Document
                                            

                                    

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q
þ
 
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2016
OR
o
 
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Commission File Number 1-9397
Baker Hughes Incorporated
(Exact name of registrant as specified in its charter)
Delaware
76-0207995
(State or other jurisdiction
(I.R.S. Employer Identification No.)
of incorporation or organization)
 
 
 
2929 Allen Parkway, Suite 2100, Houston, Texas
77019-2118
(Address of principal executive offices)
(Zip Code)
Registrant’s telephone number, including area code: (713) 439-8600
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
YES þ NO o
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
YES þ NO o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer þ
Accelerated filer o
Non-accelerated filer o
Smaller reporting company o
 
 
(Do not check if a smaller reporting company)
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
YES o NO þ
As of July 21, 2016, the registrant has outstanding 427,901,413 shares of Common Stock, $1 par value per share.



Baker Hughes Incorporated
Table of Contents

 
 
Page No.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 


1


PART I — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)
Baker Hughes Incorporated
Consolidated Condensed Statements of Income (Loss)
(Unaudited)

 
Three Months Ended June 30,
 
Six Months Ended June 30,
(In millions, except per share amounts)
2016
 
2015
 
2016
 
2015
Revenue:
 
 
 
 
 
 
 
Sales
$
954

 
$
1,431

 
$
1,967

 
$
2,959

Services
1,454

 
2,537

 
3,111

 
5,603

Total revenue
2,408

 
3,968

 
5,078

 
8,562

Costs and expenses:
 
 
 
 
 
 
 
Cost of sales
1,182

 
1,220

 
2,126

 
2,565

Cost of services
1,930

 
2,364

 
3,644

 
5,361

Research and engineering
99

 
118

 
201

 
256

Marketing, general and administrative
222

 
264

 
429

 
551

Impairment and restructuring charges
1,126

 
76

 
1,286

 
649

Goodwill impairment
1,841

 

 
1,841

 

Merger and related costs
78

 
83

 
180

 
111

Merger termination fee
(3,500
)
 

 
(3,500
)
 

Litigation settlements

 
(13
)
 

 
(13
)
Total costs and expenses
2,978

 
4,112

 
6,207

 
9,480

Operating loss
(570
)
 
(144
)
 
(1,129
)
 
(918
)
Loss on early extinguishment of debt
(142
)
 

 
(142
)
 

Interest expense, net
(48
)
 
(53
)
 
(103
)
 
(107
)
Loss before income taxes
(760
)
 
(197
)
 
(1,374
)
 
(1,025
)
Income taxes
(152
)
 
7

 
(519
)
 
242

Net loss
(912
)
 
(190
)
 
(1,893
)
 
(783
)
Net loss attributable to noncontrolling interests
1

 
2

 
1

 
6

Net loss attributable to Baker Hughes
$
(911
)
 
$
(188
)
 
$
(1,892
)
 
$
(777
)
 
 
 
 
 
 
 
 
Basic and diluted loss per share attributable to Baker Hughes
$
(2.08
)
 
$
(0.43
)
 
$
(4.30
)
 
$
(1.77
)
 
 
 
 
 
 
 
 
Cash dividends per share
$
0.17

 
$
0.17

 
$
0.34

 
$
0.34

See accompanying Notes to Unaudited Consolidated Condensed Financial Statements.

2


Baker Hughes Incorporated
Consolidated Condensed Statements of Comprehensive Income (Loss)
(Unaudited)

 
Three Months Ended June 30,
 
Six Months Ended June 30,
(In millions)
2016
 
2015
 
2016
 
2015
Net loss
$
(912
)
 
$
(190
)
 
$
(1,893
)
 
$
(783
)
Other comprehensive income (loss):
 
 
 
 
 
 
 
Foreign currency translation adjustments during the period
(25
)
 
81

 
40

 
(91
)
Pension and other postretirement benefits, net of tax
12

 
(6
)
 
14

 
1

Other comprehensive income (loss)
(13
)
 
75

 
54

 
(90
)
Comprehensive loss
(925
)
 
(115
)
 
(1,839
)
 
(873
)
Comprehensive loss attributable to noncontrolling interests
1

 
2

 
1

 
6

Comprehensive loss attributable to Baker Hughes
$
(924
)
 
$
(113
)
 
$
(1,838
)
 
$
(867
)
See accompanying Notes to Unaudited Consolidated Condensed Financial Statements.


3


Baker Hughes Incorporated
Consolidated Condensed Balance Sheets
(Unaudited)

(In millions)
June 30,
2016
 
December 31,
2015
ASSETS
Current assets:
 
 
 
Cash and cash equivalents
$
3,910

 
$
2,324

Accounts receivable - less allowance for doubtful accounts
(2016 - $573; 2015 - $383)
2,262

 
3,217

Inventories, net
1,992

 
2,917

Deferred income taxes
196

 
301

Other current assets
1,039

 
509

Total current assets
9,399

 
9,268

Property, plant and equipment - less accumulated depreciation
(2016 - $7,269; 2015 - $7,378)
5,229

 
6,693

Goodwill
4,233

 
6,070

Intangible assets, net
439

 
583

Other assets
1,019

 
1,466

Total assets
$
20,319

 
$
24,080

LIABILITIES AND EQUITY
Current liabilities:
 
 
 
Accounts payable
$
1,023

 
$
1,409

Short-term debt and current portion of long-term debt
139

 
151

Accrued employee compensation
460

 
690

Income taxes payable
175

 
55

Other accrued liabilities
541

 
470

Total current liabilities
2,338

 
2,775

Long-term debt
2,887

 
3,890

Deferred income taxes and other tax liabilities
352

 
252

Liabilities for pensions and other postretirement benefits
651

 
646

Other liabilities
125

 
135

Commitments and contingencies


 


Equity:
 
 
 
Common stock
428

 
437

Capital in excess of par value
6,853

 
7,261

Retained earnings
7,574

 
9,614

Accumulated other comprehensive loss
(951
)
 
(1,005
)
Treasury stock
(21
)
 
(9
)
Baker Hughes stockholders’ equity
13,883

 
16,298

Noncontrolling interests
83

 
84

Total equity
13,966

 
16,382

Total liabilities and equity
$
20,319

 
$
24,080

See accompanying Notes to Unaudited Consolidated Condensed Financial Statements.

4


Baker Hughes Incorporated
Consolidated Condensed Statements of Changes in Equity
(Unaudited)

 
Baker Hughes Stockholders' Equity
 
 
 
 
(In millions, except per share amounts)
Common Stock
 
Capital
in Excess
of
Par Value
 
Retained
Earnings
 
Accumulated
Other
Comprehensive
Loss
 
Treasury Stock
 
Non-controlling
Interests
 
Total Equity
Balance at December 31, 2015
$
437

 
$
7,261

 
$
9,614

 
$
(1,005
)
 
$
(9
)
 
$
84

 
$
16,382

Comprehensive loss:
 
 
 
 
 
 
 
 
 
 
 
 
 
Net loss
 
 
 
 
(1,892
)
 
 
 
 
 
(1
)
 
(1,893
)
Other comprehensive income
 
 
 
 
 
 
54

 
 
 
 
 
54

Activity related to stock plans
2

 
13

 
 
 
 
 
(12
)
 
 
 
3

Repurchase and retirement of common stock
(11
)
 
(489
)
 
 
 
 
 
 
 
 
 
(500
)
Stock-based compensation
 
 
68

 
 
 
 
 
 
 
 
 
68

Cash dividends ($0.34 per share)
 
 
 
 
(148
)
 
 
 
 
 
 
 
(148
)
Balance at June 30, 2016
$
428

 
$
6,853

 
$
7,574

 
$
(951
)
 
$
(21
)
 
$
83

 
$
13,966


 
Baker Hughes Stockholders' Equity
 
 
 
 
(In millions, except per share amounts)
Common Stock
 
Capital
in Excess
of
Par Value
 
Retained
Earnings
 
Accumulated
Other
Comprehensive
Loss
 
Treasury Stock
 
Non-controlling
Interests
 
Total Equity
Balance at December 31, 2014
$
434

 
$
7,062

 
$
11,878

 
$
(749
)
 
$

 
$
105

 
$
18,730

Comprehensive loss:
 
 
 
 
 
 
 
 
 
 
 
 
 
Net loss
 
 
 
 
(777
)
 
 
 
 
 
(6
)
 
(783
)
Other comprehensive loss
 
 
 
 
 
 
(90
)
 
 
 
 
 
(90
)
Activity related to stock plans
2

 
54

 
 
 
 
 
(8
)
 
 
 
48

Stock-based compensation
 
 
63

 
 
 
 
 
 
 
 
 
63

Cash dividends ($0.34 per share)
 
 
 
 
(148
)
 
 
 
 
 
 
 
(148
)
Net activity related to noncontrolling interests
 
 
(24
)
 
 
 
 
 
 
 
1

 
(23
)
Balance at June 30, 2015
$
436

 
$
7,155

 
$
10,953

 
$
(839
)
 
$
(8
)
 
$
100

 
$
17,797

See accompanying Notes to Unaudited Consolidated Condensed Financial Statements.

