$	(49	)	 	 	 	 	$	390	 	 	 	 	 	$	(181	)	 	 	 	 	$	(316	)	

See accompanying Notes to the Unaudited Pro Forma Condensed Combined Financial Statements

 

2

 
BAKER HUGHES, A GE COMPANY, LLC
UNAUDITED PRO FORMA CONDENSED COMBINED STATEMENT OF INCOME (LOSS)
For the fiscal year ended December 31, 2016
(in millions)

 
 	 	Historial	 	 	Pro Forma Adjustments	 	 	 	 	 	 	 	
 	 	GE O&G	 	 	BHI	 	 	Acquisition
Adjustments
(Note 3)	 	 	 	 	 	Other Merger
Related
Adjustments
(Note 4)	 	 	 	 	 	Items not
allocable to
BHGE LLC
(Note 5)	 	 	 	 	 	Pro Forma
Condensed
Combined	 	
Revenues and other income	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Sales of goods	 	$	9,488	 	 	$	3,870	 	 	$	-	 	 	 	 	 	$	(8	)	 	4(a)	 	 	$	-	 	 	 	 	 	$	13,350	 	
Sales of services	 	 	3,781	 	 	 	5,971	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	9,752	 	
Total revenue	 	$	13,269	 	 	$	9,841	 	 	$	-	 	 	 	 	 	$	(8	)	 	 	 	 	$	-	 	 	 	 	 	$	23,102	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Cost and expenses	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Cost of goods sold	 	 	7,816	 	 	 	3,722	 	 	 	-	 	 	 	 	 	 	143	 	 	4(b)	 	 	 	-	 	 	 	 	 	 	11,681	 	
Cost of services sold	 	 	2,307	 	 	 	6,251	 	 	 	-	 	 	 	 	 	 	241	 	 	4(b)	 	 	 	-	 	 	 	 	 	 	8,799	 	
Research and engineering	 	 	-	 	 	 	384	 	 	 	-	 	 	 	 	 	 	(384	)	 	4(b)	 	 	 	-	 	 	 	 	 	 	-	 	
Selling, general and administrative expenses	 	 	1,938	 	 	 	815	 	 	 	121	 	 	3(a)	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	2,874	 	
Restructuring, impairment and other	 	 	516	 	 	 	1,735	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	2,251	 	
Impairment of goodwill	 	 	-	 	 	 	1,858	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	 	 	 	 	 	 	 	1,858	 	
Merger and related costs	 	 	33	 	 	 	(3,301	)	 	 	-	 	 	 	 	 	 	(40	)	 	4(c)	 	 	 	-	 	 	 	 	 	 	(3,308	)	
Total cost and expenses	 	 	12,610	 	 	 	11,464	 	 	 	121	 	 	 	 	 	 	(40	)	 	 	 	 	 	-	 	 	 	 	 	 	24,155	 	
Operating income (loss)	 	 	659	 	 	 	(1,623	)	 	 	(121	)	 	 	 	 	 	32	 	 	 	 	 	 	-	 	 	 	 	 	 	(1,053	)	
Other non operating income (loss), net	 	 	27	 	 	 	(97	)	 	 	-	 	 	 	 	 	 	8	 	 	4(a)	 	 	 	-	 	 	 	 	 	 	(62	)	
Loss on extinguishment of debt	 	 	-	 	 	 	(142	)	 	 	-	 	 	 	 	 	 	142	 	 	4(d)	 	 	 	 	 	 	 	 	 	 	-	 	
Interest expense, net	 	 	(102	)	 	 	(178	)	 	 	54	 	 	3(b)	 	 	 	(142	)	 	4(d)	 	 	 	-	 	 	 	 	 	 	(368	)	
Income (loss) before income taxes and equity in loss of affiliate	 	 	584	 	 	 	(2,040	)	 	 	(67	)	 	 	 	 	 	40	 	 	 	 	 	 	-	 	 	 	 	 	 	(1,483	)	
Equity in loss of affiliate	 	 	-	 	 	 	-	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	-	 	
Benefit (provision) for income taxes	 	 	(250	)	 	 	(696	)	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	307	 	 	5(a)	 	 	 	(639	)	
Net income (loss)	 	 	334	 	 	 	(2,736	)	 	 	(67	)	 	 	 	 	 	40	 	 	 	 	 	 	307	 	 	 	 	 	 	(2,122	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Less: net income (loss) attributable to noncontrolling interests	 	 	(69	)	 	 	2	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	-	 	 	 	 	 	 	(67	)	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Net income (loss) attributable to the Business	 	$	403	 	 	$	(2,738	)	 	$	(67	)	 	 	 	 	$	40	 	 	 	 	 	$	307	 	 	 	 	 	$	(2,055	)	

