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EOG RESOURCES INC - Quarter Report: 2019 June (Form 10-Q)

 

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
 
FORM
10-Q
 
 
(Mark One)

           QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2019
or
          TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Commission File Number: 1-9743
 
EOG RESOURCES, INC.
(Exact name of registrant as specified in its charter)
Delaware
 
47-0684736
(State or other jurisdiction
 of incorporation or organization)
 
(I.R.S. Employer
Identification No.)
1111 Bagby, Sky Lobby 2, Houston, Texas 77002
(Address of principal executive offices)       (Zip Code)
 
713-651-7000
(Registrant's telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Trading symbol(s)
Name of each exchange on which registered
Common Stock, par value $0.01 per share
EOG
New York Stock Exchange

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   No 

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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   No 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.  See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.
Large accelerated filer     Accelerated filer     Non-accelerated filer 
Smaller reporting company    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.

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

Indicate the number of shares outstanding of each of the registrant's classes of common stock, as of the latest practicable date.
Title of each class
 
Number of shares
Common Stock, par value $0.01 per share
 
580,663,061

(as of July 26, 2019)

 

    



EOG RESOURCES, INC.

TABLE OF CONTENTS



PART I.
FINANCIAL INFORMATION
Page No.
 
 
 
 
ITEM 1.
Financial Statements (Unaudited)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
ITEM 2.
 
 
 
 
 
ITEM 3.
 
 
 
 
 
ITEM 4.
 
 
 
 
PART II.
OTHER INFORMATION
 
 
 
 
 
 
ITEM 1.
 
 
 
 
 
ITEM 2.
 
 
 
 
 
ITEM 4.
 
 
 
 
 
ITEM 6.
 
 
 
 
 
 
 
 
 

-2-

    



PART I.  FINANCIAL INFORMATION
ITEM 1.  FINANCIAL STATEMENTS
EOG RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
(In Thousands, Except Per Share Data)
(Unaudited)
 
Three Months Ended 
 June 30,
 
Six Months Ended 
 June 30,
 
2019
 
2018
 
2019
 
2018
Operating Revenues and Other
 
 
 
 
 
 
 
Crude Oil and Condensate
$
2,528,866

 
$
2,377,528

 
$
4,729,269

 
$
4,478,836

Natural Gas Liquids
186,374

 
286,354

 
405,012

 
507,769

Natural Gas
269,892

 
300,845

 
604,864

 
600,611

Gains (Losses) on Mark-to-Market Commodity Derivative Contracts
177,300

 
(185,883
)
 
156,720

 
(245,654
)
Gathering, Processing and Marketing
1,501,386

 
1,436,436

 
2,787,040

 
2,538,258

Gains (Losses) on Asset Dispositions, Net
8,009

 
(6,317
)
 
4,173

 
(21,286
)
Other, Net
25,803

 
29,114

 
69,194

 
60,705

Total
4,697,630

 
4,238,077

 
8,756,272

 
7,919,239

Operating Expenses
 

 
 

 
 

 
 

Lease and Well
347,281

 
314,604

 
683,572

 
614,668

Transportation Costs
174,101

 
177,797

 
350,623

 
354,754

Gathering and Processing Costs
112,643

 
109,169

 
223,938

 
210,514

Exploration Costs
32,522

 
47,478

 
68,846

 
82,314

Dry Hole Costs
3,769

 
4,902

 
3,863

 
4,902

Impairments
112,130

 
51,708

 
184,486

 
116,317

Marketing Costs
1,500,915

 
1,420,463

 
2,770,972

 
2,526,853

Depreciation, Depletion and Amortization
957,304

 
848,674

 
1,836,899

 
1,597,265

General and Administrative
121,780

 
104,083

 
228,452

 
198,781

Taxes Other Than Income
204,414

 
194,268

 
397,320

 
373,352

Total
3,566,859

 
3,273,146

 
6,748,971

 
6,079,720

Operating Income
1,130,771

 
964,931

 
2,007,301

 
1,839,519

Other Income (Expense), Net
8,503

 
(8,551
)
 
14,115

 
(7,824
)
Income Before Interest Expense and Income Taxes
1,139,274

 
956,380

 
2,021,416

 
1,831,695

Interest Expense, Net
49,908

 
63,444

 
104,814

 
125,400

Income Before Income Taxes
1,089,366

 
892,936

 
1,916,602

 
1,706,295

Income Tax Provision
241,525

 
196,205

 
433,335

 
370,975

Net Income
$
847,841

 
$
696,731

 
$
1,483,267

 
$
1,335,320

Net Income Per Share
 

 
 

 
 

 
 

Basic
$
1.47

 
$
1.21

 
$
2.57

 
$
2.32

Diluted
$
1.46

 
$
1.20

 
$
2.56

 
$
2.30

Average Number of Common Shares
 

 
 

 
 

 
 

Basic
577,460

 
576,135

 
577,333

 
575,953

Diluted
580,247

 
580,375

 
580,204

 
580,007

Comprehensive Income
 

 
 

 
 

 
 

Net Income
$
847,841

 
$
696,731

 
$
1,483,267

 
$
1,335,320

Other Comprehensive Income (Loss)
 

 
 

 
 

 
 

Foreign Currency Translation Adjustments
(1,665
)
 
(3,229
)
 
(3,449
)
 
1,773

Other, Net of Tax
6

 
6

 
12

 
12

Other Comprehensive Income (Loss)
(1,659
)
 
(3,223
)
 
(3,437
)
 
1,785

Comprehensive Income
$
846,182

 
$
693,508

 
$
1,479,830

 
$
1,337,105



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

-3-

    



EOG RESOURCES, INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
(In Thousands, Except Share Data)
(Unaudited)
 
June 30,
2019
 
December 31,
2018
ASSETS
Current Assets
 
 
 
Cash and Cash Equivalents
$
1,160,485

 
$
1,555,634

Accounts Receivable, Net
2,001,953

 
1,915,215

Inventories
853,128

 
859,359

Assets from Price Risk Management Activities
134,951

 
23,806

Income Taxes Receivable
121,364

 
427,909

Other
223,640

 
275,467

Total
4,495,521

 
5,057,390

Property, Plant and Equipment
 

 
 

Oil and Gas Properties (Successful Efforts Method)
60,214,151

 
57,330,016

Other Property, Plant and Equipment
4,328,675

 
4,220,665

Total Property, Plant and Equipment
64,542,826

 
61,550,681

Less:  Accumulated Depreciation, Depletion and Amortization
(34,818,395
)
 
(33,475,162
)
Total Property, Plant and Equipment, Net
29,724,431

 
28,075,519

Deferred Income Taxes
1,489

 
777

Other Assets
1,530,060

 
800,788

Total Assets
$
35,751,501

 
$
33,934,474

LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
 

 
 

Accounts Payable
$
2,387,403

 
$
2,239,850

Accrued Taxes Payable
268,837

 
214,726

Dividends Payable
165,999

 
126,971

Current Portion of Long-Term Debt
1,013,876

 
913,093

Current Portion of Operating Lease Liabilities
396,547

 

Other
181,395

 
233,724

Total
4,414,057

 
3,728,364

 
 
 
 
Long-Term Debt
4,165,284

 
5,170,169

Other Liabilities
1,803,475

 
1,258,355

Deferred Income Taxes
4,738,409

 
4,413,398

Commitments and Contingencies (Note 8)


 


 
 
 
 
Stockholders' Equity
 

 
 

Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 580,931,822 Shares Issued at June 30, 2019 and 580,408,117 Shares Issued at December 31, 2018
205,809

 
205,804

Additional Paid in Capital
5,729,318

 
5,658,794

Accumulated Other Comprehensive Loss
(4,528
)
 
(1,358
)
Retained Earnings
14,731,609

 
13,543,130

Common Stock Held in Treasury, 305,941 Shares at June 30, 2019 and 385,042 Shares at December 31, 2018
(31,932
)
 
(42,182
)
Total Stockholders' Equity
20,630,276

 
19,364,188

Total Liabilities and Stockholders' Equity
$
35,751,501

 
$
33,934,474


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

-4-

    



EOG RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
(In Thousands, Except Per Share Data)
(Unaudited)
 
Common
Stock
 
Additional
Paid In
Capital
 
Accumulated
Other
Comprehensive
Income (Loss)
 
Retained
Earnings
 
Common
Stock
Held In
Treasury
 
Total
Stockholders'
Equity
Balance at March 31, 2019
$
205,807

 
$
5,695,197

 
$
(2,869
)
 
$
14,050,676

 
$
(45,014
)
 
$
19,903,797

Net Income

 

 

 
847,841

 

 
847,841

Common Stock Issued Under Stock Plans

 

 

 

 

 

Common Stock Dividends Declared, $0.2875 Per Share

 

 

 
(166,908
)
 

 
(166,908
)
Other Comprehensive Loss

 

 
(1,659
)
 

 

 
(1,659
)
Change in Treasury Stock - Stock Compensation Plans, Net

 
(5,834
)
 

 

 
12,027

 
6,193

Restricted Stock and Restricted Stock Units, Net
2

 
1,788

 

 

 
(1,790
)
 

Stock-Based Compensation Expenses

 
38,566

 

 

 

 
38,566

Treasury Stock Issued as Compensation

 
(399
)
 

 

 
2,845

 
2,446

Balance at June 30, 2019
$
205,809

 
$
5,729,318

 
$
(4,528
)
 
$
14,731,609

 
$
(31,932
)
 
$
20,630,276


 
Common
Stock
 
Additional
Paid In
Capital
 
Accumulated
Other
Comprehensive
Income (Loss)
 
Retained
Earnings
 
Common
Stock
Held In
Treasury
 
Total
Stockholders'
Equity
Balance at March 31, 2018
$
205,793

 
$
5,569,194

 
$
(14,289
)
 
$
11,125,051

 
$
(45,110
)
 
$
16,840,639

Net Income

 

 

 
696,731

 

 
696,731

Common Stock Issued Under Stock Plans
3

 
2,171

 

 

 

 
2,174

Common Stock Dividends Declared, $0.1850 Per Share

 

 

 
(107,126
)
 

 
(107,126
)
Other Comprehensive Loss

 

 
(3,223
)
 

 

 
(3,223
)
Change in Treasury Stock - Stock Compensation Plans, Net

 
(12,446
)
 

 

 
4,717

 
(7,729
)
Restricted Stock and Restricted Stock Units, Net

 
918

 

 

 
(918
)
 

Stock-Based Compensation Expenses

 
31,804

 

 

 

 
31,804

Treasury Stock Issued as Compensation

 
2

 

 

 
(878
)
 
(876
)
Balance at June 30, 2018
$
205,796

 
$
5,591,643

 
$
(17,512
)
 
$
11,714,656

 
$
(42,189
)
 
$
17,452,394


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


-5-

    