5


Baker Hughes Incorporated
Consolidated Condensed Statements of Cash Flows
(Unaudited)

 
Six Months Ended June 30,
(In millions)
2016
 
2015
Cash flows from operating activities:
 
 
 
Net loss
$
(1,893
)
 
$
(783
)
Adjustments to reconcile net loss to net cash flows from operating activities:
 
 
 
Depreciation and amortization
659

 
894

Impairment of assets
1,055

 
265

Goodwill impairment
1,841

 

Inventory write-down
587

 
194

Loss on early extinguishment of debt
142

 

Provision (benefit) for deferred income taxes
238

 
(366
)
Provision for doubtful accounts
215

 
116

Other noncash items
(23
)
 
(10
)
Changes in operating assets and liabilities:
 
 
 
Accounts receivable
742

 
1,590

Inventories
347

 
313

Accounts payable
(385
)
 
(1,000
)
Other operating items, net
(47
)
 
(376
)
Net cash flows provided by operating activities
3,478

 
837

Cash flows from investing activities:
 
 
 
Expenditures for capital assets
(156
)
 
(573
)
Proceeds from disposal of assets
139

 
171

Proceeds from maturities of investment securities
204

 

Purchases of investment securities
(276
)
 

Other investing items, net

 
(11
)
Net cash flows used in investing activities
(89
)
 
(413
)
Cash flows from financing activities:
 
 
 
Net repayments of short-term debt and other borrowings
(36
)
 
(64
)
Repayment of long-term debt
(1,135
)
 

Repurchase of common stock
(500
)
 

Dividends paid
(148
)
 
(148
)
Other financing items, net
14

 
25

Net cash flows used in financing activities
(1,805
)
 
(187
)
Effect of foreign exchange rate changes on cash and cash equivalents
2

 
(4
)
Increase in cash and cash equivalents
1,586

 
233

Cash and cash equivalents, beginning of period
2,324

 
1,740

Cash and cash equivalents, end of period
$
3,910

 
$
1,973

Supplemental cash flows disclosures:
 
 
 
Income taxes paid, net of refunds
$
213

 
$
306

Interest paid
$
129

 
$
122

Supplemental disclosure of noncash investing activities:
 
 
 
Capital expenditures included in accounts payable
$
22

 
$
100

See accompanying Notes to Unaudited Consolidated Condensed Financial Statements.

6


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Nature of Operations
Baker Hughes Incorporated ("Baker Hughes," "Company," "we," "our," or "us,") is a leading supplier of oilfield services, products, technology and systems used for drilling, formation evaluation, completion and production, pressure pumping, and reservoir development in the worldwide oil and natural gas industry. We also provide products and services for other businesses including downstream chemicals, and process and pipeline services.
Basis of Presentation
Our unaudited consolidated condensed financial statements included herein have been prepared in accordance with generally accepted accounting principles ("GAAP") in the United States of America ("U.S.") and pursuant to the rules and regulations of the Securities and Exchange Commission ("SEC") for interim financial information. Accordingly, certain information and disclosures normally included in our annual financial statements have been condensed or omitted. These unaudited consolidated condensed financial statements should be read in conjunction with our audited consolidated financial statements included in our Annual Report on Form 10-K/A for the year ended December 31, 2015. We believe the unaudited consolidated condensed financial statements included herein reflect all adjustments (consisting of normal recurring adjustments) necessary for a fair presentation of the interim periods. The results of operations for the interim periods are not necessarily indicative of the results of operations to be expected for the full year. In the Notes to Unaudited Consolidated Condensed Financial Statements, all dollar and share amounts in tabulations are in millions of dollars and shares, respectively, unless otherwise indicated.
Beginning in 2016, all merger and related costs are presented as a separate line item in the consolidated condensed statement of income (loss). Prior year merger and related costs were reclassified to conform to the current year presentation.
New Accounting Standards Adopted
In July 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2015-11, Simplifying the Measurement of Inventory, which requires inventory measured using average cost methods, which we utilize, to be subsequently measured at the lower of cost or net realizable value. Net realizable value is the estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation. We adopted this guidance as of January 1, 2016 because we believe this approach will reduce the complexity in the subsequent measurement of our inventory. The guidance stipulates that the amendments in ASU No. 2015-11 shall be adopted on a prospective basis, therefore our adoption had no impact on prior reporting periods.
New Accounting Standards To Be Adopted
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, and is to be applied retrospectively. Early adoption is permitted. We have not completed an evaluation of the impact the pronouncement will have on our consolidated financial statements and related disclosures.
In November 2015, the FASB issued 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 noncurrent on the balance sheet. The pronouncement is effective for annual reporting periods beginning after December 15, 2016, and may be applied either prospectively or retrospectively. We have not completed an

7


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

evaluation of the impact the pronouncement will have on our consolidated financial statements and related disclosures.
In February 2016, the FASB issued ASU No. 2016-02, Leases, a new standard on accounting for leases. The ASU introduces a lessee model that brings most leases on the balance sheet. The new standard also aligns many of the underlying principles of the new lessor model with those in the current accounting guidance as well as the FASB's new revenue recognition standard. However, the ASU eliminates the use of bright-line tests in determining lease classification as required in the current guidance. The ASU also requires additional qualitative disclosures along with specific quantitative disclosures to better enable users of financial statements to assess the amount, timing, and uncertainty of cash flows arising from leases. The pronouncement is effective for annual reporting periods beginning after December 15, 2018, including interim periods within that reporting period, using a modified retrospective approach. Early adoption is permitted. We have not completed an evaluation of the impact the pronouncement will have on our consolidated financial statements and related disclosures.
In March 2016, the FASB issued ASU No. 2016-09, Improvements to Employee Share-Based Payment Accounting. The standard provides a new requirement to record all of the tax effects related to share-based payments at settlement (or expiration) through the income statement. This pronouncement is effective for annual reporting periods beginning after December 15, 2016. We have not completed an evaluation of the impact the pronouncement will have on our consolidated financial statements and related disclosures.

NOTE 2. HALLIBURTON MERGER AGREEMENT
On November 16, 2014, Baker Hughes, Halliburton Company ("Halliburton") and a wholly owned subsidiary of Halliburton ("Merger Sub"), entered into an Agreement and Plan of Merger (the "Merger Agreement"), under which Halliburton would acquire all of the outstanding shares of Baker Hughes through a merger of Baker Hughes with and into Merger Sub (the "Merger").
In accordance with the provisions of Section 9.1 of the Merger Agreement, Baker Hughes and Halliburton agreed to terminate the Merger Agreement on April 30, 2016, as a result of the failure of the Merger to occur on or before April 30, 2016 due to the inability to obtain certain specified antitrust related approvals. Halliburton paid $3.5 billion to Baker Hughes on May 4, 2016, representing the termination fee required to be paid pursuant to the Merger Agreement.
Baker Hughes incurred costs related to the Merger of $78 million and $83 million for the three months ended June 30, 2016 and 2015, respectively, and $180 million and $111 million for the six months ended June 30, 2016 and 2015, respectively, including costs under our retention programs and obligations for minimum incentive compensation costs which, based on meeting eligibility criteria, have been treated as merger and related expenses.

NOTE 3. IMPAIRMENT AND RESTRUCTURING CHARGES
IMPAIRMENT CHARGES
We conduct impairment tests on long-lived assets whenever events or changes in circumstances indicate that the carrying value may not be recoverable based on estimated future cash flows. Although oil prices have risen since the lows reached in February 2016 and rig counts have begun to stabilize, customer spending and activity continues at low levels, thus continuing lower demand for our products and services. We consider our customers' constrained capital spending budgets for 2016 and the current outlook for low activity levels to be impairment indicators and accordingly continue to evaluate our long-lived assets for impairment.
As a result of our impairment testing in the second quarter of 2016, certain machinery and equipment, with a total carrying value of $754 million, was written down to its estimated fair value, resulting in an impairment charge of $240 million. These assets remain in use. Additionally, certain intangible assets, with a total carrying value of $174 million, were written down to their estimated fair values, resulting in an impairment charge of $89 million. Total impairment charges for the three and six months ended June 30, 2016 were $329 million and $447 million, respectively. The majority of the impaired machinery and equipment and intangible assets related to our pressure pumping business in North America, Middle East and Asia Pacific. The estimated fair values for these assets were

8


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

determined using discounted future cash flows. The significant Level 3 unobservable inputs used in the determination of the fair value of these assets were the estimated future cash flows and the weighted average cost of capital of 10.0% for North America, 14.0% for Middle East and 13.5% for Asia Pacific.
RESTRUCTURING CHARGES
We recognize restructuring charges for costs associated with workforce reductions, contract terminations, facility closures and impairments related to the permanent removal from service and disposal of excess machinery and equipment. As a result of the downturn in the industry in 2015 and its impact on our business outlook, we took actions to restructure and adjust our operations and cost structure to reflect current and expected activity levels to the extent allowable under the Merger Agreement with Halliburton. Following the termination of the Merger Agreement in the second quarter of 2016, to address ongoing industry challenges, we took additional actions to reduce costs, simplify our organization, refine and rationalize our operating strategy and adjust our capacity to meet expected levels of future demand. These actions necessitated workforce reductions, contract terminations, facility closures and the permanent removal from service and disposal of excess machinery and equipment. Depending on future market conditions and activity levels, further actions may be necessary to adjust our operations, which may result in additional charges.
During the three and six months ended June 30, 2016 and 2015, we recorded restructuring charges as summarized below:
 
Three Months Ended
 
Six Months Ended
Restructuring Charges
June 30, 2016
June 30, 2015
 
June 30, 2016
June 30, 2015
  Workforce reductions
$
98

$
61

 
$
145

$
308

  Contract terminations
91

(3
)
 