See accompanying Notes to the Unaudited Pro Forma Condensed Combined Financial Statements

3

 
NOTES TO THE UNAUDITED PRO FORMA CONDENSED COMBINED FINANCIAL STATEMENTS
Note 1. Description of the Transactions
The previously announced combination (the “Transactions”) of GE O&G and Baker Hughes was completed on July 3, 2017 (the “Closing Date”) pursuant to the Transaction Agreement and Plan of Merger, dated as of October 30, 2016, among GE, Baker Hughes, Bear NewCo, Inc. (which was renamed “Baker Hughes, a GE company”) (“BHGE”) and Bear MergerSub, Inc., as amended by the Amendment to Transaction Agreement and Plan of Merger, dated as of March 27, 2017, among GE, Baker Hughes, BHGE, Bear MergerSub, Inc., BHI Newco, Inc. (“Newco 2”) and Bear MergerSub 2, Inc. (the “Transaction Agreement”).
The Transactions included (i) the merger of Baker Hughes with Bear MergerSub 2, Inc., an indirect, wholly owned subsidiary of Baker Hughes, with Baker Hughes surviving the merger as a direct wholly owned subsidiary of Newco 2 (the “First Merger”), (ii) the conversion of the surviving corporation of the First Merger into a Delaware limited liability company (which was originally named Newco LLC and then renamed Baker Hughes, a GE company, LLC) (the “Conversion”), (iii) the merger of Newco 2 with BHGE, with BHGE surviving the merger (the “Second Merger” and collectively with the First Merger, the “Mergers”) and (iv) the transfer by GE to BHGE LLC, following the Mergers and the Conversion, of (1) all of the equity interests of the GE O&G holding companies that held directly or indirectly the assets and liabilities of GE O&G, including GE O&G operating subsidiaries, and (2) $7.4 billion in cash in exchange for approximately 62.5% of the membership interests in BHGE LLC (the “Contribution”).  GE also received Class B common stock, par value $0.0001 per share (the “Class B Common Stock”), of BHGE, representing approximately 62.5% of the voting power of the outstanding shares of common stock of BHGE, in exchange for contributing the par value thereof to BHGE.
As a result of the Mergers, each outstanding share of Baker Hughes common stock was converted into the right to receive one share of BHGE’s Class A common stock, par value $0.0001 per share (the “Class A Common Stock”).  Following the Mergers and the Contribution, BHGE declared as a special dividend an amount equal to $17.50 per share (the “Dividend”) to the holders of record of the Class A Common Stock immediately following the effective time of the Second Merger.  The Class A Common Stock is listed on the New York Stock Exchange LLC (“NYSE”).
Note 2. Basis of Presentation
The accompanying Unaudited Pro Forma Condensed Combined Financial Statements present the pro forma consolidated results of operations of BHGE LLC based upon the historical financial statements of each of GE O&G and Baker Hughes, after giving effect to the Transactions and are intended to reflect the impact of the Transactions on BHGE LLC’s consolidated statements of income (loss).
The accompanying Unaudited Pro Forma Condensed Combined Financial Statements have been prepared using and should be read in conjunction with the respective unaudited consolidated or combined condensed financial statements of BHGE LLC for the nine-month period ended September 30, 2017, Baker Hughes for the six-month period ended June 30, 2017 and the audited historical financial statement of GE O&G and Baker Hughes for the fiscal year ended December 31, 2016. The accompanying Unaudited Pro Forma Condensed Combined Financial Statements are presented for illustrative purposes only and do not reflect the costs of any integration activities or benefits that may result from realization of future costs savings due to operating efficiencies or revenue synergies that may result from the Transactions.
The Unaudited Pro Forma Condensed Combined Statement of Income (Loss) for the nine-month period ended September 30, 2017 combines the historical Condensed Combined Statement of Income (Loss) of BHGE LLC and the historical Consolidated Condensed Statement of Income (Loss) of Baker Hughes for the six-month period ended June 30, 2017, to reflect the Transactions as if Closing had occurred on January 1, 2016.
The Unaudited Pro Forma Condensed Combined Statement of Income (Loss) for the fiscal year ended December 31, 2016 combines the historical Condensed Combined Statement of Earnings of GE O&G and the historical Consolidated Condensed Statement of Income (Loss) of Baker Hughes for the fiscal year ended December 31, 2016, to reflect the Transactions as if Closing had occurred on January 1, 2016.
The accompanying Unaudited Pro Forma Condensed Combined Financial Statements of the combined company have been prepared in accordance with GAAP. The Mergers have collectively been accounted for as a business combination, with GE O&G treated as the “acquirer” and Baker Hughes treated as the “acquired” company for financial reporting purposes.
The unaudited historical consolidated condensed financial statements of Baker Hughes have been adjusted to reflect certain reclassifications in order to conform to GE O&G’s financial statement presentation.
 