EOG RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
(In Thousands, Except Per Share Data)
(Unaudited)
 
Common
Stock
 
Additional
Paid In
Capital
 
Accumulated
Other
Comprehensive
Income (Loss)
 
Retained
Earnings
 
Common
Stock
Held In
Treasury
 
Total
Stockholders'
Equity
Balance at December 31, 2018
$
205,804

 
$
5,658,794

 
$
(1,358
)
 
$
13,543,130

 
$
(42,182
)
 
$
19,364,188

Net Income

 

 

 
1,483,267

 

 
1,483,267

Common Stock Issued Under Stock Plans

 

 

 

 

 

Common Stock Dividends Declared, $0.5075 Per Share

 

 

 
(294,521
)
 

 
(294,521
)
Other Comprehensive Loss

 

 
(3,437
)
 

 

 
(3,437
)
Change in Treasury Stock - Stock Compensation Plans, Net

 
(7,074
)
 

 

 
7,478

 
404

Restricted Stock and Restricted Stock Units, Net
5

 
384

 

 

 
(389
)
 

Stock-Based Compensation Expenses

 
77,653

 

 

 

 
77,653

Treasury Stock Issued as Compensation

 
(439
)
 

 

 
3,161

 
2,722

Cumulative Effect of Adoption of ASU 2018-02, "Income Statement - Reporting Comprehensive Income (Topic 220)"

 

 
267

 
(267
)
 

 

Balance at June 30, 2019
$
205,809

 
$
5,729,318

 
$
(4,528
)
 
$
14,731,609

 
$
(31,932
)
 
$
20,630,276


 
Common
Stock
 
Additional
Paid In
Capital
 
Accumulated
Other
Comprehensive
Income (Loss)
 
Retained
Earnings
 
Common
Stock
Held In
Treasury
 
Total
Stockholders'
Equity
Balance at December 31, 2017
$
205,788

 
$
5,536,547

 
$
(19,297
)
 
$
10,593,533

 
$
(33,298
)
 
$
16,283,273

Net Income

 

 

 
1,335,320

 

 
1,335,320

Common Stock Issued Under Stock Plans
5

 
3,623

 

 

 

 
3,628

Common Stock Dividends Declared, $0.37 Per Share

 

 

 
(214,197
)
 

 
(214,197
)
Other Comprehensive Loss

 

 
1,785

 

 

 
1,785

Change in Treasury Stock - Stock Compensation Plans, Net

 
(20,052
)
 

 

 
(4,452
)
 
(24,504
)
Restricted Stock and Restricted Stock Units, Net
3

 
4,127

 

 

 
(4,130
)
 

Stock-Based Compensation Expenses

 
67,289

 

 

 

 
67,289

Treasury Stock Issued as Compensation

 
109

 

 

 
(309
)
 
(200
)
Balance at June 30, 2018
$
205,796

 
$
5,591,643

 
$
(17,512
)
 
$
11,714,656

 
$
(42,189
)
 
$
17,452,394


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



-6-


EOG RESOURCES, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In Thousands)
(Unaudited)
 
Six Months Ended 
 June 30,
 
2019
 
2018
Cash Flows from Operating Activities
 
 
 
Reconciliation of Net Income to Net Cash Provided by Operating Activities:
 
 
 
Net Income
$
1,483,267

 
$
1,335,320

Items Not Requiring (Providing) Cash
 

 
 

Depreciation, Depletion and Amortization
1,836,899

 
1,597,265

Impairments
184,486

 
116,317

Stock-Based Compensation Expenses
77,653

 
67,289

Deferred Income Taxes
324,294

 
347,586

(Gains) Losses on Asset Dispositions, Net
(4,173
)
 
21,286

Other, Net
5,439

 
13,507

Dry Hole Costs
3,863

 
4,902

Mark-to-Market Commodity Derivative Contracts
 

 
 

Total (Gains) Losses
(156,720
)
 
245,654

Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts
31,290

 
(88,334
)
Other, Net
1,639

 
(261
)
Changes in Components of Working Capital and Other Assets and Liabilities
 

 
 

Accounts Receivable
(69,746
)
 
(309,751
)
Inventories
(11,259
)
 
(192,219
)
Accounts Payable
126,853

 
455,977

Accrued Taxes Payable
53,280

 
22,535

Other Assets
487,387

 
(62,843
)
Other Liabilities
(58,106
)
 
(53,168
)
Changes in Components of Working Capital Associated with Investing and Financing Activities
(22,034
)
 
(27,279
)
Net Cash Provided by Operating Activities
4,294,312

 
3,493,783

Investing Cash Flows
 

 
 

Additions to Oil and Gas Properties
(3,446,497
)
 
(2,980,286
)
Additions to Other Property, Plant and Equipment
(116,881
)
 
(144,858
)
Proceeds from Sales of Assets
17,642

 
8,276

Changes in Components of Working Capital Associated with Investing Activities
22,056

 
27,250

Net Cash Used in Investing Activities
(3,523,680
)
 
(3,089,618
)
Financing Cash Flows
 

 
 

Long-Term Debt Repayments
(900,000
)
 

Dividends Paid
(254,681
)
 
(203,610
)
Treasury Stock Purchased
(8,403
)
 
(32,023
)
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan
8,695

 
11,145

Debt Issuance Costs
(4,902
)
 

Repayment of Finance Lease Liabilities
(6,403
)
 
(3,354
)
Changes in Components of Working Capital Associated with Financing Activities
(22
)
 
29

Net Cash Used in Financing Activities
(1,165,716
)
 
(227,813
)
Effect of Exchange Rate Changes on Cash
(65
)
 
(2,365
)
Increase (Decrease) in Cash and Cash Equivalents
(395,149
)
 
173,987

Cash and Cash Equivalents at Beginning of Period
1,555,634

 
834,228

Cash and Cash Equivalents at End of Period
$
1,160,485

 
$
1,008,215


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

-7-

    



EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)

1.    Summary of Significant Accounting Policies

General. The condensed consolidated financial statements of EOG Resources, Inc., together with its subsidiaries (collectively, EOG), included herein have been prepared by management without audit pursuant to the rules and regulations of the United States Securities and Exchange Commission (SEC). Accordingly, they reflect all normal recurring adjustments which are, in the opinion of management, necessary for a fair presentation of the financial results for the interim periods presented. Certain information and notes normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (U.S. GAAP) have been condensed or omitted pursuant to such rules and regulations. However, management believes that the disclosures included either on the face of the financial statements or in these notes are sufficient to make the interim information presented not misleading. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto included in EOG's Annual Report on Form 10-K for the year ended December 31, 2018, filed on February 26, 2019 (EOG's 2018 Annual Report).

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. The operating results for the three and six months ended June 30, 2019, are not necessarily indicative of the results to be expected for the full year.

Effective January 1, 2019, EOG adopted the provisions of Accounting Standards Update (ASU) 2016-02, "Leases (Topic 842)" (ASU 2016-02). ASU 2016-02 and other related ASUs require that lessees recognize a right-of-use (ROU) asset and related lease liability, representing the obligation to make lease payments for certain lease transactions, on the Condensed Consolidated Balance Sheets and disclose additional leasing information.

EOG elected to adopt ASU 2016-02 and other related ASUs using the modified retrospective approach with a cumulative-effect adjustment to the opening balance of retained earnings as of the effective date. Financial results reported in periods prior to January 1, 2019, are unchanged. Additionally, EOG elected the package of practical expedients within ASU 2016-02 that allows an entity to not reassess prior to the effective date (i) whether any expired or existing contracts are or contain leases, (ii) the lease classification for any expired or existing leases, or (iii) initial direct costs for any existing leases, but did not elect the practical expedient of hindsight when determining the lease term of existing contracts at the effective date. EOG also elected the practical expedient under ASU 2018-01, "Leases (Topic 842) - Land Easement Practical Expedient for Transition to Topic 842," and did not evaluate existing or expired land easements not previously accounted for as leases prior to the January 1, 2019 effective date. There was no impact to retained earnings upon adoption of ASU 2016-02 and other related ASUs. See Note 14.

2.    Stock-Based Compensation

As more fully discussed in Note 7 to the Consolidated Financial Statements included in EOG's 2018 Annual Report, EOG maintains various stock-based compensation plans. Stock-based compensation expense is included on the Condensed Consolidated Statements of Income and Comprehensive Income based upon the job function of the employees receiving the grants as follows (in millions):
 
Three Months Ended 
 June 30,
 
Six Months Ended 
 June 30,
 
2019
 
2018
 
2019
 
2018
Lease and Well
$
13.6

 
$
11.4

 
$
27.3

 
$
24.2

Gathering and Processing Costs
0.3

 
0.1

 
0.5

 
0.2

Exploration Costs
6.5

 
5.7

 
13.0

 
12.6

General and Administrative
18.2

 
14.6

 
36.9

 
30.3

Total
$
38.6

 
$
31.8

 
$
77.7

 
$
67.3



The Amended and Restated EOG Resources, Inc. 2008 Omnibus Equity Compensation Plan (2008 Plan) provides for grants of stock options, stock-settled stock appreciation rights (SARs), restricted stock and restricted stock units, performance units and other stock-based awards.

-8-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)



At June 30, 2019, approximately 13.0 million common shares remained available for grant under the 2008 Plan. EOG's policy is to issue shares related to 2008 Plan grants from previously authorized unissued shares or treasury shares to the extent treasury shares are available.

Stock Options and Stock-Settled Stock Appreciation Rights and Employee Stock Purchase Plan. The fair value of stock option grants and SAR grants is estimated using the Hull-White II binomial option pricing model. The fair value of Employee Stock Purchase Plan (ESPP) grants is estimated using the Black-Scholes-Merton model. Stock-based compensation expense related to stock option, SAR and ESPP grants totaled $13.6 million and $11.7 million during the three months ended June 30, 2019 and 2018, respectively, and $27.5 million and $23.7 million during the six months ended June 30, 2019 and 2018, respectively.

Weighted average fair values and valuation assumptions used to value stock option, SAR and ESPP grants during the six-month periods ended June 30, 2019 and 2018 are as follows:
 
Stock Options/SARs
 
ESPP
 
Six Months Ended 
 June 30,
 
Six Months Ended 
 June 30,
 
2019
 
2018
 
2019
 
2018
Weighted Average Fair Value of Grants
$
25.68

 
$
29.18

 
$
22.98

 
$
23.27

Expected Volatility
31.50
%
 
28.88
%
 
36.31
%
 
22.04
%
Risk-Free Interest Rate
2.38
%
 
2.23
%
 
2.48
%
 
1.60
%
Dividend Yield
0.96
%
 
0.67
%
 
0.83
%
 
0.66
%
Expected Life
5.1 years
 
5.0 years

 
0.5 years

 
0.5 years



Expected volatility is based on an equal weighting of historical volatility and implied volatility from traded options in EOG's common stock. The risk-free interest rate is based upon United States Treasury yields in effect at the time of grant. The expected life is based upon historical experience and contractual terms of stock option, SAR and ESPP grants.