91

83

  Impairment of buildings and improvements
110

5

 
105

82

  Impairment of machinery and equipment
498

13

 
498

176

Total restructuring charges
$
797

$
76

 
$
839

$
649


Workforce reduction costs: During the second quarter of 2016, we initiated workforce reductions that will result in the elimination of approximately 3,000 additional positions worldwide and recorded a charge for severance expense of $98 million. As of June 30, 2016, we had $66 million of accrued severance. We expect that substantially all of the accrued severance will be paid by the end of 2016.
Contract termination costs: During the second quarter of 2016, we canceled a supply contract and certain equipment leases and recorded a charge of $91 million. During the same period, we made payments totaling $54 million relating to contract termination costs. As of June 30, 2016, we had accrued contract termination costs of $47 million.
Impairment of buildings and improvements: During the second quarter of 2016, we consolidated and closed certain facilities and recorded related impairment charges of $110 million in North America. These facilities have been taken out of service and will be disposed.
Impairment of machinery and equipment: During the second quarter of 2016, we evaluated our capacity and made adjustments to align our capacity to expected future operational levels and strategy. These actions impacted all product lines and as a result, we recognized an impairment loss of $498 million relating to the cost to impair excess machinery and equipment to its net realizable value. The total machinery and equipment impairments reduced our segment assets as follows: North America - $203 million; Latin America - $97 million; Europe/Africa/Russia Caspian - $84 million; Middle East/Asia Pacific - $76 million; and Industrial Services - $38 million. We are disposing of all excess machinery and equipment and expect to be substantially complete by the end of the third quarter of 2016.

9


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

OTHER CHARGES
During the second quarter of 2016, in connection with the evaluation of our current inventory levels and expected future demand and to align with our future strategy, we recorded charges of $621 million, including $34 million of disposal costs, of which $205 million is reported in cost of sales and $416 million is reported in cost of services, to write off the carrying value of inventory deemed excess. These actions impacted all product lines. The amount of the inventory write-off recorded by segment is as follows: North America - $209 million; Latin America - $88 million; Europe/Africa/Russia Caspian - $152 million; Middle East/Asia Pacific - $125 million; and Industrial Services - $47 million. We are disposing of the excess inventory, and we expect to be substantially complete by the end of the third quarter of 2016. During the first six months of 2015, we recorded charges of $194 million, of which $37 million is reported in cost of sales and $157 million is reported in cost of services, to write down the carrying value of certain inventory. The product lines impacted were primarily pressure pumping and drilling and completion fluids.
The second quarter of 2016 was benefited by a reversal of a loss on a firm purchase commitment of $51 million that was recorded in cost of service in the first quarter of 2016 as the contract was settled in the second quarter of 2016.

NOTE 4. SEGMENT INFORMATION
We are a supplier of oilfield services, products, technology and systems used in the worldwide oil and natural gas business, referred to as oilfield operations, which are managed through operating segments that are aligned with our geographic regions. We also provide services and products to the downstream chemicals, and process and pipeline services, referred to as Industrial Services.
The performance of our operating segments is evaluated based on operating profit (loss) before tax, which is defined as income (loss) before income taxes and before the following: net interest expense, corporate expenses and certain gains and losses, including impairment and restructuring charges, goodwill impairment charges and the merger termination fee, not allocated to the operating segments.
Beginning in 2016, we excluded merger and related costs from our operating segments. These costs are now presented as a separate line item in the consolidated condensed statement of income (loss). Prior year merger and related costs have been reclassified to conform to the current year presentation.

10


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

Summarized financial information is shown in the following tables:
 
Three Months Ended
 
Three Months Ended
 
June 30, 2016
 
June 30, 2015
Segments
Revenue
 
Operating Profit (Loss) Before Tax
 
Revenue
 
Operating Profit (Loss) Before Tax
North America
$
668

 
$
(311
)
 
$
1,498

 
$
(150
)
Latin America
235

 
(243
)
 
439

 
45

Europe/Africa/Russia Caspian
581

 
(257
)
 
869

 
57

Middle East/Asia Pacific
651

 
(142
)
 
856

 
60

Industrial Services
273

 
(43
)
 
306

 
32

Total Operations
2,408

 
(996
)
 
3,968

 
44

Corporate

 
(29
)
 

 
(42
)
Loss on early extinguishment of debt

 
(142
)
 

 

Interest expense, net

 
(48
)
 

 
(53
)
Impairment and restructuring charges

 
(1,126
)
 

 
(76
)
Goodwill impairment

 
(1,841
)
 

 

Merger and related costs

 
(78
)
 

 
(83
)
Merger termination fee

 
3,500

 

 

Litigation settlements

 

 

 
13

Total
$
2,408

 
$
(760
)
 
$
3,968

 
$
(197
)

 
Six Months Ended
 
Six Months Ended
 
June 30, 2016
 
June 30, 2015
Segments
Revenue
 
Operating Profit (Loss) Before Tax
 
Revenue
 
Operating Profit (Loss) Before Tax
North America
$
1,487

 
$
(536
)
 
$
3,504

 
$
(359
)
Latin America
512

 
(309
)
 
932

 
78

Europe/Africa/Russia Caspian
1,192

 
(276
)
 
1,764

 
37

Middle East/Asia Pacific
1,369

 
(93
)
 
1,772

 
122

Industrial Services
518

 
(47
)
 
590

 
42

Total Operations
5,078

 
(1,261
)
 
8,562

 
(80
)
Corporate

 
(61
)
 

 
(91
)
Loss on early extinguishment of debt

 
(142
)
 

 

Interest expense, net

 
(103
)
 

 
(107
)
Impairment and restructuring charges

 
(1,286
)
 

 
(649
)
Goodwill impairment

 
(1,841
)
 

 

Merger and related costs

 
(180
)
 

 
(111
)
Merger termination fee

 
3,500

 

 

Litigation settlements

 

 

 
13

Total
$
5,078

 
$
(1,374
)
 
$
8,562

 
$
(1,025
)


11


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

The following table presents total assets by segment at June 30, 2016 and December 31, 2015:
 
June 30, 2016
 
December 31, 2015
Segments
Assets
 
Assets
North America
$
3,745

 
$
6,599

Latin America
1,690

 
2,323

Europe/Africa/Russia Caspian
2,589

 
3,077

Middle East/Asia Pacific
2,870

 
3,441

Industrial Services
683

 
1,106

Shared assets
5,332

 
5,613

Total Operations
16,909

 
22,159

Corporate
3,410

 
1,921

Total
$
20,319


$
24,080

Shared assets consist primarily of the assets carried at the enterprise level and include our supply chain, product line technology and information technology organizations. These assets are used to support our operating segments and consist primarily of manufacturing inventory, property, plant and equipment used in manufacturing and information technology, intangible assets related to technology, and certain deferred tax assets. All costs and expenses from these organizations, including depreciation and amortization, are allocated to our operating segments as these enterprise organizations support our global operations. Corporate assets include cash, certain facilities, and certain other noncurrent assets.

NOTE 5. INCOME TAXES
For the three months ended June 30, 2016, total income tax expense was $152 million on a loss before income taxes of $760 million, resulting in a negative effective tax rate of 20.0%. The negative effective tax rate is driven primarily by the $1.84 billion goodwill impairment with a tax benefit of $76 million due to a significant portion of the goodwill having no tax basis. Also, the impairment and restructuring charges totaling $1.13 billion along with $621 million of charges to write off and dispose of certain excess inventory resulted in $290 million of tax benefit due primarily to valuation allowances provided in certain jurisdictions. These negative rate drivers were partially offset by the reversal of approximately $460 million of valuation allowances for certain tax credit carryforwards that will be utilized as a result of receiving the $3.5 billion termination fee which represents U.S. taxable income.
As a consequence of receiving the $3.5 billion termination fee, we no longer expect to have a U.S. net operating loss ("NOL") in 2016. However, we still intend to carryback the 2015 NOL to prior tax years. As a result, a $409 million current income tax receivable is reflected on the balance sheet as of June 30, 2016.


12


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

NOTE 6. EARNINGS PER SHARE
A reconciliation of the number of shares used for the basic and diluted loss per share computations is as follows:
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
2016
 
2015
 
2016
 
2015
Weighted average common shares outstanding for basic and diluted loss per share
438

 
438

 
440

 
438

 
 
 
 
 
 
 
 
Anti-dilutive shares excluded from diluted loss per share (1)
1

 
2

 
1

 
2

Future potentially dilutive shares excluded from diluted loss per share (2)
6

 
2

 
7

 
2


(1) 
The calculation of diluted loss per share for both the three and six months ended June 30, 2016 excludes shares potentially issuable under stock-based incentive compensation plans and the employee stock purchase plan, as their effect, if included, would have been anti-dilutive.
(2) 
Options where the exercise price exceeds the average market price are excluded from the calculation of diluted net loss or earnings per share because their effect would be anti-dilutive.

NOTE 7. INVENTORIES

Inventories, net of reserves of $78 million at June 30, 2016 and $278 million at December 31, 2015, are comprised of the following:
 
June 30,
2016
 
December 31,
2015
Finished goods
$
1,749

 
$
2,649

Work in process
121

 
132

Raw materials
122

 
136

Total inventories
$
1,992

 
$
2,917


In the first six months of 2016, we wrote off the carrying value of certain excess inventory resulting in a charge of $587 million, net of existing reserves of $262 million. In addition, we accrued $34 million of related disposal costs. See Note 3. "Impairment and Restructuring Charges" for further discussion. We are disposing of the excess inventory, and we expect to be substantially complete by the end of the third quarter of 2016.