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The accompanying Unaudited Pro Forma Condensed Combined Financial Statements present the pro forma consolidated tax results based on the treatment of BHGE LLC as a partnership for U.S. federal income tax purposes following Closing. As such, BHGE LLC itself is not subject to U.S. federal income tax under current U.S. tax laws. BHGE LLC will file a U.S. federal partnership information return that reports its U.S. items of income, gain, loss and deduction for each taxable year. The members of BHGE LLC will each be required to take into account for U.S. federal income tax purposes its distributive share of the items of income, gain, loss and deduction of BHGE LLC, which generally will include the items of income, gain, loss and deduction attributable to the U.S. operations of both Baker Hughes and GE O&G. BHGE and GE will each be taxed on their distributive share of income and gain, whether or not a corresponding amount of cash or other property is distributed to them. For assets held indirectly by BHGE LLC through subsidiaries, the taxes attributable to those subsidiaries will be reflected in the consolidated financial statements of BHGE LLC and BHGE.
For purposes of these Unaudited Pro Forma Condensed Combined Financial Statements, a global blended statutory tax rate of 36% has been used. This does not reflect BHGE LLC’s effective tax rate, which includes other tax items such as state and foreign taxes, which are generally at tax rates lower than the U.S. federal income tax rate as well as other tax charges and benefits, and does not take into account any historical or possible future tax events that may impact BHGE LLC.
Certain columns may not add due to the use of rounded numbers.
Note 3. Purchase Accounting Adjustments
The Unaudited Pro Forma Condensed Combined Statements of Income (Loss) reflect the allocation of the preliminary estimated purchase price to identifiable assets to be acquired and liabilities to be assumed, with the excess recorded as goodwill. The purchase price allocation in these Unaudited Pro Forma Condensed Combined Financial Statements is based upon a purchase price of approximately $24,798 million and results in goodwill of approximately $13,144 million.