The following table sets forth stock option and SAR transactions for the six-month periods ended June 30, 2019 and 2018 (stock options and SARs in thousands):
 
Six Months Ended 
 June 30, 2019
 
Six Months Ended 
 June 30, 2018
 
Number of
Stock
Options/SARs
 
Weighted
Average
Grant
Price
 
Number of
Stock
Options/SARs
 
Weighted
Average
Grant
Price
Outstanding at January 1
8,310

 
$
96.90

 
9,103

 
$
83.89

Granted
32

 
93.29

 
32

 
110.17

Exercised (1)
(157
)
 
73.39

 
(1,662
)
 
71.33

Forfeited
(107
)
 
105.47

 
(124
)
 
92.07

Outstanding at June 30 (2)
8,078

 
$
97.23

 
7,349

 
$
86.71

Vested or Expected to Vest (3)
7,741

 
$
96.78

 
7,006

 
$
86.44

Exercisable at June 30 (4)
3,905

 
$
86.71

 
2,938

 
$
78.74



(1)
The total intrinsic value of stock options/SARs exercised during the six months ended June 30, 2019 and 2018 was $3.9 million and $74.5 million, respectively. The intrinsic value is based upon the difference between the market price of EOG's common stock on the date of exercise and the grant price of the stock options/SARs.
(2)
The total intrinsic value of stock options/SARs outstanding at June 30, 2019 and 2018 was $45.0 million and $277.2 million, respectively. At June 30, 2019 and 2018, the weighted average remaining contractual life was 4.0 years and 4.3 years, respectively.
(3)
The total intrinsic value of stock options/SARs vested or expected to vest at June 30, 2019 and 2018 was $44.4 million and $266.2 million, respectively. At June 30, 2019 and 2018, the weighted average remaining contractual life was 3.9 years and 4.3 years, respectively.
(4)
The total intrinsic value of stock options/SARs exercisable at June 30, 2019 and 2018 was $37.1 million and $134.2 million, respectively. At June 30, 2019 and 2018, the weighted average remaining contractual life was 2.5 years and 2.7 years, respectively.


-9-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


At June 30, 2019, unrecognized compensation expense related to non-vested stock option, SAR and ESPP grants totaled $81.3 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.6 years.

Restricted Stock and Restricted Stock Units. Employees may be granted restricted (non-vested) stock and/or restricted stock units without cost to them. Stock-based compensation expense related to restricted stock and restricted stock units totaled $23.1 million and $19.0 million for the three months ended June 30, 2019 and 2018, respectively, and $46.4 million and $41.3 million for the six months ended June 30, 2019 and 2018, respectively.

The following table sets forth restricted stock and restricted stock unit transactions for the six-month periods ended June 30, 2019 and 2018 (shares and units in thousands):
 
Six Months Ended 
 June 30, 2019
 
Six Months Ended 
 June 30, 2018
 
Number of
Shares and
Units
 
Weighted
Average
Grant Date
Fair Value
 
Number of
Shares and
Units
 
Weighted
Average
Grant Date
Fair Value
Outstanding at January 1
3,792

 
$
96.64

 
3,905

 
$
88.57

Granted
401

 
96.22

 
309

 
103.52

Released (1)
(395
)
 
93.84

 
(331
)
 
69.55

Forfeited
(68
)
 
98.27

 
(120
)
 
91.28

Outstanding at June 30 (2)
3,730

 
$
96.86

 
3,763

 
$
91.39

 
(1)
The total intrinsic value of restricted stock and restricted stock units released during the six months ended June 30, 2019 and 2018 was $35.7 million and $34.9 million, respectively. The intrinsic value is based upon the closing price of EOG's common stock on the date the restricted stock and restricted stock units are released.
(2)
The total intrinsic value of restricted stock and restricted stock units outstanding at June 30, 2019 and 2018 was $347.5 million and $468.2 million, respectively.

At June 30, 2019, unrecognized compensation expense related to restricted stock and restricted stock units totaled $158.2 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.7 years.

Performance Units. EOG grants performance units annually to its executive officers without cost to them. As more fully discussed in the grant agreements, the performance metric applicable to the performance units is EOG's total shareholder return over a three-year performance period relative to the total shareholder return of a designated group of peer companies (Performance Period). Upon the application of the performance multiple at the completion of the Performance Period, a minimum of 0% and a maximum of 200% of the performance units granted could be outstanding. The fair value of the performance units is estimated using a Monte Carlo simulation. Stock-based compensation expense related to the performance unit grants totaled $1.9 million and $1.1 million for the three months ended June 30, 2019 and 2018, respectively, and $3.8 million and $2.3 million for the six months ended June 30, 2019 and 2018, respectively.


-10-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


The following table sets forth the performance unit transactions for the six-month periods ended June 30, 2019 and 2018 (units in thousands):
 
Six Months Ended 
 June 30, 2019
 
Six Months Ended 
 June 30, 2018
 
Number of
Units
 
Weighted
Average
Price per
Grant Date
 
Number of
Units
 
Weighted
Average
Price per
Grant Date
Outstanding at January 1
539

 
$
101.53

 
502

 
$
90.96

Granted

 

 

 

Granted for Performance Multiple (1)
72

 
69.43

 
72

 
101.87

Released (2)
(83
)
 
85.65

 

 

Forfeited

 

 

 

Outstanding at June 30 (3)
528

(4)
$
99.64

 
574

 
$
92.33

 
(1)
Upon completion of the Performance Period for the performance units granted in 2015 and 2014, a performance multiple of 200% was applied to each of the grants resulting in additional grants of performance units in February 2019 and February 2018, respectively.
(2)
The total intrinsic value of performance units released during the six months ended June 30, 2019, was $7.7 million. The intrinsic value is based upon the closing price of EOG's common stock on the date the performance units are released.
(3)
The total intrinsic value of performance units outstanding at June 30, 2019 and 2018 was approximately $49.2 million and $71.4 million, respectively.
(4)
Upon the application of the relevant performance multiple at the completion of each of the remaining Performance Periods, a minimum of 205 and a maximum of 852 performance units could be outstanding.

At June 30, 2019, unrecognized compensation expense related to performance units totaled $6.0 million. Such unrecognized expense will be amortized on a straight-line basis over a weighted average period of 1.2 years.

3.    Net Income Per Share

The following table sets forth the computation of Net Income Per Share for the three-month and six-month periods ended June 30, 2019 and 2018 (in thousands, except per share data):
 
Three Months Ended 
 June 30,
 
Six Months Ended 
 June 30,
 
2019
 
2018
 
2019
 
2018
Numerator for Basic and Diluted Earnings Per Share -
 
 
 
 
 
 
 
Net Income
$
847,841

 
$
696,731

 
$
1,483,267

 
$
1,335,320

Denominator for Basic Earnings Per Share -
 

 
 

 
 

 
 

Weighted Average Shares
577,460

 
576,135

 
577,333

 
575,953

Potential Dilutive Common Shares -
 

 
 

 
 

 
 

Stock Options/SARs
434

 
1,365

 
452

 
1,237

Restricted Stock/Units and Performance Units
2,353

 
2,875

 
2,419

 
2,817

Denominator for Diluted Earnings Per Share -
 

 
 

 
 

 
 

Adjusted Diluted Weighted Average Shares
580,247

 
580,375

 
580,204

 
580,007

Net Income Per Share
 

 
 

 
 

 
 

Basic
$
1.47

 
$
1.21

 
$
2.57

 
$
2.32

Diluted
$
1.46

 
$
1.20

 
$
2.56

 
$
2.30



The diluted earnings per share calculation excludes stock options and SARs that were anti-dilutive. Shares underlying the excluded stock options and SARs were 6 million and zero shares for the three months ended June 30, 2019 and 2018, respectively, and were 6 million and zero shares for the six months June 30, 2019 and 2018, respectively.


-11-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


4.    Supplemental Cash Flow Information

Net cash paid (received) for interest and income taxes was as follows for the six-month periods ended June 30, 2019 and 2018 (in thousands):
 
Six Months Ended 
 June 30,
 
2019
 
2018
Interest (1)
$
108,994

 
$
133,148

Income Taxes, Net of Refunds Received
$
(331,778
)
 
$
62,777

 
(1)
Net of capitalized interest of $18 million and $11 million for the six months ended June 30, 2019 and 2018, respectively.

EOG's accrued capital expenditures at June 30, 2019 and 2018 were $626 million and $724 million, respectively.

Non-cash investing activities for the six months ended June 30, 2019 and 2018, included additions of $72 million and $83 million, respectively, to EOG's oil and gas properties as a result of property exchanges. Non-cash investing activities for the six months ended June 30, 2018 included additions of $48 million to EOG's other property, plant and equipment primarily in connection with a finance lease transaction in the Permian Basin.

Cash paid for leases for the six months ended June 30, 2019, are disclosed in Note 14.

5.    Segment Information

Selected financial information by reportable segment is presented below for the three-month and six-month periods ended June 30, 2019 and 2018 (in thousands):
 
Three Months Ended 
 June 30,
 
Six Months Ended 
 June 30,
 
2019
 
2018
 
2019
 
2018
Operating Revenues and Other
 
 
 
 
 
 
 
United States
$
4,611,789

 
$
4,114,610

 
$
8,588,808

 
$
7,685,744

Trinidad
71,132

 
81,611

 
141,000

 
162,624

Other International (1)
14,709

 
41,856

 
26,464

 
70,871

Total
$
4,697,630

 
$
4,238,077

 
$
8,756,272

 
$
7,919,239

Operating Income (Loss)
 

 
 

 
 

 
 

United States
$
1,107,910

 
$
946,883

 
$
1,958,810

 
$
1,792,736

Trinidad
34,390

 
27,821

 
73,222

 
68,118

Other International (1)
(11,529
)
 
(9,773
)
 
(24,731
)
 
(21,335
)
Total
1,130,771

 
964,931

 
2,007,301

 
1,839,519

Reconciling Items
 

 
 

 
 

 
 

Other Income (Expense), Net
8,503

 
(8,551
)
 
14,115

 
(7,824
)
Interest Expense, Net
(49,908
)
 
(63,444
)
 
(104,814
)
 
(125,400
)
Income Before Income Taxes
$
1,089,366

 
$
892,936

 
$
1,916,602

 
$
1,706,295

 
(1)
Other International primarily consists of EOG's United Kingdom, China and Canada operations. The United Kingdom operations were sold in the fourth quarter of 2018.