13


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements


NOTE 8. PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment are comprised of the following at June 30, 2016 and December 31, 2015:

 
Useful Life
 
June 30, 2016
 
December 31, 2015
Land
 
 
$
246

 
$
263

Buildings and improvements
5 - 30 years
 
2,514

 
2,624

Machinery, equipment and other
1 - 20 years
 
9,738

 
11,184

Subtotal
 
 
12,498

 
14,071

Less: Accumulated depreciation
 
 
7,269

 
7,378

Total property, plant and equipment
 
 
$
5,229

 
$
6,693


During the first six months of 2016, we recorded impairment charges relating to property, plant and equipment totaling approximately $949 million. See Note 3. "Impairment and Restructuring Charges" for further discussion.

NOTE 9. GOODWILL AND INTANGIBLE ASSETS
The changes in the carrying amount of goodwill are detailed below by segment.

 
North
America
 
Latin
America
 
Europe/
Africa/
Russia
Caspian
 
Middle
East/
Asia
Pacific
 
Industrial
Services
 
Total Goodwill
Balance at December 31, 2015
$
3,097

 
$
584

 
$
1,068

 
$
819

 
$
502

 
$
6,070

Impairments
(1,530
)
 

 

 

 
(311
)
 
(1,841
)
Currency translation adjustments
2

 
3

 
(1
)
 

 

 
4

Balance at June 30, 2016
$
1,569

 
$
587

 
$
1,067

 
$
819

 
$
191

 
$
4,233

Goodwill is tested annually for impairment as of October 1 of each year or sooner when circumstances indicate an impairment may exist at the reporting unit level. During the second quarter of 2016, as a result of the termination of the Merger Agreement with Halliburton, we concluded it was necessary to conduct a goodwill impairment review. Our reporting units are the same as our five reportable segments. Goodwill is tested for impairment using a two-step approach. In the first step, the fair value of each reporting unit is determined and compared to the reporting unit's carrying value, including goodwill. If the fair value of a reporting unit is less than its carrying value, the second step of the goodwill impairment test is performed to measure the amount of impairment, if any. In the second step, the fair value of the reporting unit is allocated to the assets and liabilities of the reporting unit as if it had been acquired in a business combination and the purchase price was equivalent to the fair value of the reporting unit. The excess of the fair value of the reporting unit over the amounts assigned to its assets and liabilities is referred to as the implied fair value of goodwill. The implied fair value of the reporting unit's goodwill is then compared to the actual carrying value of goodwill. If the implied fair value of goodwill is less than the carrying value of goodwill, an impairment loss is recognized for the difference.

We determined the fair value of our reporting units using a combination of techniques including discounted cash flows derived from our long-term plans and a market approach that provides value indications through a comparison with guideline public companies. The inputs used to determine the fair values were classified as Level 3 in the fair value hierarchy. Based on the results of our impairment test, we determined that goodwill of two of our reporting units was impaired and recorded an estimate of the goodwill impairment loss of $1.84 billion, which consisted of $1.53 billion for the North America segment and $311 million for the Industrial Services segment. While we have substantially completed all actions necessary in the determination of the implied fair value of goodwill, some of the estimated fair values and allocations are subject to adjustment once the valuations and other computations are

14


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

completed. We will finalize these items and record any required adjustments as we obtain the information necessary to complete the analysis, which we expect to occur in the third quarter of 2016. The volatility that currently exists in the oil and natural gas industry and further declines in future commodity prices and customer spending could negatively impact our forecasted profitability and operating cash flows, necessitating a future goodwill impairment review. Depending on the changes in our business outlook and other assumptions underlying the fair value measurements of our reporting units, we may be required to recognize additional goodwill impairments.

Intangible assets are comprised of the following:
 
June 30, 2016
 
December 31, 2015
 
Gross
Carrying
Amount
 
Less:
Accumulated
Amortization
 
Net
 
Gross
Carrying
Amount
 
Less:
Accumulated
Amortization
 
Net
Technology
$
793

 
$
426

 
$
367

 
$
866

 
$
452

 
$
414

Customer relationships
94

 
38

 
56

 
251

 
106

 
145

Trade names
96

 
83

 
13

 
108

 
89

 
19

Other
16

 
13

 
3

 
18

 
13

 
5

Total intangible assets
$
999

 
$
560

 
$
439

 
$
1,243

 
$
660

 
$
583


During the first six months of 2016, we recorded impairments relating to various intangible assets totaling $101 million. See Note 3. "Impairment and Restructuring Charges" for further discussion.
Intangible assets are generally amortized on a straight-line basis with estimated useful lives ranging from 3 to 30 years. Amortization expense for the three and six months ended June 30, 2016 was $20 million and $42 million, respectively, as compared to $25 million and $51 million reported in 2015 for the same periods.

Amortization expense of these intangibles over the remainder of 2016 and for each of the subsequent five fiscal years is expected to be as follows:
Year
Estimated Amortization Expense
Remainder of 2016
$
34

2017
67

2018
62

2019
59

2020
50

2021
44



15


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

NOTE 10. INDEBTEDNESS
Total debt consisted of the following at June 30, 2016, net of unamortized discount and debt issuance cost:

 
June 30, 2016
 
December 31, 2015
6.0% Notes due June 2018
$
200

 
$
255

7.5% Senior Notes due November 2018
524

 
747

3.2% Senior Notes due August 2021
511

 
746

8.55% Debentures due June 2024
112

 
149

6.875% Notes due January 2029
302

 
394

5.125% Notes due September 2040
1,132

 
1,482

Other debt
245

 
268

Total debt
3,026

 
4,041

Less: short-term debt and current portion of long-term debt
139

 
151

Total long-term debt
$
2,887

 
$
3,890

The estimated fair value of total debt at June 30, 2016 and December 31, 2015 was $3,431 million and $4,321 million, respectively, which differs from the carrying amounts of $3,026 million and $4,041 million, respectively, included in our unaudited consolidated condensed balance sheets. The fair value was determined using quoted period end market prices.
In June 2016, we purchased $1.0 billion of the aggregate outstanding principal amount associated with our long-term outstanding notes and debentures, which included portions of each tranche of notes and debentures. Pursuant to a cash tender offer, the purchases resulted in the payment of an early-tender premium, including various fees, of $135 million and a pre-tax loss on the early extinguishment of debt of $142 million, which includes the premium and the write-off of a portion of the remaining original debt issue costs and debt discounts or premiums.
At June 30, 2016, we had a committed revolving credit facility ("credit facility") with commercial banks and a related commercial paper program under which the maximum combined borrowing at any time under both the credit facility and the commercial paper program was $2.5 billion. The credit facility had a maturity date in September 2016. There were no direct borrowings under the credit facility during the first six months of 2016, and we were in compliance with all of the credit facility's covenants. Under the commercial paper program, we may issue from time to time up to $2.5 billion in commercial paper with maturities of no more than 270 days. The amount available to borrow under the credit facility would be reduced by the amount of any commercial paper outstanding. At June 30, 2016, we had no borrowings outstanding under the commercial paper program.
On July 13, 2016, we entered into a new five-year $2.5 billion committed revolving credit facility (the "2016 Credit Agreement") with commercial banks maturing in July 2021, which replaced our existing credit facility of $2.5 billion, but maintained the existing commercial paper program. The 2016 Credit Agreement contains certain covenants, which, among other things, require the maintenance of a total debt-to-total capitalization ratio, restrict certain merger transactions or the sale of all or substantially all of our assets or a significant subsidiary and limit the amount of subsidiary indebtedness. Upon the occurrence of certain events of default, our obligations under the 2016 Credit Agreement may be accelerated. Such events of default include payment defaults to lenders under the 2016 Credit Agreement, covenant defaults and other customary defaults. To the extent we have outstanding commercial paper, the aggregate ability to borrow under the 2016 Credit Agreement is reduced.

NOTE 11. FINANCIAL INSTRUMENTS
Our financial instruments include cash and cash equivalents, accounts receivable, investments, accounts payable, short and long-term debt and derivative financial instruments. Except for long-term debt, the estimated fair value of our financial instruments at June 30, 2016 and December 31, 2015 approximates their carrying value as

16


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

reflected in our unaudited consolidated condensed balance sheets. For further information on the fair value of our debt, see Note 10. "Indebtedness."