The purchase price is computed using the value of Baker Hughes’ share price on the Closing Date of $57.68 per share.
The following table summarizes the components of the estimated merger consideration reflected in the unaudited pro forma condensed combined financial information (in millions except share and per-share data):
 
Purchase Consideration	 	July 3, 2017	
 	 	 (in millions, except share and per share amounts) 	
Baker Hughes shares outstanding	 	 	426,097,407	 	
Restricted stock units vested upon closing	 	 	1,611,566	 	
 	 	 	 	 	
Total Baker Hughes shares outstanding for merger consideration	 	 	427,708,973	 	
Baker Hughes share price on July 3, 2017 per share	 	$	57.68	 	
 	 	 	 	 	
Purchase consideration	 	$	24,670	 	
 	 	 	 	 	
Rollover of outstanding options into options to purchase Class A shares of BHGE (fair value)	 	 	114	 	
 	 	 	 	 	
Precombination service of restricted stock units (fair value)	 	 	14	 	
Total purchase consideration	 	$	24,798	 	

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The following table summarizes the preliminary allocation of purchase consideration to the identifiable assets acquired and liabilities assumed of Baker Hughes:
Preliminary identifiable assets acquired and liabilities assumed	 	Estimated Fair Value
at July 3, 2017	
Assets	 	 	 	
Cash and equivalents	 	$	4,133	 	
Current receivables	 	 	2,378	 	
Inventories	 	 	1,975	 	
Property, plant and equipment	 	 	4,048	 	
Other intangible assets	 	 	4,400	 	
All other assets	 	 	1,395	 	
Liabilities	 	 	 	 	
Accounts payable	 	 	(1,115	)	
Borrowings	 	 	(3,373	)	
Liabilities for pensions and other postretirement benefits	 	 	(684	)	
All other liabilities	 	 	(1,426	)	
Total identifiable net assets	 	$	11,731	 	
Noncontrolling interest associated with net assets acquired	 	 	(77	)	
Goodwill	 	 	13,144	 	
Total purchase consideration	 	$	24,798	 	
The estimated intangible assets attributable to the Transactions are comprised of the following (in millions except weighted average life):
 	 	 	 	 	Amortization Expense	 	 	 	 	
 	 	Fair
value	 	 	Six-month
period ended
June 30,
2017	 	 	Fiscal
year ended
December 31,
2016	 	 	Estimated Weighted
Average Life (Years)	 	
Customer relationships	 	$	1,300	 	 	$	43	 	 	$	87	 	 	 	15	 	
Trade name—Baker Hughes	 	 	2,000	 	 	 	—	 	 	 	—	 	 	Indefinite-lived	 	
Trade names—Other	 	 	200	 	 	 	10	 	 	 	20	 	 	 	10	 	
Developed Technology	 	 	900	 	 	 	45	 	 	 	90	 	 	 	10	 	
Total	 	$	4,400	 	 	$	98	 	 	$	197	 	 	 	 	 	
The estimated fair values for this pro forma presentation for technology and trade names were measured using the relief-from-royalty method. This method assumes the developed technology and trade names have value to the extent that the owner is relieved of the obligation to pay royalties for the benefits received from them.
The estimated fair value for this pro forma presentation for customer relationships is measured using the discounted cash flow method.
The use of different methodologies or assumptions could result in different values, and those differences could be significant.

The Unaudited Pro Forma Condensed Combined Statements of Income (Loss) reflect the following adjustments:

3(a)	Represents net change in selling, general and administrative expenses of $71 million and $121 million for the pre-Merger periods (six-month period ended June 30, 2017 and the fiscal year ended December 31, 2016, respectively), resulting from adjustments to intangible assets described in Note 3 and the removal of historical amortization of pre-existing intangibles of $27 million and $76 million for the pre-Merger periods (six-month period ended June 30, 2017 and the fiscal year ended December 31, 2016, respectively).	
 
3(b)	Represents a decrease in interest and other financial charges of $22 million and $54 million for the pre-Merger periods (six-month period ended June 30, 2017 and the fiscal year ended December 31, 2016, respectively), resulting from the amortization, by the effective interest method, of the fair value increase to debt (an adjustment of $364 million to record Baker Hughes’ debt at its estimated fair value of $3,143 million (carrying value at July 3, 2017 of $2,779 million) which generates a reduction of interest expense in a manner similar to the amortization of debt premium.	