-12-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


Total assets by reportable segment are presented below at June 30, 2019 and December 31, 2018 (in thousands):
 
At
June 30,
2019
 
At
December 31,
2018
Total Assets
 
 
 
United States
$
35,025,034

 
$
33,178,733

Trinidad
586,586

 
629,633

Other International (1)
139,881

 
126,108

Total
$
35,751,501

 
$
33,934,474

 
(1)
Other International primarily consists of EOG's China and Canada operations.

6.    Asset Retirement Obligations

The following table presents the reconciliation of the beginning and ending aggregate carrying amounts of short-term and long-term legal obligations associated with the retirement of property, plant and equipment for the six-month periods ended June 30, 2019 and 2018 (in thousands):
 
Six Months Ended 
 June 30,
 
2019
 
2018
Carrying Amount at January 1
$
954,377

 
$
946,848

Liabilities Incurred
56,490

 
25,496

Liabilities Settled (1)
(41,650
)
 
(8,184
)
Accretion
20,523

 
17,941

Revisions
8,006

 
(148
)
Foreign Currency Translations
219

 
(547
)
Carrying Amount at June 30
$
997,965

 
$
981,406

 
 
 
 
Current Portion
$
27,416

 
$
18,892

Noncurrent Portion
$
970,549

 
$
962,514

 
(1)
Includes settlements related to asset sales.

The current and noncurrent portions of EOG's asset retirement obligations are included in Current Liabilities - Other and Other Liabilities, respectively, on the Condensed Consolidated Balance Sheets.

7.    Exploratory Well Costs

EOG's net changes in capitalized exploratory well costs for the six-month period ended June 30, 2019, are presented below (in thousands):
 
Six Months Ended 
 June 30, 2019
Balance at January 1
$
4,121

Additions Pending the Determination of Proved Reserves
19,664

Reclassifications to Proved Properties
(2,606
)
Costs Charged to Expense
(3,801
)
Balance at June 30
$
17,378




-13-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


At June 30, 2019, all capitalized exploratory well costs had been capitalized for periods of less than one year.

8.    Commitments and Contingencies

There are currently various suits and claims pending against EOG that have arisen in the ordinary course of EOG's business, including contract disputes, personal injury and property damage claims and title disputes. While the ultimate outcome and impact on EOG cannot be predicted, management believes that the resolution of these suits and claims will not, individually or in the aggregate, have a material adverse effect on EOG's consolidated financial position, results of operations or cash flow. EOG records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.

9.    Pension and Postretirement Benefits

EOG has defined contribution pension plans in place for most of its employees in the United States, and a defined benefit pension plan covering certain of its employees in Trinidad. For the six months ended June 30, 2019 and 2018, EOG's total costs recognized for these pension plans were $23.0 million and $20.2 million, respectively. EOG also has postretirement medical and dental plans in place for eligible employees and their dependents in the United States and Trinidad, the costs of which are not material.

10.    Long-Term Debt and Common Stock

Long-Term Debt. EOG had no outstanding commercial paper borrowings or uncommitted credit facility borrowings at June 30, 2019 and December 31, 2018, and did not utilize any such borrowings during the six months ended June 30, 2019. During the six months ended June 30, 2018, EOG utilized commercial paper borrowings, bearing market interest rates, for various corporate financing purposes. The average borrowings outstanding under the commercial paper program was $17 million during the six months ended June 30, 2018. The weighted average interest rate for commercial paper borrowings during the six months ended June 30, 2018, was 1.97%.

On June 3, 2019, EOG repaid upon maturity the $900 million aggregate principal amount of its 5.625% Senior Notes due 2019.

On June 27, 2019, EOG entered into a new $2.0 billion senior unsecured Revolving Credit Agreement (New Facility) with domestic and foreign lenders (Banks). The New Facility replaces EOG’s $2.0 billion senior unsecured Revolving Credit Agreement, dated as of July 21, 2015, with domestic and foreign lenders (2015 Facility), which had a scheduled maturity date of July 21, 2020 and which was terminated by EOG (without penalty), effective as of June 27, 2019, in connection with the completion of the New Facility.

The New Facility has a scheduled maturity date of June 27, 2024, and includes an option for EOG to extend, on up to two occasions, the term for successive one-year periods subject to certain terms and conditions. The New Facility (i) commits the Banks to provide advances up to an aggregate principal amount of $2.0 billion at any one time outstanding, with an option for EOG to request increases in the aggregate commitments to an amount not to exceed $3.0 billion, subject to certain terms and conditions, and (ii) includes a swingline subfacility and a letter of credit subfacility. Advances under the New Facility will accrue interest based, at EOG’s option, on either the London InterBank Offered Rate plus an applicable margin (Eurodollar Rate) or the Base Rate (as defined in the New Facility) plus an applicable margin. The applicable margin used in connection with interest rates and fees will be based on EOG’s credit rating for its senior unsecured long-term debt at the applicable time.

Consistent with the terms of the 2015 Facility, the New Facility contains representations, warranties, covenants and events of default that we believe are customary for investment grade, senior unsecured commercial bank credit agreements, including a financial covenant for the maintenance of a ratio of total debt-to-total capitalization (as such terms are defined in the New Facility) of no greater than 65%. At June 30, 2019, EOG was in compliance with this financial covenant.

There were no borrowings or letters of credit outstanding under the 2015 Facility as of (i) December 31, 2018 or (ii) the June 27, 2019 effective date of the closing of the New Facility and termination of the 2015 Facility. Further, at June 30, 2019, there were no borrowings or letters of credit outstanding under the New Facility. The Eurodollar Rate and Base Rate (inclusive of the applicable margin), had there been any amounts borrowed under the New Facility at June 30, 2019, would have been 3.30% and 5.50%, respectively.


-14-

EOG RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


Common Stock. On May 2, 2019, EOG's Board of Directors increased the quarterly cash dividend on the common stock from the previous $0.22 per share to $0.2875 per share, effective beginning with the dividend to be paid on July 31, 2019, to stockholders of record as of July 17, 2019.

11.    Fair Value Measurements

As more fully discussed in Note 13 to the Consolidated Financial Statements included in EOG's 2018 Annual Report, certain of EOG's financial and nonfinancial assets and liabilities are reported at fair value on the Condensed Consolidated Balance Sheets. The following table provides fair value measurement information within the fair value hierarchy for certain of EOG's financial assets and liabilities carried at fair value on a recurring basis at June 30, 2019 and December 31, 2018 (in thousands):
 
Fair Value Measurements Using:
 
Quoted
Prices in
Active
Markets
(Level 1)
 
Significant
Other
Observable
Inputs
(Level 2)
 
Significant
Unobservable
Inputs
(Level 3)
 
Total
At June 30, 2019
 

 
 

 
 

 
 

Financial Assets:
 

 
 

 
 

 
 

Natural Gas Swaps
$

 
$
18,507

 
$

 
$
18,507

Crude Oil Swaps

 
118,854

 

 
118,854

Crude Oil Basis Swaps

 
867

 

 
867

Financial Liabilities:
 
 
 
 
 
 
 
Crude Oil Basis Swaps
$

 
$
3,277

 
$

 
$
3,277

 
 
 
 
 
 
 
 
At December 31, 2018
 
 
 
 
 
 
 
Financial Assets:
 
 
 
 
 
 
 
Crude Oil Basis Swaps
$

 
$
23,806

 
$

 
$
23,806



The estimated fair value of commodity derivative contracts was based upon forward commodity price curves based on quoted market prices. Commodity derivative contracts were valued by utilizing an independent third-party derivative valuation provider who uses various types of valuation models, as applicable.

The initial measurement of asset retirement obligations at fair value is calculated using discounted cash flow techniques and based on internal estimates of future retirement costs associated with property, plant and equipment. Significant Level 3 inputs used in the calculation of asset retirement obligations include plugging costs and reserve lives. A reconciliation of EOG's asset retirement obligations is presented in Note 6.

Proved oil and gas properties and other assets with a carrying amount of $413 million were written down to their fair value of $322 million, resulting in pretax impairment charges of $91 million for the six months ended June 30, 2019. Included in the $91 million pretax impairment charges are $89 million for a commodity price-related write-down of other assets.

EOG utilized average prices per acre from comparable market transactions and estimated discounted cash flows as the basis for determining the fair value of unproved and proved properties, respectively, received in non-cash property exchanges. See Note 4.

Fair Value of Debt. At June 30, 2019 and December 31, 2018, respectively, EOG had outstanding $5,140 million and $6,040 million aggregate principal amount of senior notes, which had estimated fair values at such dates of approximately $5,387 million and $6,027 million, respectively. The estimated fair value of debt was based upon quoted market prices and, where such prices were not available, other observable (Level 2) inputs regarding interest rates available to EOG at the end of each respective period.


-15-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


12.    Risk Management Activities

Commodity Price Risk. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's 2018 Annual Report, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for crude oil and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for financial commodity derivative contracts using the mark-to-market accounting method.

Commodity Derivative Contracts. Prices received by EOG for its crude oil production generally vary from U.S. New York Mercantile Exchange (NYMEX) West Texas Intermediate prices due to adjustments for delivery location (basis) and other factors. EOG has entered into crude oil basis swap contracts in order to fix the differential between pricing in Midland, Texas, and Cushing, Oklahoma (Midland Differential). Presented below is a comprehensive summary of EOG's Midland Differential basis swap contracts for the six months ended June 30, 2019. The weighted average price differential expressed in dollars per barrel ($/Bbl) represents the amount of reduction to Cushing, Oklahoma, prices for the notional volumes expressed in barrels per day (Bbld) covered by the basis swap contracts.
 
Midland Differential Basis Swap Contracts
 
 
 
Volume (Bbld)
 
Weighted Average Price Differential
($/Bbl)
 
 
 
2019
 
 
 
 
 
January 1, 2019 through July 31, 2019 (closed)
 
20,000

 
$
1.075

 
August 1, 2019 through December 31, 2019
 
20,000

 
1.075



EOG has also entered into crude oil basis swap contracts in order to fix the differential between pricing in the U.S. Gulf Coast and Cushing, Oklahoma (Gulf Coast Differential). Presented below is a comprehensive summary of EOG's Gulf Coast Differential basis swap contracts for the six months ended June 30, 2019. The weighted average price differential expressed in $/Bbl represents the amount of addition to Cushing, Oklahoma, prices for the notional volumes expressed in Bbld covered by the basis swap contracts.
 