NOTE 12. EMPLOYEE BENEFIT PLANS
We have both funded and unfunded noncontributory defined benefit pension plans ("Pension Benefits") covering certain employees primarily in the U.S., the United Kingdom, Germany and Canada. We also provide certain postretirement health care benefits ("Other Postretirement Benefits"), through an unfunded plan, to a closed group of U.S. employees who, when they retire, have met certain age and service requirements.
The components of net periodic cost (benefit) are as follows for the three months ended June 30:
 
U.S. Pension Benefits
 
Non-U.S. Pension Benefits
 
Other Postretirement Benefits
 
2016
 
2015
 
2016
 
2015
 
2016
 
2015
Service cost
$
13

 
$
16

 
$
3

 
$
4

 
$
1

 
$
1

Interest cost
7

 
7

 
7

 
8

 
1

 
1

Expected return on plan assets
(10
)
 
(12
)
 
(9
)
 
(12
)
 

 

Amortization of prior service credit

 

 

 

 
(2
)
 
(3
)
Amortization of net actuarial loss
2

 
2

 
2

 
1

 

 
1

Net periodic cost (benefit)
$
12

 
$
13

 
$
3

 
$
1

 
$

 
$

The components of net periodic cost (benefit) are as follows for the six months ended June 30:
 
U.S. Pension Benefits
 
Non-U.S. Pension Benefits
 
Other Postretirement Benefits
 
2016
 
2015
 
2016
 
2015
 
2016
 
2015
Service cost
$
26

 
$
34

 
$
7

 
$
8

 
$
2

 
$
2

Interest cost
14

 
14

 
14

 
16

 
2

 
2

Expected return on plan assets
(20
)
 
(25
)
 
(18
)
 
(24
)
 

 

Amortization of prior service credit

 

 

 

 
(4
)
 
(6
)
Amortization of net actuarial loss
5

 
4

 
3

 
2

 

 
2

Curtailment gain

 

 

 

 

 
(9
)
Net periodic cost (benefit)
$
25

 
$
27

 
$
6

 
$
2

 
$

 
$
(9
)
For all pension plans, we make annual contributions to the plans in amounts equal to or greater than amounts necessary to meet minimum governmental funding requirements. During the six months ended June 30, 2016, we contributed approximately $24 million to our defined benefit and other postretirement plans. We expect to contribute between $38 million and $42 million to our funded and unfunded pension plans and to make payments of between $7 million and $8 million related to other postretirement benefits for the remainder of 2016.
We contributed approximately $65 million to our defined contribution plans during the six months ended June 30, 2016. Effective April 2016, employer contributions to certain plans were suspended indefinitely. We estimate we will contribute between $23 million and $25 million to other defined contribution plans for the remainder of 2016.

NOTE 13. COMMITMENTS AND CONTINGENCIES
LITIGATION
We are subject to a number of lawsuits and claims arising out of the conduct of our business. The ability to predict the ultimate outcome of such matters involves judgments, estimates and inherent uncertainties. We record a liability for those contingencies where the incurrence of a loss is probable and the amount can be reasonably estimated, including accruals for self-insured losses which are calculated based on historical claim data, specific

17


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

loss development factors and other information. A range of total possible losses for all litigation matters cannot be reasonably estimated. Based on a consideration of all relevant facts and circumstances, we do not expect the ultimate outcome of any currently pending lawsuits or claims against us will have a material adverse effect on our financial position, results of operations or cash flows; however, there can be no assurance as to the ultimate outcome of these matters.
We insure against risks arising from our business to the extent deemed prudent by our management and to the extent insurance is available, but no assurance can be given that the nature and amount of that insurance will be sufficient to fully indemnify us against liabilities arising out of pending or future legal proceedings or other claims. Most of our insurance policies contain deductibles or self-insured retentions in amounts we deem prudent and for which we are responsible for payment. In determining the amount of self-insurance, it is our policy to self-insure those losses that are predictable, measurable and recurring in nature, such as claims for automobile liability, general liability and workers compensation.
The following lawsuits were filed in Delaware in connection with our Merger with Halliburton. Subsequent to the filing of the lawsuits, on April 30, 2016, the Merger Agreement with Halliburton was terminated as described in Note 2. "Halliburton Merger Agreement."
On November 24, 2014, Gary Molenda, a purported shareholder of the Company, filed a class action lawsuit in the Court of Chancery of the State of Delaware ("Delaware Chancery Court") against Baker Hughes, the Company’s Board of Directors, Halliburton, and Red Tiger LLC, a wholly owned subsidiary of Halliburton ("Red Tiger" and together with all defendants, "Defendants") styled Gary R. Molenda v. Baker Hughes, Inc., et al., Case No. 10390-CB.
On November 26, 2014, a second purported shareholder of the Company, Booth Family Trust, filed a substantially similar class action lawsuit in Delaware Chancery Court.
On December 1, 2014, New Jersey Building Laborers Annuity Fund and James Rice, two additional purported shareholders of the Company, filed substantially similar class action lawsuits in Delaware Chancery Court.
On December 10, 2014, a fifth purported shareholder of the Company, Iron Workers Mid-South Pension Fund, filed another substantially similar class action lawsuit in the Delaware Chancery Court.
On December 24, 2014, a sixth purported shareholder of the Company, Annette Shipp, filed another substantially similar class action lawsuit in the Delaware Chancery Court.
All of the lawsuits make substantially similar claims.  The plaintiffs generally allege that the members of the Company’s Board of Directors breached their fiduciary duties to our shareholders in connection with the Merger negotiations by entering into the Merger Agreement and by approving the Merger, and that the Company, Halliburton, and Red Tiger aided and abetted the purported breaches of fiduciary duties.  More specifically, the lawsuits allege that the Merger Agreement provides inadequate consideration to our shareholders, that the process resulting in the Merger Agreement was flawed, that the Company’s directors engaged in self-dealing, and that certain provisions of the Merger Agreement improperly favor Halliburton and Red Tiger, precluding or impeding third parties from submitting potentially superior proposals, among other things.  The lawsuit filed by Annette Shipp also alleges that our Board of Directors failed to disclose material information concerning the proposed Merger in the preliminary registration statement on Form S-4.  On January 7, 2015, James Rice amended his complaint, adding similar allegations regarding the disclosures in the preliminary registration statement on Form S-4.  The lawsuits seek unspecified damages, injunctive relief enjoining the Merger, and rescission of the Merger Agreement, among other relief.  On January 23, 2015, the Delaware lawsuits were consolidated under the caption In re Baker Hughes Inc. Stockholders Litigation, Consolidated C.A. No. 10390-CB (the "Consolidated Case"). Pursuant to the Court’s consolidation order, plaintiffs filed a consolidated complaint on February 4, 2015, which alleges substantially similar claims and seeks substantially similar relief to that raised in the six individual complaints, except that while Baker Hughes is named as a defendant, no claims are asserted against the Company.
On March 18, 2015, the parties reached an agreement in principle to settle the Consolidated Case in exchange for the Company making certain additional disclosures. Those disclosures were contained in a Form 8-K filed with the SEC on March 18, 2015. The settlement was made subject to certain conditions, including consummation of the Merger, final documentation, and court approval. With the termination of the Merger Agreement with Halliburton, the March 18, 2015 settlement agreement is rendered null and void. On May 31, 2016, the Consolidated Case and

18


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

the claims asserted therein were dismissed, save and except for plaintiffs counsel's Fee and Expense Application to the Delaware Chancery Court.
On October 9, 2014, our subsidiary filed a Request for Arbitration against a customer before the London Court of International Arbitration, pursuing claims for the non-payment of invoices for goods and services provided in an amount provisionally quantified to exceed $67.9 million. In our Request for Arbitration, we also noted that invoices in an amount exceeding $57 million had been issued to the customer, and would be added to the claim in the event that they became overdue. On November 6, 2014, the customer filed its Response and Counterclaim, denying liability and counterclaiming damages for breach of contract of approximately $182 million. On March 31, 2016, the parties agreed to a settlement principally involving the purchase by the customer of certain inventory held by our subsidiary, with all other claims and counterclaims being released and discharged by each party, and the arbitral proceedings being discontinued. On April 18, 2016, all claims and counterclaims filed in the London Court of International Arbitration were released and discontinued. The settlement did not have a material impact on our financial position, results of operations or cash flows.
During 2014, we received customer notifications related to a possible equipment failure in a natural gas storage system in Northern Germany, which includes certain of our products. We are currently investigating the cause of the possible failure and, if necessary, possible repair and replacement options for our products. Similar products were utilized in other natural gas storage systems for this and other customers. The customer initiated arbitral proceedings against us on June 19, 2015, under the rules of the German Institute of Arbitration e.V. (DIS). The customer alleges damages of approximately $170 million plus interest at an annual rate of prime + 5%. The hearing before the arbitration panel is scheduled to commence on January 16, 2017. In addition, on September 21, 2015, TRIUVA Kapitalverwaltungsgesellschaft mbH filed a lawsuit in the United States District Court for the Southern District of Texas, Houston Division against the Company and Baker Hughes Oilfield Operations, Inc. alleging that the plaintiff is the owner of gas storage caverns in Etzel, Germany in which the Company provided certain equipment in connection with the development of the gas storage caverns. The plaintiff further alleges that the Company supplied equipment that was either defectively designed or failed to warn of risks that the equipment posed, and that these alleged defects caused damage to the plaintiff’s property. The plaintiff seeks recovery of alleged compensatory and punitive damages of an unspecified amount, in addition to reasonable attorneys’ fees, court costs and pre-judgment and post-judgment interest. The allegations in this lawsuit are related to the claims made in the June 19, 2015 German arbitration referenced above. At this time, we are not able to predict the outcome of these claims or whether either will have any material impact on our financial position, results of operations or cash flows.
On August 31, 2015, a customer of one of the Company’s subsidiaries issued a Letter of Claim pursuant to a Construction and Engineering Contract. The customer has claimed $369 million plus loss of production resulting from a breach of contract related to five electric submersible pumps installed by the subsidiary in Europe. On January 29, 2016, the Customer served its Statement of Claim, Case No. CL-2015-00584, in the Commercial Court Queen's Bench Division of the High Court of Justice. Investigation is ongoing as to the merits of the claim. At this time, we are not able to predict the outcome of this claim or whether it will have a material impact on our financial position, results of operations or cash flows.
On October 30, 2015, Chieftain Sand and Proppant Barron, LLC initiated arbitration against our subsidiary, Baker Hughes Oilfield Operations, Inc., in the American Arbitration Association. The Claimant alleged that the Company failed to purchase the required sand tonnage for the contract year 2014-2015 and further alleged that the Company repudiated its yearly purchase obligations over the remaining contract term. The Claimant alleged damages of approximately $110 million plus interest, attorneys’ fees and costs. On June 2, 2016, the parties agreed to a settlement of all claims and counterclaims asserted in the Arbitration. The settlement did not have a material impact on our financial position, results of operations or cash flows.
On April 30, 2015, a class and collective action lawsuit alleging that we failed to pay a nationwide class of workers overtime in compliance with the Fair Labor Standards Act and North Dakota law was filed titled Williams et al. v. Baker Hughes Oilfield Operations, Inc. in the U.S. District Court for the District of North Dakota.  On February 8, 2016, the Court conditionally certified certain subclasses of employees for collective action treatment. We are evaluating the background facts and at this time cannot predict the outcome of this lawsuit and are not able to