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Note 4. Other Adjustments

In addition to the purchase accounting adjustments described in Note 3, other adjustments were made as described in this Note 4.

The Unaudited Pro Forma Condensed Combined Statements of Income (Loss) reflect the following adjustments:

4(a)	Represent the reclassification of royalty income of $4 million and $8 million for the pre-Merger periods (six-month period ended June 30, 2017 and the fiscal year ended December 31, 2016, respectively), to conform the amounts of Baker Hughes to GE O&G’s financial statement presentation, which reflects similar costs as other non-operating income (loss).	

4(b)	Represents the reclassification of research and engineering costs of $201 million and $384 million for the pre-Merger periods (six-month period ended June 30, 2017 and the fiscal year ended December 31, 2016, respectively), to conform the amounts of Baker Hughes to GE O&G’s financial statement presentation, which reflects similar costs as either cost of goods sold or cost of services sold depending on their nature. The reclassification is as follows:	

 	•	increase to cost of goods sold of $84 million and $143 million for the pre-Merger periods (six-month period ended June 30, 2017 and the fiscal year ended December 31, 2016, respectively); and	

 	•	increase to cost of services sold of $117 million and $241 million for the pre-Merger periods (six-month period ended June 30, 2017 and the fiscal year ended December 31, 2016, respectively).	

4(c)	Represents the net elimination of costs related to the Transactions, including legal, professional and other directly attributable transaction costs, of $390 million and $40 million that were reflected in the historical financial statements of (i) BHGE LLC for the nine-month period ended September 30, 2017 and Baker Hughes for the pre-Merger period (six-month period ended June 30, 2017), and (ii) GE O&G and Baker Hughes for the fiscal year ended December 31, 2016, respectively, that are non-recurring, directly attributable to the Transactions and incurred within 12 months of the transactions.	

4(d)	Represents the reclassification of loss on early extinguishment of debt of $142 million to conform the amounts of Baker Hughes to GE O&G’s financial statement presentation for the fiscal year ended December 31, 2016.	

Note 5. Items Not Allocable to BHGE LLC
The following represent an adjustment to the historical financial statements of GE O&G and Baker Hughes to give effect to the formation of BHGE LLC as an entity that is taxed as a partnership pursuant to the terms of the Transaction Agreement and the agreement of the parties with respect to pre-Closing tax liabilities and assets.

5(a)	Represents an adjustment of $(181) million and $307 million for the pre-Merger periods (six-month period ended June 30, 2017 and the fiscal year ended December 31, 2016, respectively). The adjustments eliminate all of the historical U.S taxes associated with assets held directly by BHGE LLC.	

Note 6. Items Not Included
The following impacts, which could be material, related to the Transactions are not included or provided for in the Unaudited Pro Forma Condensed Combined Statements of Income (Loss):

 	•	Property, plant and equipment has not been adjusted as BHGE LLC will require additional information to complete its analysis. The fair value adjustment is not expected to be significant.	

 	•	Estimated transaction costs that are non-recurring, directly attributable to the Transactions and expected to be incurred within 12 months of the Transactions.	

 	•	Costs that may be incurred in connection with the integration of GE O&G and Baker Hughes, including transition services agreements, site services agreement, professional fees, consultants, information technology implementation, relocation and severance, would not be considered factually supportable.	

 	•	Other appropriate adjustments to the purchase price allocation which will be refined and recorded as more information becomes available.	
The Unaudited Pro Forma Condensed Combined Statements of Income (Loss) also do not reflect any revenue or cost synergies expected to be realized in connection with the Transactions.
 
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Note 7. Significant Non-recurring Item
In May 2016, Baker Hughes was paid a contractually obligated termination fee of $3.5 billion pursuant to the termination of the prior merger agreement with Halliburton. In addition, Baker Hughes incurred costs of $180 million associated with the prior merger agreement. These amounts are included in Baker Hughes’ Consolidated Statements of Income (Loss) for fiscal year ended December 31, 2016. The recognized income and expense are not expected to recur in future periods.

 

 

 

 
 
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