Gulf Coast Differential Basis Swap Contracts
 
 
 
Volume (Bbld)
 
Weighted Average Price Differential
($/Bbl)
 
 
 
2019
 
 
 
 
 
January 1, 2019 through July 31, 2019 (closed)
 
13,000

 
$
5.572

 
August 1, 2019 through December 31, 2019
 
13,000

 
5.572



Presented below is a comprehensive summary of EOG's crude oil price swap contracts for the six months ended June 30, 2019, with notional volumes expressed in Bbld and prices expressed in $/Bbl.
Crude Oil Price Swap Contracts
 
 
Volume (Bbld)
 
Weighted Average Price ($/Bbl)
2019
 
 
 
 
April 2019 (closed)
 
25,000

 
$
60.00

May 1, 2019 through June 30, 2019 (closed)
 
150,000

 
62.50

July 1, 2019 through December 31, 2019
 
150,000

 
62.50




-16-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


Presented below is a comprehensive summary of EOG's natural gas price swap contracts for the six months ended June 30, 2019, with notional volumes expressed in million British thermal units (MMBtu) per day (MMBtud) and prices expressed in dollars per MMBtu ($/MMBtu).
Natural Gas Price Swap Contracts
 
 
Volume (MMBtud)
 
Weighted Average Price ($/MMBtu)
2019
 
 
 
 
April 1, 2019 through July 31, 2019 (closed)
 
250,000

 
$
2.90

August 1, 2019 through October 31, 2019
 
250,000

 
2.90




The following table sets forth the amounts and classification of EOG's outstanding financial derivative instruments at June 30, 2019 and December 31, 2018.  Certain amounts may be presented on a net basis on the Condensed Consolidated Financial Statements when such amounts are with the same counterparty and subject to a master netting arrangement (in thousands):
 
 
  
 
Fair Value at
Description
 
Location on Balance Sheet
 
June 30, 2019
 
December 31, 2018
Asset Derivatives
 
 
 
 
 
 
Crude oil and natural gas derivative contracts -
 
 
 
 
 
 
Current portion
 
Assets from Price Risk Management Activities (1)
 
$
134,951

 
$
23,806

 
(1)
The current portion of Assets from Price Risk Management Activities consists of gross assets of $138 million, partially offset by gross liabilities of $3 million at June 30, 2019.

Credit Risk. Notional contract amounts are used to express the magnitude of a financial derivative. The amounts potentially subject to credit risk, in the event of nonperformance by the counterparties, are equal to the fair value of such contracts (see Note 11). EOG evaluates its exposure to significant counterparties on an ongoing basis, including those arising from physical and financial transactions. In some instances, EOG renegotiates payment terms and/or requires collateral, parent guarantees or letters of credit to minimize credit risk.

All of EOG's derivative instruments are covered by International Swap Dealers Association Master Agreements (ISDAs) with counterparties. The ISDAs may contain provisions that require EOG, if it is the party in a net liability position, to post collateral when the amount of the net liability exceeds the threshold level specified for EOG's then-current credit ratings. In addition, the ISDAs may also provide that as a result of certain circumstances, including certain events that cause EOG's credit ratings to become materially weaker than its then-current ratings, the counterparty may require all outstanding derivatives under the ISDAs to be settled immediately. See Note 11 for the aggregate fair value of all derivative instruments that were in a net asset position at June 30, 2019 and December 31, 2018. EOG had no collateral posted and held collateral of $4 million at June 30, 2019. EOG had no collateral posted or held at December 31, 2018.


-17-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


13.  Acquisitions and Divestitures

During the six months ended June 30, 2019, EOG paid cash for property acquisitions of $304 million in the United States. Additionally, during the six months ended June 30, 2019, EOG recognized net gains on asset dispositions of $4 million and received proceeds of approximately $18 million. During the six months ended June 30, 2018, EOG recognized net losses on asset dispositions of $(21) million, primarily due to non-cash exchanges of unproved leasehold in New Mexico and Wyoming as well as the disposition of inventory and other assets, and received proceeds of approximately $8 million.

14. Leases

In the ordinary course of business, EOG enters into contracts for drilling, fracturing, compression, real estate and other services which contain equipment and other assets that meet the definition of a lease under ASU 2016-02. The lease term for these contracts, which includes any renewals at EOG's option that are reasonably certain to be exercised, ranges from one month to 30 years. ROU assets and related liabilities are recognized on commencement date on the Condensed Consolidated Balance Sheets based on future lease payments, discounted based on the rate implicit in the contract, if readily determinable, or EOG's incremental borrowing rate commensurate with the lease term of the contract. Contracts with lease terms less than 12 months are not recorded on the Condensed Consolidated Balance Sheets, but instead are disclosed as short-term lease cost.

EOG has elected not to separate non-lease components from all leases, excluding those for fracturing services, real estate and salt water disposal, as lease payments for these contracts contain significant non-lease components, such as labor and operating costs.

Lease costs are classified by the function of the ROU asset. The lease costs related to exploration and development activities are initially included in the Oil and Gas Properties line on the Condensed Consolidated Balance Sheets and subsequently accounted for in accordance with the Extractive Industries - Oil and Gas Topic of the Accounting Standards Codification. Variable lease cost represents costs incurred above the contractual minimum payments for operating and finance leases. The components of lease cost for the three month and six month periods ended June 30, 2019, were as follows (in millions):
 
Three Months Ended 
 June 30, 2019
 
Six Months Ended 
 June 30, 2019
Operating Lease Cost
$
134

 
$
253

Finance Lease Cost:
 
 
 
Amortization of Lease Assets
4

 
7

Interest on Lease Liabilities

 
1

Variable Lease Cost
97

 
128

Short-Term Lease Cost
157

 
228

Total Lease Cost
$
392

 
$
617




-18-

EOG RESOURCES, INC.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS – (Continued)
(Unaudited)


The following table sets forth the amounts and classification of EOG's outstanding ROU assets and related lease liabilities and supplemental information at June 30, 2019 (in millions, except lease terms and discount rates):
Description
 
Location on Balance Sheet
 
Amount
Assets
 
 
 
 
Operating Leases
 
Other Assets
 
$
895

Finance Leases
 
Property, Plant and Equipment, Net (1)
 
59

Total
 
 
 
$
954

 
 
 
 
 
Liabilities
 
 
 
 
Current
 
 
 
 
Operating Leases
 
Current Portion of Operating Lease Liabilities
 
$
397

Finance Leases
 
Current Portion of Long-Term Debt
 
15

Long-Term
 
 
 
 
Operating Leases
 
Other Liabilities
 
527

Finance Leases
 
Long-Term Debt
 
49

Total
 
 
 
$
988

 
(1)
Finance lease assets are recorded net of accumulated amortization of $53 million at June 30, 2019.



 
Six Months Ended 
 June 30, 2019
Weighted Average Remaining Lease Term (in years):
 
Operating Leases
3.3

Finance Leases
5.3

 
 
Weighted Average Discount Rate:
 
Operating Leases
3.5
%
Finance Leases
3.0
%


Cash paid for leases was as follows for the six months ended June 30, 2019 (in millions):
 
Six Months Ended 
 June 30, 2019
Repayment of Operating Lease Liabilities Associated with Operating Activities
$
104

Repayment of Operating Lease Liabilities Associated with Investing Activities
146

Repayment of Finance Lease Liabilities
8



Upon adoption of ASU 2016-02 effective January 1, 2019, EOG recognized operating lease ROU assets of $566 million. Non-cash leasing activities for the six months ended June 30, 2019, included the addition of $606 million of operating leases.


-19-

EOG RESOURCES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Concluded)
(Unaudited)


At June 30, 2019, the future minimum lease payments under non-cancellable leases were as follows (in millions):
 
Operating Leases
 
Finance Leases
July 1, 2019 to December 31, 2019
$
230

 
$
8

2020
362

 
15

2021
177

 
15

2022
104

 
12

2023
45

 
8

2024 and Beyond
63

 
14

Total Lease Payments
981

 
72

Less: Discount to Present Value
57

 
8

Total Lease Liabilities
924

 
64

Less: Current Portion of Lease Liabilities
397

 
15

Long-Term Lease Liabilities
$
527

 
$
49



At June 30, 2019, EOG had additional leases of $823 million, of which $97 million, $521 million and $205 million were expected to commence in the remainder of 2019, 2020 and 2021, respectively, with lease terms of 1 month to 10 years.

At December 31, 2018 and prior to the adoption of ASU 2016-02 and other related ASUs, the future minimum commitments under non-cancellable leases, including non-lease components and excluding contracts with lease terms less than 12 months, were as follows (in millions):
 
Operating Leases
 
Finance Leases
2019
$
380

 
$
15

2020
213

 
15

2021
86

 
15

2022
39

 
12

2023
30

 
8

2024 and Beyond
62

 
14

Total Lease Payments
$
810

 
$
79




-20-

    



PART I.  FINANCIAL INFORMATION

ITEM 2.  MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
EOG RESOURCES, INC.

Overview
EOG Resources, Inc., together with its subsidiaries (collectively, EOG), is one of the largest independent (non-integrated) crude oil and natural gas companies in the United States with proved reserves in the United States, Trinidad and China. EOG operates under a consistent business and operational strategy that focuses predominantly on maximizing the rate of return on investment of capital by controlling operating and capital costs and maximizing reserve recoveries. Each prospective drilling location is evaluated by its estimated rate of return. This strategy is intended to enhance the generation of cash flow and earnings from each unit of production on a cost-effective basis, allowing EOG to deliver long-term production growth while maintaining a strong balance sheet. EOG implements its strategy primarily by emphasizing the drilling of internally generated prospects in order to find and develop low-cost reserves. Maintaining the lowest possible operating cost structure that is consistent with efficient, safe and environmentally responsible operations is also an important goal in the implementation of EOG's strategy.

United States. EOG's efforts to identify plays with large reserve potential have proven to be successful. EOG continues to drill numerous wells in large acreage plays, which in the aggregate have contributed substantially to, and are expected to continue to contribute substantially to, EOG's crude oil and liquids-rich natural gas production. EOG has placed an emphasis on applying its horizontal drilling and completion expertise to unconventional crude oil and liquids-rich reservoirs.

Crude oil, natural gas liquids (NGLs) and natural gas prices have been volatile, and this volatility is expected to continue. As a result of the many uncertainties associated with the world political environment, worldwide supplies of, and demand for, crude oil and condensate, NGLs and natural gas and the availability of other energy supplies, EOG is unable to predict what changes may occur in crude oil and condensate, NGLs, and natural gas prices in the future. The market prices of crude oil and condensate, NGLs and natural gas in 2019 will continue to impact the amount of cash generated from EOG's operating activities, which will in turn impact EOG's financial position and results of operations. For the first six months of 2019, the average U.S. New York Mercantile Exchange (NYMEX) crude oil and natural gas prices were $57.38 per barrel and $2.87 per million British thermal units (MMBtu), respectively, representing a decrease of 12% and an increase of 1%, respectively, from the average NYMEX prices for the same period in 2018. Market prices for NGLs are influenced by crude oil prices and the composition of NGL production, including ethane, propane and butane, among others. Based on its 2019 drilling and completion plans, EOG expects its 2019 total production and total crude oil production to increase as compared to 2018.