19


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

reasonably estimate the potential impact, if any, such outcome would have on our financial position, results of operations or cash flows.
On July 31, 2015, Rapid Completions LLC filed a lawsuit in federal court in the Eastern District of Texas against Baker Hughes Incorporated, Baker Hughes Oilfield Operations, Inc., and others claiming infringement of U.S. Patent Nos. 6,907,936; 7,134,505; 7,543,634; 7,861,774; and 8,657,009.  On August 6, 2015, Rapid Completions amended its complaint to allege infringement of U.S. Patent No. 9,074,451.  On September 17, 2015, Rapid Completions and Packers Plus Energy Services Inc., sued Baker Hughes Canada Company in the Canada Federal Court on related Canadian patent 2,412,072. On April 1, 2016, Rapid Completions removed U.S. Patent No. 6,907,936 from its claims in the lawsuit. On April 5, 2016, Rapid Completions filed a second lawsuit in federal court in the Eastern District of Texas against Baker Hughes Incorporated, Baker Hughes Oilfield Operations, Inc. and others claiming infringement of U.S. Patent No. 9,303,501. These patents relate primarily to certain specific downhole completions equipment. The plaintiff has requested a permanent injunction against further alleged infringement, damages in an unspecified amount, supplemental and enhanced damages, and additional relief such as attorney’s fees and costs.  At this time, we are not able to predict the outcome of these claims or whether they will have a material impact on our financial position, results of operations or cash flows.
On April 6, 2016, a civil Complaint against Baker Hughes Incorporated and Halliburton Company was filed by the United States of America seeking a permanent injunction restraining Baker Hughes and Halliburton from carrying out the planned acquisition of Baker Hughes by Halliburton or any other transaction that would combine the two companies. The lawsuit is styled United States of America v. Halliburton Co. and Baker Hughes Inc., in the U.S. District Court for the District of Delaware, Case No. 1:16-cv-00233-UNA. The Complaint alleges that the proposed transaction between Halliburton and Baker Hughes would violate Section 7 of the Clayton Act. Subsequent to the filing of the Complaint, on April 30, 2016, the Merger Agreement with Halliburton was terminated as described in Note 2. "Halliburton Merger Agreement." On May 4, 2016, the United States filed a Notice of Voluntary Dismissal of the Complaint.
On May 30, 2013, we received a Civil Investigative Demand ("CID") from the U.S. Department of Justice ("DOJ") pursuant to the Antitrust Civil Process Act. The CID sought documents and information from us for the period from May 29, 2011 through the date of the CID in connection with a DOJ investigation related to pressure pumping services in the U.S. On May 18, 2016, we received notice from the DOJ that they have closed the investigation with no further action requested of the Company.
OTHER
In the normal course of business with customers, vendors and others, we have entered into off-balance sheet arrangements, such as surety bonds for performance, letters of credit and other bank issued guarantees, which totaled approximately $1.1 billion at June 30, 2016. It is not practicable to estimate the fair value of these financial instruments. None of the off-balance sheet arrangements either has, or is likely to have, a material effect on our financial position, results of operations or cash flows.


20


Baker Hughes Incorporated
Notes to Unaudited Consolidated Condensed Financial Statements

NOTE 14. ACCUMULATED OTHER COMPREHENSIVE LOSS

The following tables present the changes in accumulated other comprehensive loss, net of tax:
 
Pensions and Other Postretirement Benefits
Foreign Currency Translation Adjustments
Accumulated Other Comprehensive Loss
Balance at December 31, 2015
 
$
(261
)
 
 
$
(744
)
 
 
$
(1,005
)
 
Other comprehensive income before reclassifications
 
11

 
 
40

 
 
51

 
Amounts reclassified from accumulated other comprehensive loss
 
4

 
 

 
 
4

 
Deferred taxes
 
(1
)
 
 

 
 
(1
)
 
Balance at June 30, 2016
 
$
(247
)
 
 
$
(704
)
 
 
$
(951
)
 

 
Pensions and Other Postretirement Benefits
Foreign Currency Translation Adjustments
Accumulated Other Comprehensive Loss
Balance at December 31, 2014
 
$
(246
)
 
 
$
(503
)
 
 
$
(749
)
 
Other comprehensive income (loss) before reclassifications
 
5

 
 
(91
)
 
 
(86
)
 
Amounts reclassified from accumulated other comprehensive loss
 
(7
)
 
 

 
 
(7
)
 
Deferred taxes
 
3

 
 

 
 
3

 
Balance at June 30, 2015
 
$
(245
)
 
 
$
(594
)
 
 
$
(839
)
 

The amounts reclassified from accumulated other comprehensive loss during the six months ended June 30, 2016 and 2015 represent the amortization of prior service credit, net actuarial loss, curtailment gain and certain other items which are included in the computation of net periodic cost (benefit). See Note 12. "Employee Benefit Plans" for additional details. Net periodic cost (benefit) is recorded in cost of sales and services, research and engineering, and marketing, general and administrative expenses.


21


ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Management’s Discussion and Analysis of Financial Condition and Results of Operations ("MD&A") should be read in conjunction with the unaudited consolidated condensed financial statements and the related notes included in Item 1 thereto, as well as our Annual Report on Form 10-K/A for the year ended December 31, 2015 ("2015 Annual Report").
EXECUTIVE SUMMARY
Baker Hughes is a leading supplier of oilfield services, products, technology and systems used in the worldwide oil and natural gas industry, referred to as our oilfield operations. We manage our oilfield operations through four geographic segments consisting of North America, Latin America, Europe/Africa/Russia Caspian ("EARC"), and Middle East/Asia Pacific ("MEAP"). Our Industrial Services businesses are reported in a fifth segment. As of June 30, 2016, Baker Hughes had approximately 36,000 employees compared to approximately 43,000 employees as of December 31, 2015.
Within our oilfield operations, the primary driver of our businesses is our customers’ capital and operating expenditures dedicated to oil and natural gas exploration, field development and production. The main products and services provided by oilfield operations fall into one of two categories, Drilling and Evaluation or Completion and Production. This classification is based on the two major phases of constructing an oil and/or natural gas well, the drilling phase and the completion phase, and how our products and services are utilized in each phase. We also provide products and services to the downstream chemicals, and process and pipeline services, referred to as Industrial Services.
In the first half of 2016, we continued to face difficult industry conditions as activity continued to decline across the globe as reflected by the worldwide rig count which has declined 29% since December of 2015, causing additional pricing deterioration in many markets. Although oil prices have increased 30% in the first half of the year, driven primarily by temporary supply outages in Nigeria and Canada, a steady decline in U.S. oil production and improving economic data indicating an increase in oil demand growth, customer spending continued to decline as most operators are looking for a sustainable rebalancing of the oil market before increasing activity. As a result, we experienced a significant decline in demand and increased pricing pressure for our products and services throughout the second quarter of 2016.
During the second quarter, following the termination of the merger with Halliburton, we announced a series of actions to reduce costs and simplify our business, enhance our commercial strategy, and optimize our capital structure by paying down debt and buying back shares. More specifically, we have restructured the company to remove significant costs and create a more efficient organization which aligns with our strategy to take our products and technology to market faster and more efficiently through our full-service model and a broader set of sales channels. In an effort to improve our return on invested capital, we have conducted an analysis of our product offerings and as a result of that review, we have begun the process of reducing certain product offerings in specific markets based on our objectives of profitable growth and return on invested capital. While these potential reductions will have a minimal impact on our current revenue, they are expected to have a positive impact on operating profitability. Additionally, we have decided to retain a selective footprint in our U.S. onshore pressure pumping business centered in two basins. However, we continue to retain the operating structure for North America pressure pumping, while we determine the best approach to maximize the value of our assets.
Financial Results
For the second quarter of 2016, we generated revenue of $2.41 billion, a decrease of $1.56 billion, or 39%, compared to the second quarter of 2015, consistent with the 35% drop in the worldwide rig count. In the first six months of 2016, revenue totaled $5.08 billion, a decline of $3.48 billion, or 41%, compared to the same period in the prior year, with a 39% drop in the worldwide rig count over the same time frame. All geographic segments experienced revenue declines in the second quarter and first six months of 2016 due primarily to the downturn in the oil and natural gas market. North America, driven by the drop in the onshore rig count, was the largest contributor to the year-over-year revenue decline. As a result, we continued to experience reduced activity, an

22


oversupply of equipment and an unfavorable pricing environment. Additionally, the decision to continue limiting our exposure to the unprofitable onshore pressure pumping business in North America has resulted in share reductions in this segment. Revenue was also negatively impacted by an unfavorable change in exchange rates of several currencies relative to the U.S. Dollar, predominately in the EARC segment.
Net loss attributable to Baker Hughes was $911 million and $1.89 billion for the second quarter and first six months of 2016, respectively, compared to $188 million and $777 million for the second quarter and first six months of 2015, respectively. Loss before income tax was $760 million and $1.37 billion for the second quarter and first six months of 2016, respectively, compared to $197 million and $1.03 billion for the second quarter and first six months of 2015, respectively.
Throughout this downturn, we have taken actions to reduce costs and adjust our operational cost structure, within the limitations of the Merger Agreement, to reflect current and expected near-term activity levels. Following the termination of the Merger Agreement in the second quarter of 2016, we took additional actions to reduce costs, simplify the organization, and rationalize our operating structure to address the ongoing industry challenges and to support our future operational strategy. These restructuring activities included workforce reductions, contract terminations, facility closures and the removal of excess machinery and equipment, which resulted in asset impairments. In the second quarter of 2016, we recorded charges totaling $1.13 billion, primarily related to impairment charges of $937 million to adjust the carrying amount of certain assets. For the first six months of 2016, total restructuring charges were $1.29 billion. In the second quarter of 2015, we recorded restructuring charges of $76 million related primarily to workforce reductions. For the first six months of 2015, total restructuring charges were $649 million. These restructuring impairment charges have been excluded from the results of our operating segments. Additionally, we incurred costs of $621 million, including $34 million of related disposal costs, in the second quarter of 2016 to write off the carrying value of inventory deemed excess, compared to $171 million and $23 million incurred in the first and second quarters of 2015, respectively. The second quarter of 2016 was benefited by a reversal of a loss on a firm purchase commitment of $51 million that was recorded in cost of service in the first quarter of 2016 as the contract was settled in the second quarter of 2016. The inventory adjustments and loss, and its reversal, on firm purchase commitment are included in the results of our operating segments.
Also, in the second quarter of 2016, we recorded a loss on the impairment of goodwill for the North America and Industrial Services segments totaling $1.84 billion. This charge is excluded from the results of our operating segments.
Halliburton Merger Agreement
On November 16, 2014, Baker Hughes and Halliburton Company ("Halliburton") entered into a definitive agreement and plan of merger (the "Merger Agreement") under which Halliburton would acquire all outstanding shares of Baker Hughes in a stock and cash transaction (the "Merger"). In accordance with the provisions of Section 9.1 of the Merger Agreement, Baker Hughes and Halliburton agreed to terminate the Merger Agreement on April 30, 2016, as a result of the failure of the Merger to occur on or before April 30, 2016 due to the inability to obtain certain specified antitrust related approvals. Halliburton paid $3.5 billion to Baker Hughes on May 4, 2016, representing the antitrust termination fee required to be paid pursuant to the Merger Agreement.
Outlook
While we have seen U.S. production edge down, most of the decline has been offset by additional production from Iran. Additionally, oil demand growth remains tapered with increased uncertainty stemming from the Brexit vote, which has led to a stronger U.S. Dollar. Although oil prices have rebounded more than 30% this year, we believe there has not been an economic catalyst that would create a step-change to supply and demand that could lead to a more sustainable improvement in oil prices, and in turn to a more material increase in exploration and production companies' spending.
As such, in North America, we expect near-term activity to modestly increase driven by seasonality in Canada and a measured activity uptick in the U.S. onshore. While the increase in U.S. oilfield activity is expected to be more heavily driven by drilled-but-uncompleted well completions, the volume and pace will likely vary widely based on the well economics for each customer. Internationally, activity is expected to continue to decline in most

23


countries, with a steeper decline in markets with higher lifting costs, such as deepwater. On the other hand, conventional markets with lower lifting costs, such as those in the Middle East and Russia Caspian, could see modest growth. As a consequence, we expect pricing for our products and services to remain challenging. Despite these market dynamics, we continue to see opportunities for our capabilities and product innovations. Our products and services put us in a position to help our customer maximize production and lower overall costs while continuing to leverage opportunities to convert our capabilities into earnings.

BUSINESS ENVIRONMENT
We operate in more than 80 countries helping customers find, evaluate, drill, produce, transport and process hydrocarbon resources. Our revenue is predominately generated from the sale of products and services to major, national, and independent oil and natural gas companies worldwide, and is dependent on spending by our customers for oil and natural gas exploration, field development and production. This spending is dependent on a number of factors, including our customers’ forecasts of future energy demand and supply, their access to resources to develop and produce oil and natural gas, their ability to fund their capital programs, the impact of new government regulations and most importantly, their expectations for oil and natural gas prices as a key driver of their cash flows.
Oil and Natural Gas Prices
Oil and natural gas prices are summarized in the table below as averages of the daily closing prices during each of the periods indicated.
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
2016
 
2015
 
2016
 
2015
Brent oil price ($/Bbl) (1)
$
46.01

 
$
62.06

 
$
40.26

 
$
58.04

WTI oil price ($/Bbl) (2)
45.53

 
57.85

 
39.62

 
53.25

Natural gas price ($/mmBtu) (3)
2.14

 
2.73

 
2.05

 
2.80


(1) 
Bloomberg Dated Brent ("Brent") Oil Spot Price per Barrel
(2) 
Bloomberg West Texas Intermediate ("WTI") Cushing Crude Oil Spot Price per Barrel
(3)Bloomberg Henry Hub Natural Gas Spot Price per million British Thermal Unit
In North America, customer spending is highly driven by WTI oil prices, which increased during the second quarter of 2016 as a result of three main drivers. First, increasing global oil supply outages primarily in Canada and Nigeria. Canada's wildfires at their peak removed up to 1.5 mb/d of production capacity; in Nigeria, militant activity forced production down reaching thirty-year lows during the quarter. Even though these supply outages were temporary, combined with other rising supply concerns, such as Venezuela where oil producers and refiners are struggling to keep output up due to power outages and equipment shortages, the supply outages have taken pressure off storage capacity in the near-term. Second, the steady decline of U.S. oil production and third, improving economic data and other indications that global oil demand growth is accelerating. The International Energy Agency published firm data for the first quarter of 2016 showing a year-over-year growth of 1.6 mb/d versus an initial expectation of 1.2 mb/d. However, this year's strong start for oil demand growth might not be maintained as Britain's vote in late June to leave the European Union has raised concerns that Brexit could slow the global economy with the British Pound falling to a 31-year low and corresponding strength in the U.S. Dollar.
Outside North America, customer spending is most heavily influenced by Brent oil prices, which, similar to WTI oil prices, increased throughout the quarter, exiting the quarter at $48.42/Bbl. Brent oil price fluctuations were driven by the same factors as WTI.
Overall, WTI and Brent oil prices in the first half of 2016 averaged lower than the prior year by 26% and 31%, respectively. Although oil prices have rebounded more than 80% from the previous twelve-year-low of $26/Bbl reached earlier this year to $48/Bbl at the end of the quarter, there has yet to be any material change in customer behavior to suggest a near-term improvement in activity levels.

24


In North America, natural gas prices, as measured by the Henry Hub Natural Gas Spot Price, steadily increased during the quarter as a result of seasonally warmer weather, exiting the quarter at $2.90/mmBtu, a 90% increase from the 20-year lows reached in the prior quarter. Compared to the prior year, natural gas prices have decreased 22% as a result of a warmer-than-normal 2015-2016 winter, record inventory levels, and production growth. For the first half of 2016, natural gas prices averaged $2.05/mmBtu and decreased 27% compared to the first half of 2015. According to the U.S. Department of Energy ("DOE"), working natural gas in storage at the end of the second quarter of 2016 was 3,140 Bcf, which is 25% higher than the previous five-year (2011-2015) average, and 22%, or 563 Bcf, above the corresponding week in 2015.

Baker Hughes Rig Count
The Baker Hughes rig counts are an important business barometer for the drilling industry and its suppliers. When drilling rigs are active they consume products and services produced by the oil service industry. Rig count trends are governed by the exploration and development spending by oil and natural gas companies, which in turn is influenced by current and future price expectations for oil and natural gas. Therefore, the counts may reflect the relative strength and stability of energy prices and overall market activity. However, these counts should not be solely relied on as other specific and pervasive conditions may exist that affect overall energy prices and market activity.
Baker Hughes has been providing rig counts to the public since 1944. We gather all relevant data through our field service personnel, who obtain the necessary data from routine visits to the various rigs, customers, contractors and/or other outside sources. We base the classification of a well as either oil or natural gas primarily upon filings made by operators in the relevant jurisdiction. This data is then compiled and distributed to various wire services and trade associations and is published on our website. We believe the counting process and resulting data is reliable; however, it is subject to our ability to obtain accurate and timely information. Rig counts are compiled weekly for the U.S. and Canada and monthly for all international rigs. Published international rig counts do not include rigs drilling in certain locations, such as Russia, the Caspian region, Iran and onshore China because this information is not readily available.
Rigs in the U.S. and Canada are counted as active if, on the day the count is taken, the well being drilled has been started but drilling has not been completed and the well is anticipated to be of sufficient depth to be a potential consumer of our drill bits. In international areas, rigs are counted on a weekly basis and deemed active if drilling activities occurred during the majority of the week. The weekly results are then averaged for the month and published accordingly. The rig count does not include rigs that are in transit from one location to another, rigging up, being used in non-drilling activities including production testing, completion and workover, and are not expected to be significant consumers of drill bits.
The rig counts are summarized in the table below as averages for each of the periods indicated.
 