During the first half of 2019, EOG continued to focus on increasing drilling, completion and operating efficiencies gained in prior years. In addition, EOG continued to evaluate certain potential crude oil and liquids-rich natural gas exploration and development prospects and to look for opportunities to add drilling inventory through leasehold acquisitions, farm-ins, exchanges or tactical acquisitions. On a volumetric basis, as calculated using the ratio of 1.0 barrel of crude oil and condensate or NGLs to 6.0 thousand cubic feet of natural gas, crude oil and condensate and NGL production accounted for approximately 77% and 76% of EOG's United States production during the first half of 2019 and 2018, respectively. During the first half of 2019, EOG's drilling and completion activities occurred primarily in the Eagle Ford play, Delaware Basin play and Rocky Mountain area. EOG's major producing areas in the United States are in New Mexico, North Dakota, Texas and Wyoming.

Trinidad. In Trinidad, EOG continues to deliver natural gas under existing supply contracts. Several fields in the South East Coast Consortium (SECC) Block, Modified U(a) Block, Block 4(a), Modified U(b) Block, the Banyan Field and the Sercan Area have been developed and are producing natural gas which is sold to the National Gas Company of Trinidad and Tobago Limited and its subsidiary, and crude oil and condensate which is sold to Heritage Petroleum Company Limited. During the second half of 2019, EOG plans to drill three net wells.

Other International. In the Sichuan Basin, Sichuan Province, China, EOG drilled two wells in the first half of 2019 to complete the drilling program started in 2018. EOG completed one drilled uncompleted well from the 2018 drilling program in 2019. All natural gas produced from the Baijaochang Field is sold under a long-term contract to PetroChina.

EOG continues to evaluate other select crude oil and natural gas opportunities outside the United States, primarily by pursuing exploitation opportunities in countries where indigenous crude oil and natural gas reserves have been identified.


-21-

    



Capital Structure. One of management's key strategies is to maintain a strong balance sheet with a consistently below average debt-to-total capitalization ratio as compared to those in EOG's peer group. EOG's debt-to-total capitalization ratio was 20% at June 30, 2019 and 24% at December 31, 2018. As used in this calculation, total capitalization represents the sum of total current and long-term debt and total stockholders' equity.

On June 3, 2019, EOG repaid upon maturity the $900 million aggregate principal amount of its 5.625% Senior Notes due 2019.

On June 27, 2019, EOG entered into a new $2.0 billion senior unsecured Revolving Credit Agreement (New Facility) with domestic and foreign lenders. The New Facility replaces EOG's $2.0 billion senior unsecured Revolving Credit Agreement, dated as of July 21, 2015, which had a scheduled maturity date of July 21, 2020. The New Facility has a scheduled maturity date of June 27, 2024, and includes an option for EOG to extend, on up to two occasions, the term for successive one-year periods subject to certain terms and conditions. The New Facility (i) commits the Banks to provide advances up to an aggregate principal amount of $2.0 billion at any one time outstanding, with an option for EOG to request increases in the aggregate commitments to an amount not to exceed $3.0 billion, subject to certain terms and conditions, and (ii) includes a swingline subfacility and a letter of credit subfacility.

Effective January 1, 2019, EOG adopted the provisions of Accounting Standards Update (ASU) 2016-02, "Leases (Topic 842)" (ASU 2016-02). ASU 2016-02 and other related ASUs resulted in the recognition of right-of-use assets and related lease liabilities representing the obligation to make lease payments for certain lease transactions and the disclosure of additional leasing information. The adoption of ASU 2016-02 and other related ASUs resulted in a significant increase to assets and liabilities related to operating leases on the Condensed Consolidated Balance Sheet at June 30, 2019. Financial results prior to January 1, 2019, are unchanged. See Note 1 "Summary of Significant Accounting Policies" and Note 14 "Leases" to EOG's Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q.

Total anticipated 2019 capital expenditures are estimated to range from approximately $6.1 billion to $6.5 billion, excluding acquisitions and non-cash transactions. The majority of 2019 expenditures will be focused on United States crude oil drilling activities. EOG has significant flexibility with respect to financing alternatives, including borrowings under its commercial paper program and other uncommitted credit facilities, bank borrowings, borrowings under its $2.0 billion senior unsecured revolving credit facility, joint development agreements and similar agreements and equity and debt offerings.

Management continues to believe EOG has one of the strongest prospect inventories in EOG's history. When it fits EOG's strategy, EOG will make acquisitions that bolster existing drilling programs or offer incremental exploration and/or production opportunities.



-22-

    



Results of Operations

The following review of operations for the three months and six months ended June 30, 2019 and 2018 should be read in conjunction with the Condensed Consolidated Financial Statements of EOG and notes thereto included in this Quarterly Report on Form 10‑Q.

Three Months Ended June 30, 2019 vs. Three Months Ended June 30, 2018

Operating Revenues. During the second quarter of 2019, operating revenues increased $460 million, or 11%, to $4,698 million from $4,238 million for the same period of 2018. Total wellhead revenues, which are revenues generated from sales of EOG's production of crude oil and condensate, NGLs and natural gas, for the second quarter of 2019 increased $20 million, or 1%, to $2,985 million from $2,965 million for the same period of 2018. EOG recognized net gains on the mark-to-market of financial commodity derivative contracts of $177 million for the second quarter of 2019 compared to net losses of $186 million for the same period of 2018. Gathering, processing and marketing revenues for the second quarter of 2019 increased $65 million, or 5%, to $1,501 million from $1,436 million for the same period of 2018. Net gains on asset dispositions were $8 million for the second quarter of 2019 compared to net losses of $6 million for the same period of 2018.


-23-

    



Wellhead volume and price statistics for the three-month periods ended June 30, 2019 and 2018 were as follows:
 
Three Months Ended 
 June 30,
 
 
2019
 
 
2018
 
Crude Oil and Condensate Volumes (MBbld) (1)
 
 
 
 
 
United States
454.9

 
 
379.2

 
Trinidad
0.6

 
 
0.8

 
Other International (2)
0.2

 
 
4.6

 
Total
455.7

 
 
384.6

 
Average Crude Oil and Condensate Prices ($/Bbl) (3)
 

 
 
 
 
United States
$
61.01

 
 
$
67.91

 
Trinidad
49.56

 
 
60.57

 
Other International (2)
55.07

 
 
70.88

 
Composite
60.99

 
 
67.93

 
Natural Gas Liquids Volumes (MBbld) (1)
 
 
 
 
 
United States
131.1

 
 
112.9

 
Other International (2)

 
 

 
Total
131.1

 
 
112.9

 
Average Natural Gas Liquids Prices ($/Bbl) (3)
 

 
 
 

 
United States
$
15.63

 
 
$
27.86

 
Other International (2)

 
 

 
Composite
15.63

 
 
27.86

 
Natural Gas Volumes (MMcfd) (1)
 
 
 
 
 
United States
1,047

 
 
914

 
Trinidad
273

 
 
282

 
Other International (2)
36

 
 
32

 
Total
1,356

 
 
1,228

 
Average Natural Gas Prices ($/Mcf) (3)
 

 
 
 

 
United States
$
1.98

 
 
$
2.56

 
Trinidad
2.69

 
 
2.98

 
Other International (2)
4.25

 
 
4.10

 
Composite
2.19

 
 
2.69

 
Crude Oil Equivalent Volumes (MBoed) (4)
 
 
 
 
 
United States
760.4

 
 
644.4

 
Trinidad
46.1

 
 
47.8

 
Other International (2)
6.3

 
 
10.0

 
Total
812.8

 
 
702.2

 
 
 
 
 
 
 
Total MMBoe (4)
74.0

 
 
63.9

 
 
(1)
Thousand barrels per day or million cubic feet per day, as applicable.
(2)
Other International includes EOG's United Kingdom, China and Canada operations. The United Kingdom operations were sold in the fourth quarter of 2018.
(3)
Dollars per barrel or per thousand cubic feet, as applicable. Excludes the impact of financial commodity derivative instruments (see Note 12 to the Condensed Consolidated Financial Statements).
(4)
Thousand barrels of oil equivalent per day or million barrels of oil equivalent, as applicable; includes crude oil and condensate, NGLs and natural gas. Crude oil equivalent volumes are determined using a ratio of 1.0 barrel of crude oil and condensate or NGLs to 6.0 thousand cubic feet of natural gas. MMBoe is calculated by multiplying the MBoed amount by the number of days in the period and then dividing that amount by one thousand.


-24-

    



Wellhead crude oil and condensate revenues for the second quarter of 2019 increased $151 million, or 6%, to $2,529 million from $2,378 million for the same period of 2018. The increase was due to an increase of 71 MBbld, or 18%, in wellhead crude oil and condensate production ($439 million), partially offset by a lower composite average price ($288 million). Increased production was primarily due to increases in the Permian Basin and the Eagle Ford. EOG's composite wellhead crude oil and condensate price for the second quarter of 2019 decreased 10% to $60.99 per barrel compared to $67.93 per barrel for the same period of 2018.

NGL revenues for the second quarter of 2019 decreased $100 million, or 35%, to $186 million from $286 million for the same period of 2018 due to a lower composite average price ($146 million), partially offset by an increase of 18 MBbld, or 16%, in production ($46 million). Increased production was primarily in the Permian Basin. EOG's composite NGL price for the second quarter of 2019 decreased 44% to $15.63 per barrel compared to $27.86 per barrel for the same period of 2018.

Wellhead natural gas revenues for the second quarter of 2019 decreased $31 million, or 10%, to $270 million from $301 million for the same period of 2018. The decrease was due to a lower average composite price ($63 million), partially offset by an increase in natural gas deliveries ($32 million). Natural gas deliveries for the second quarter of 2019 increased 128 MMcfd, or 10%, compared to the same period of 2018 due primarily to higher deliveries in the United States primarily resulting from increased production of associated natural gas from the Permian Basin and higher natural gas volumes in South Texas. EOG's composite wellhead natural gas price for the second quarter of 2019 decreased 19% to $2.19 per Mcf compared to $2.69 per Mcf for the same period of 2018.

During the second quarter of 2019, EOG recognized net gains on the mark-to-market of financial commodity derivative contracts of $177 million compared to net losses of $186 million for the same period of 2018. During the second quarter of 2019, net cash received from settlements of financial commodity derivative contracts was $10 million compared to net cash paid of $66 million for the same period of 2018.

Gathering, processing and marketing revenues are revenues generated from sales of third-party crude oil, NGLs and natural gas, as well as gathering fees associated with gathering third-party natural gas and revenues from sales of EOG-owned sand. Purchases and sales of third-party crude oil and natural gas may be utilized in order to balance firm transportation capacity with production in certain areas and to utilize excess capacity at EOG-owned facilities. EOG sells sand in order to balance the timing of firm purchase agreements with completion operations and to utilize excess capacity at EOG-owned facilities. Marketing costs represent the costs to purchase third-party crude oil, natural gas and sand and the associated transportation costs, as well as costs associated with EOG-owned sand sold to third parties.