Three Months Ended June 30,
 
Six Months Ended June 30,
 
 
2016
2015
% Change
2016
2015
% Change
U.S. - land and inland waters
398

876

(55
%)
467

1,115

(58
%)
U.S. - offshore
24

31

(23
%)
25

40

(38
%)
Canada
48

98

(51
%)
107

206

(48
%)
North America
470

1,005

(53
%)
599

1,361

(56
%)
Latin America
190

322

(41
%)
211

337

(37
%)
North Sea
29

38

(24
%)
30

41

(27
%)
Continental Europe
63

78

(19
%)
68

83

(18
%)
Africa
89

108

(18
%)
90

119

(24
%)
Middle East
388

403

(4
%)
395

408

(3
%)
Asia Pacific
184

220

(16
%)
185

228

(19
%)
Outside North America
943

1,169

(19
%)
979

1,216

(19
%)
Worldwide
1,413

2,174

(35
%)
1,578

2,577

(39
%)

25


The rig count in North America decreased 53% in the second quarter of 2016 compared to the same period a year ago, as a consequence of reduced spending from our customers as they adapt to a lower commodity price environment. Reduced cash flows in 2015 and 2016 has prompted many companies to scale back investment programs, deferring new drilling projects until a sustained price recovery occurs. Also, the prospect of higher interest rates and tighter lending conditions will likely limit the availability of capital for many smaller producers, giving rise to distressed asset sales and consolidation of acreage holdings by firms that are more financially sound. The oil-directed drilling rig count experienced a 51% decline in rig counts as the steep drop in oil prices over the last year resulted in a reduction in exploration and production spending across the region, especially in the U.S. onshore and Canadian oil sands. The natural gas-directed rig count experienced a 58% decrease compared to the same period a year ago as a result of lower natural gas prices. In the U.S., natural gas prices remain below levels that are considered to be economic for new investments in many natural gas fields. In Canada, the reduction in the natural gas-directed rig count was primarily related to lower drilling activity levels in condensate rich zones in Alberta to service oil sands.
Outside North America, the rig count in the second quarter of 2016 decreased 19% compared to the same period a year ago. In Latin America, the rig count declined 41% as a consequence of customer spending reductions throughout the entire region, but most notably in Mexico, Argentina, Brazil, Colombia, and Ecuador. In Europe, the rig count in the North Sea decreased 24%, primarily due to a reduction in offshore drilling activity in the UK, and in Continental Europe the rig count declined by 19% driven by lower onshore drilling activity primarily in Romania and Poland. In Africa, the rig count decreased 18% primarily due to reduced drilling activity across the region, mainly in Nigeria, Gabon, Angola, and Chad. The rig count decreased 4% in the Middle East due to lower drilling activity in Egypt onshore, Iraq, and Kuwait partially offset by increased drilling activity in Abu Dhabi and Pakistan. In Asia Pacific, the rig count declined 16% as a result of reduced drilling activity in Australia, Indonesia, India, and Thailand.
RESULTS OF OPERATIONS
The discussions below relating to significant line items from our unaudited consolidated condensed statements of income (loss) are based on available information and represent our analysis of significant changes or events that impact the comparability of reported amounts. Where appropriate, we have identified specific events and changes that affect comparability or trends and, where reasonably practicable, have quantified the impact of such items. In addition, the discussions below for revenue and cost of revenue are on a total basis as the business drivers for product sales and services are similar. All dollar amounts in tabulations in this section are in millions of dollars, unless otherwise stated.
Revenue and Operating Profit (Loss) Before Tax
Revenue and operating profit (loss) before tax for each of our five operating segments is provided below. The performance of our operating segments is evaluated based on operating profit (loss) before tax, which is defined as income (loss) before income taxes and before the following: net interest expense, corporate expenses and certain gains and losses, including impairment and restructuring charges, goodwill impairment charges and the merger termination fee, not allocated to the operating segments. Beginning in 2016, we excluded merger and related costs from our operating segments. These costs are now presented as a separate line item in the consolidated condensed statement of income (loss). Prior year merger and related costs have been reclassified to conform to the current year presentation.
 
Three Months Ended June 30,
 
$
Change
 
%
Change
 
Six Months Ended June 30,
 
$
Change
 
%
Change
 
2016
 
2015
 
 
2016
 
2015
 
Revenue:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
North America
$
668

 
$
1,498

 
$
(830
)
 
(55
%)
 
$
1,487

 
$
3,504

 
$
(2,017
)
 
(58
%)
Latin America
235

 
439

 
(204
)
 
(46
%)
 
512

 
932

 
(420
)
 
(45
%)
Europe/Africa/Russia Caspian
581

 
869

 
(288
)
 
(33
%)
 
1,192

 
1,764

 
(572
)
 
(32
%)
Middle East/Asia Pacific
651

 
856

 
(205
)
 
(24
%)
 
1,369

 
1,772

 
(403
)
 
(23
%)
Industrial Services
273

 
306

 
(33
)
 
(11
%)
 
518

 
590

 
(72
)
 
(12
%)
Total
$
2,408

 
$
3,968

 
$
(1,560
)
 
(39
%)
 
$
5,078

 
$
8,562

 
$
(3,484
)
 
(41
%)

26



 
Three Months Ended June 30,
 
$
Change
 
%
Change
 
Six Months Ended June 30,
 
$
Change
 
%
Change
 
2016
 
2015
 
 
2016
 
2015
 
Operating Profit (Loss) Before Tax:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
North America
$
(311
)
 
$
(150
)
 
$
(161
)
 
(107
%)
 
$
(536
)
 
$
(359
)
 
$
(177
)
 
(49
%)
Latin America
(243
)
 
45

 
(288
)
 
(640
%)
 
(309
)
 
78

 
(387
)
 
(496
%)
Europe/Africa/Russia Caspian
(257
)
 
57

 
(314
)
 
(551
%)
 
(276
)
 
37

 
(313
)
 
(846
%)
Middle East/Asia Pacific
(142
)
 
60

 
(202
)
 
(337
%)
 
(93
)
 
122

 
(215
)
 
(176
%)
Industrial Services
(43
)
 
32

 
(75
)
 
(234
%)
 
(47
)
 
42

 
(89
)
 
(212
%)
Total Operations
(996
)
 
44

 
(1,040
)
 
N/M

 
(1,261
)
 
(80
)
 
(1,181
)
 
N/M

Corporate
(29
)
 
(42
)
 
13

 
(31
%)
 
(61
)
 
(91
)
 
30

 
(33
%)
Loss on early extinguishment of debt
(142
)
 

 
(142
)
 
N/M

 
(142
)
 

 
(142
)
 
N/M

Interest expense, net
(48
)
 
(53
)
 
5

 
(9
%)
 
(103
)
 
(107
)
 
4

 
(4
%)
Impairment and restructuring charges
(1,126
)
 
(76
)
 
(1,050
)
 
N/M

 
(1,286
)
 
(649
)
 
(637
)
 
98
%
Goodwill impairment
(1,841
)
 

 
(1,841
)
 
N/M

 
(1,841
)
 

 
(1,841
)
 
N/M

Merger and related costs
(78
)
 
(83
)
 
5

 
(6
%)
 
(180
)
 
(111
)
 
(69
)
 
62
%
Merger termination fee
3,500

 

 
3,500

 
N/M

 
3,500

 

 
3,500

 
N/M

Litigation settlements

 
13

 
(13
)
 
(100
%)
 

 
13

 
(13
)
 
(100
%)
Loss Before Income Taxes
$
(760
)
 
$
(197
)
 
$
(563
)
 
(286
%)
 
$
(1,374
)
 
$
(1,025
)
 
$
(349
)
 
(34
%)
"N/M" represents not meaningful.
Second Quarter of 2016 Compared to the Second Quarter of 2015
North America
North America revenue decreased $830 million, or 55%, in the second quarter of 2016 compared to the second quarter of 2015 primarily as a result of the steep drop in activity, as reflected in the 53% year-over-year rig count decline, and deteriorating pricing conditions as operators further adjusted their spending levels in 2016. All product lines have been unfavorably impacted by the activity drop, with production chemicals, deepwater operations, and artificial lift showing the most resilience. Revenue has also been impacted by onshore pressure pumping share reductions, driven by efforts to reduce losses and improve cash flow in a market where pricing remains unsustainable.
North America operating loss before tax was $311 million in the second quarter of 2016 compared to $150 million in the second quarter of 2015. Operating results were negatively impacted by the sharp reduction in activity and an increasingly unfavorable pricing environment. Actions taken to reduce our workforce, close and consolidate facilities and improve commercial terms with vendors resulted in lower operating costs. These actions to restructure our North American operations to operate in a lower activity environment, combined with the reduction of depreciation and amortization from asset impairments, helped mitigate the impact of the precipitous decline in revenue. Our operating results for the second quarter of 2016 include $209 million of costs related to writing down certain excess inventory, compared to $23 million in the second quarter of 2015. Also, our current quarter results include a $51 million benefit from a reversal of a loss on a firm purchase commitment recognized in the first quarter of 2016 as the contract was settled in the current quarter.

27