Gathering, processing and marketing revenues less marketing costs for the second quarter of 2019 decreased $15 million as compared to the same period of 2018 primarily due to lower margins on crude oil marketing activities, partially offset by higher margins on natural gas marketing activities.

Operating and Other Expenses.  For the second quarter of 2019, operating expenses of $3,567 million were $294 million higher than the $3,273 million incurred during the second quarter of 2018.  The following table presents the costs per barrel of oil equivalent (Boe) for the three-month periods ended June 30, 2019 and 2018:
 
Three Months Ended 
 June 30,
 
2019
 
2018
Lease and Well
$
4.70

 
$
4.92

Transportation Costs
2.35

 
2.78

Depreciation, Depletion and Amortization (DD&A) -
 
 
 
Oil and Gas Properties
12.55

 
12.83

Other Property, Plant and Equipment
0.39

 
0.45

General and Administrative (G&A)
1.65

 
1.63

Interest Expense, Net
0.67

 
0.99

Total (1)
$
22.31

 
$
23.60

 
(1)
Total excludes gathering and processing costs, exploration costs, dry hole costs, impairments, marketing costs and taxes other than income.


-25-

    



The primary factors impacting the cost components of per-unit rates of lease and well, transportation costs, DD&A, G&A and net interest expense for the three months ended June 30, 2019, compared to the same period of 2018, are set forth below. See "Operating Revenues" above for a discussion of wellhead volumes.

Lease and well expenses include expenses for EOG-operated properties, as well as expenses billed to EOG from other operators where EOG is not the operator of a property. Lease and well expenses can be divided into the following categories: costs to operate and maintain crude oil and natural gas wells, the cost of workovers and lease and well administrative expenses. Operating and maintenance costs include, among other things, pumping services, salt water disposal, equipment repair and maintenance, compression expense, lease upkeep and fuel and power. Workovers are operations to restore or maintain production from existing wells.

Each of these categories of costs individually fluctuates from time to time as EOG attempts to maintain and increase production while maintaining efficient, safe and environmentally responsible operations. EOG continues to increase its operating activities by drilling new wells in existing and new areas. Operating and maintenance costs within these existing and new areas, as well as the costs of services charged to EOG by vendors, fluctuate over time.

Lease and well expenses of $347 million for the second quarter of 2019 increased $32 million from $315 million for the same prior year period primarily due to increased operating and maintenance costs ($24 million), lease and well administrative expenses ($8 million) and workover expenditures ($4 million), all in the United States, partially offset by decreased operating and maintenance costs in the United Kingdom ($3 million) due to the sale of operations in the fourth quarter of 2018. Lease and well expenses increased in the United States primarily due to increased operating activities resulting in increased production.

Transportation costs represent costs associated with the delivery of hydrocarbon products from the lease to a downstream point of sale. Transportation costs include transportation fees, the cost of compression (the cost of compressing natural gas to meet pipeline pressure requirements), the cost of dehydration (the cost associated with removing water from natural gas to meet pipeline requirements), gathering fees and fuel costs.

Transportation costs of $174 million for the second quarter of 2019 decreased $4 million from $178 million for the same prior year period primarily due to decreased transportation costs in the Eagle     Ford ($24 million), partially offset by increased transportation costs in the Permian Basin ($17 million) and Rocky Mountain area ($4 million).

DD&A of the cost of proved oil and gas properties is calculated using the unit-of-production method. EOG's DD&A rate and expense are the composite of numerous individual DD&A group calculations. There are several factors that can impact EOG's composite DD&A rate and expense, such as field production profiles, drilling or acquisition of new wells, disposition of existing wells and reserve revisions (upward or downward) primarily related to well performance, economic factors and impairments. Changes to these factors may cause EOG's composite DD&A rate and expense to fluctuate from period to period. DD&A of the cost of other property, plant and equipment is generally calculated using the straight-line depreciation method over the useful lives of the assets.

DD&A expenses for the second quarter of 2019 increased $108 million to $957 million from $849 million for the same prior year period. DD&A expenses associated with oil and gas properties for the second quarter of 2019 were $108 million higher than the same prior year period. The increase primarily reflects increased production in the United States.

G&A expenses of $122 million for the second quarter of 2019 increased $18 million from $104 million for the same prior year period primarily due to increased employee-related expenses resulting from expanded operations.

Interest expense, net of $50 million for the second quarter of 2019 decreased $14 million compared to the same prior year period primarily due to repayment in October 2018 of the $350 million aggregate principal amount of 6.875% Senior Notes due 2018 ($6 million), repayment in June 2019 of the $900 million aggregate principal amount of 5.625% Senior Notes due 2019 ($4 million) and higher capitalized interest ($4 million).

Exploration costs of $33 million for the second quarter of 2019 decreased $14 million from $47 million for the same prior year period primarily due to decreased geological and geophysical costs in Trinidad.


-26-

    



Impairments include amortization of unproved oil and gas property costs as well as impairments of proved oil and gas properties; other property, plant and equipment; and other assets. Unproved properties with acquisition costs that are not individually significant are aggregated, and the portion of such costs estimated to be nonproductive is amortized over the remaining lease term. Unproved properties with individually significant acquisition costs are reviewed individually for impairment. When circumstances indicate that a proved property may be impaired, EOG compares expected undiscounted future cash flows at a DD&A group level to the unamortized capitalized cost of the asset. If the expected undiscounted future cash flows are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is generally calculated by using the Income Approach described in the Fair Value Measurement Topic of the Financial Accounting Standards Board's Accounting Standards Codification. In certain instances, EOG utilizes accepted offers from third-party purchasers as the basis for determining fair value.

Impairments of $112 million for the second quarter of 2019 were $60 million higher than impairments for the same prior year period primarily due to increased impairments of other assets in the United States. EOG recorded impairments of proved properties, other property, plant and equipment and other assets of $65 million and $10 million for the second quarter of 2019 and 2018, respectively.

Taxes other than income include severance/production taxes, ad valorem/property taxes, payroll taxes, franchise taxes and other miscellaneous taxes. Severance/production taxes are generally determined based on wellhead revenues, and ad valorem/property taxes are generally determined based on the valuation of the underlying assets.

Taxes other than income for the second quarter of 2019 increased $10 million to $204 million (6.8% of wellhead revenues) compared to $194 million (6.6% of wellhead revenues) for the same prior year period. The increase in taxes other than income was primarily due to increased ad valorem/property taxes ($16 million) primarily as a result of increased valuation of the underlying assets, partially offset by decreases in severance/production taxes ($3 million), both in the United States, and an increase in credits available to EOG in the second quarter of 2019 for Texas high-cost gas severance tax rate reductions ($2 million).

Other income, net of $9 million for the second quarter of 2019 increased $17 million compared to the same prior year period primarily due to higher foreign currency exchange gains ($7 million), an increase in interest income ($6 million) and a decrease in deferred compensation expense ($5 million).

EOG recognized an income tax provision of $242 million for the second quarter of 2019 compared to an income tax provision of $196 million for the second quarter of 2018, primarily due to an increase in pretax income. The net effective tax rate of 22% for the second quarter of 2019 was unchanged from the second quarter of 2018.

Six Months Ended June 30, 2019 vs. Six Months Ended June 30, 2018

Operating Revenues. During the first six months of 2019, operating revenues increased $837 million, or 11%, to $8,756 million from $7,919 million for the same period of 2018. Total wellhead revenues for the first six months of 2019 increased $152 million, or 3%, to $5,739 million from $5,587 million for the same period of 2018. During the first six months of 2019, EOG recognized net gains on the mark-to-market of financial commodity derivative contracts of $157 million compared to net losses of $246 million for the same period of 2018. Gathering, processing and marketing revenues for the first six months of 2019 increased $249 million, or 10%, to $2,787 million from $2,538 million for the same period of 2018. Net gains on asset dispositions were $4 million for the first six months of 2019 compared to net losses of $21 million for the same period of 2018.


-27-

    



Wellhead volume and price statistics for the six-month periods ended June 30, 2019 and 2018 were as follows:
 
Six Months Ended 
 June 30,
 
 
2019
 
 
2018
 
Crude Oil and Condensate Volumes (MBbld)
 
 
 
 
 
United States
445.1

 
 
369.5

 
Trinidad
0.7

 
 
0.9

 
Other International

 
 
3.6

 
Total
445.8

 
 
374.0

 
Average Crude Oil and Condensate Prices ($/Bbl) (1)
 

 
 
 

 
United States
$
58.63

 
 
$
66.13

 
Trinidad
46.62

 
 
57.59

 
Other International
57.78

 
 
71.14

 
Composite
58.61

 
 
66.16

 
Natural Gas Liquids Volumes (MBbld)
 
 
 
 
 
United States
125.4

 
 
106.8

 
Other International

 
 

 
Total
125.4

 
 
106.8

 
Average Natural Gas Liquids Prices ($/Bbl)
 

 
 
 

 
United States
$
17.84

 
 
$
26.27

 
Other International

 
 

 
Composite
17.84

 
 
26.27

 
Natural Gas Volumes (MMcfd)
 
 
 
 
 
United States
1,025

 
 
884

 
Trinidad
270

 
 
288

 
Other International
37

 
 
30

 
Total
1,332

 
 
1,202

 
Average Natural Gas Prices ($/Mcf) (1)
 

 
 
 

 
United States
$
2.37

 
 
$
2.65

 
Trinidad
2.80

 
 
2.93

 
Other International
4.31

 
 
4.22

 
Composite
2.51

 
 
2.76

 
Crude Oil Equivalent Volumes (MBoed)
 
 
 
 
 
United States
741.3

 
 
623.6

 
Trinidad
45.6

 
 
48.8

 
Other International
6.4

 
 
8.8

 
Total
793.3

 
 
681.2

 
 
 
 
 
 
 
Total MMBoe
143.6

 
 
123.3

 
 
(1)
Excludes the impact of financial commodity derivative instruments (see Note 12 to the Condensed Consolidated Financial Statements).


-28-

    



Wellhead crude oil and condensate revenues for the first six months of 2019 increased $250 million, or 6%, to $4,729 million from $4,479 million for the same period of 2018 due to an increase of 72 MBbld, or 19%, in wellhead crude oil and condensate production ($859 million), partially offset by a lower composite average price ($609 million). Increased production was primarily due to increases in the Permian Basin and the Eagle Ford. EOG's composite wellhead crude oil and condensate price for the first six months of 2019 decreased 11% to $58.61 per barrel compared to $66.16 per barrel for the same period of 2018.

NGL revenues for the first six months of 2019 decreased $103 million, or 20%, to $405 million from $508 million for the same period of 2018 due to a lower composite average price ($192 million), partially offset by an increase of 19 MBbld, or 17%, in NGL deliveries ($89 million). Increased production was primarily in the Permian Basin. EOG's composite NGL price for the first six months of 2019 decreased 32% to $17.84 per barrel compared to $26.27 per barrel for the same period of 2018.

Wellhead natural gas revenues for the first six months of 2019 increased $4 million, or 1%, to $605 million from $601 million for the same period of 2018. The increase was due to an increase in natural gas deliveries ($59 million), partially offset by a lower composite wellhead natural gas price ($55 million). Natural gas deliveries for the first six months of 2019 increased 130 MMcfd, or 11%, compared to the same period of 2018 due primarily to higher deliveries in the United States resulting from increased production of associated natural gas from the Permian Basin and higher natural gas volumes from South Texas, partially offset by lower production of associated natural gas in the Rocky Mountain area and lower natural gas deliveries in Trinidad. EOG's composite wellhead natural gas price for the first six months of 2019 decreased 9% to $2.51 per Mcf compared to $2.76 per Mcf for the same period of 2018.

During the first six months of 2019, EOG recognized net gains on the mark-to-market of financial commodity derivative contracts of $157 million compared to net losses of $246 million for the same period of 2018. During the first six months of 2019, net cash received from settlements of financial commodity derivative contracts was $31 million compared to net cash paid for settlements of financial commodity derivative contracts of $88 million for the same period of 2018.

Gathering, processing and marketing revenues less marketing costs for the first six months of 2019 increased $5 million as compared to the same period of 2018 primarily due to higher margins on natural gas marketing activities.

Operating and Other Expenses. For the first six months of 2019, operating expenses of $6,749 million were $669 million higher than the $6,080 million incurred during the same period of 2018. The following table presents the costs per Boe for the six-month periods ended June 30, 2019 and 2018:
 
Six Months Ended 
 June 30,
 
2019
 
2018
Lease and Well
$
4.76

 
$
4.99

Transportation Costs
2.44

 
2.88

DD&A -
 
 
 
Oil and Gas Properties
12.40

 
12.49

Other Property, Plant and Equipment
0.39

 
0.46

G&A
1.59

 
1.61

Interest Expense, Net
0.73

 
1.02

Total (1)
$
22.31

 
$
23.45

 
(1)
Total excludes gathering and processing costs, exploration costs, dry hole costs, impairments, marketing costs and taxes other than income.

The primary factors impacting the cost components of per-unit rates of lease and well, transportation costs, DD&A, G&A and net interest expense for the six months ended June 30, 2019, compared to the same period of 2018 are set forth below. See "Operating Revenues" above for a discussion of wellhead volumes.

Lease and well expenses of $684 million for the first six months of 2019 increased $69 million from $615 million for the same prior year period primarily due to higher operating and maintenance costs ($48 million), higher workover expenditures ($17 million) and higher lease and well administrative costs ($12 million), all in the United States, partially offset by lower operating and maintenance costs in the United Kingdom ($8 million) due to the sale of operations in the fourth quarter of 2018. Lease and well expenses increased in the United States primarily due to increased operating activities resulting in increased production.


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Transportation costs of $351 million for the first six months of 2019 decreased $4 million from $355 million for the same prior year period primarily due to decreased transportation costs in the Eagle Ford ($40 million), partially offset by increased transportation costs in the Permian Basin ($38 million).

DD&A expenses for the first six months of 2019 increased $240 million to $1,837 million from $1,597 million for the same prior year period. DD&A expenses associated with oil and gas properties for the first six months of 2019 were $241 million higher than the same prior year period. The increase primarily reflects increased production in the United States.

G&A expenses of $228 million for the first six months of 2019 increased $29 million from $199 million for the same prior year period primarily due to increased employee-related expenses resulting from expanded operations.

Interest expense, net of $105 million for the first six months of 2019 decreased $21 million compared to the same prior year period primarily due to repayment in October 2018 of the $350 million aggregate principal amount of 6.875% Senior Notes due 2018 ($12 million), higher capitalized interest ($6 million) and repayment in June 2019 of the $900 million aggregate principal amount of 5.625% Senior Notes due 2019 ($4 million).

Gathering and processing costs represent operating and maintenance expenses and administrative expenses associated with operating EOG's gathering and processing assets as well as natural gas processing fees from third parties. EOG pays third parties to process the majority of its natural gas production to extract NGLs.

Gathering and processing costs of $224 million for the first six months of 2019 increased $13 million compared to the same prior year period primarily due to increased operating costs in the Permian Basin ($28 million) and the Rocky Mountain area ($5 million), partially offset by decreased operating costs in the United Kingdom ($19 million) due to the sale of operations in the fourth quarter of 2018.

Exploration costs of $69 million for the first six months of 2019 decreased $13 million from $82 million for the same prior year period primarily due to decreased geological and geophysical costs in Trinidad.

Impairments of $184 million for the first six months of 2019 were $68 million higher than impairments for the same prior year period primarily due to increased impairments of other assets in the United States. EOG recorded impairments of proved properties, other property, plant and equipment and other assets of $91 million and $32 million for the first six months of 2019 and 2018, respectively.

Taxes other than income for the first six months of 2019 increased $24 million to $397 million (6.9% of wellhead revenues) from $373 million (6.7% of wellhead revenues) for the same prior year period. The increase in taxes other than income was primarily due to increased ad valorem/property taxes in the United States ($37 million) primarily as a result of increased valuation of the underlying assets, partially offset by decreases in severance/production taxes in the United States ($6 million) and Trinidad ($3 million), and an increase in credits available to EOG in the second quarter of 2019 for Texas high-cost severance tax rate reductions ($4 million).

Other income, net of $14 million for the first six months of 2019 increased $22 million compared to the same prior year period primarily due to an increase in interest income ($11 million) and higher foreign currency exchange gains ($8 million).

EOG recognized an income tax provision of $433 million for the first six months of 2019 compared to an income tax provision of $371 million for the same period in 2018, primarily due to an increase in pretax income. The net effective tax rate for the first six months of 2019 increased to 23% from 22% for the first six months of 2018.

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Capital Resources and Liquidity

Cash Flow. The primary sources of cash for EOG during the six months ended June 30, 2019, were funds generated from operations. The primary uses of cash were funds used in operations; exploration and development expenditures; long-term debt repayments; dividend payments to stockholders; and other property, plant and equipment expenditures. During the first six months of 2019, EOG's cash balance decreased $396 million to $1,160 million from $1,556 million at December 31, 2018.

Net cash provided by operating activities of $4,294 million for the first six months of 2019 increased $801 million compared to the same period of 2018 primarily due to a decrease in net cash paid for income taxes ($395 million), a favorable change in working capital ($252 million), an increase in wellhead revenues ($152 million) and an increase in cash received for settlements of commodity derivative contracts ($120 million), partially offset by an increase in cash operating expenses ($104 million).

Net cash used in investing activities of $3,524 million for the first six months of 2019 increased by $434 million compared to the same period of 2018 due to an increase in additions to oil and gas properties ($466 million) and an unfavorable change in components of working capital associated with investing activities ($5 million), partially offset by a decrease in additions to other property, plant and equipment ($28 million) and an increase in proceeds from the sale of assets ($9 million).

Net cash used in financing activities of $1,166 million for the first six months of 2019 included repayments of long-term debt ($900 million) and cash dividend payments ($255 million). Net cash used in financing activities of $228 million for the first six months of 2018 included cash dividend payments ($204 million) and purchases of treasury stock in connection with stock compensation plans ($32 million).

Total Expenditures. For the year 2019, EOG's budget for exploration and development and other property, plant and equipment expenditures is approximately $6.1 billion to $6.5 billion, excluding acquisitions and non-cash transactions. The table below sets out components of total expenditures for the six-month periods ended June 30, 2019 and 2018 (in millions):
 
Six Months Ended 
 June 30,
 
2019
 
2018
Expenditure Category
 
 
 
Capital
 
 
 
Exploration and Development Drilling
$
2,692

 
$
2,503

Facilities
338

 
340

Leasehold Acquisitions (1)
145

 
172

Property Acquisitions (2)
322

 
37

Capitalized Interest
18

 
11

Subtotal
3,515

 
3,063

Exploration Costs
69

 
82

Dry Hole Costs
4

 
5

Exploration and Development Expenditures
3,588

 
3,150

Asset Retirement Costs
60

 
31

Total Exploration and Development Expenditures
3,648

 
3,181

Other Property, Plant and Equipment (3)
117

 
193

Total Expenditures
$
3,765

 
$
3,374

 
(1)
Leasehold acquisitions included $54 million and $60 million for the six-month periods ended June 30, 2019 and 2018, respectively, related to non-cash property exchanges.
(2)
Property acquisitions included $18 million and $23 million for the six-month periods ended June 30, 2019 and 2018, respectively, related to non-cash property exchanges.
(3)
Other property, plant and equipment included $48 million of non-cash additions for the six-month period ended June 30, 2018 made in connection with a finance lease transaction in the Permian Basin.
    

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Exploration and development expenditures of $3,588 million for the first six months of 2019 were $438 million higher than the same period of 2018 primarily due to increased property acquisitions ($285 million) and increased exploration and drilling expenditures in the United States ($181 million), partially offset by decreased leasehold acquisitions ($27 million). Exploration and development expenditures for the first six months of 2019 of $3,588 million consisted of $3,010 million in development drilling and facilities, $322 million in property acquisitions, $238 million in exploration and $18 million in capitalized interest. Exploration and development expenditures for the first six months of 2018 of $3,150 million consisted of $2,839 million in development drilling and facilities, $263 million in exploration, $37 million in property acquisitions and $11 million in capitalized interest.

The level of exploration and development expenditures, including acquisitions, will vary in future periods depending on energy market conditions and other economic factors. EOG has significant flexibility with respect to financing alternatives and the ability to adjust its exploration and development expenditure budget as circumstances warrant. While EOG has certain continuing commitments associated with expenditure plans related to its operations, such commitments are not expected to be material when considered in relation to the total financial capacity of EOG.

Commodity Derivative Transactions. As more fully discussed in Note 12 to the Consolidated Financial Statements included in EOG's Annual Report on Form 10-K for the year ended December 31, 2018, filed on February 26, 2019, EOG engages in price risk management activities from time to time. These activities are intended to manage EOG's exposure to fluctuations in commodity prices for crude oil and natural gas. EOG utilizes financial commodity derivative instruments, primarily price swap, option, swaption, collar and basis swap contracts, as a means to manage this price risk. EOG has not designated any of its financial commodity derivative contracts as accounting hedges and, accordingly, accounts for financial commodity derivative contracts using the mark-to-market accounting method. Under this accounting method, changes in the fair value of outstanding financial instruments are recognized as gains or losses in the period of change and are recorded as Gains (Losses) on Mark-to-Market Commodity Derivative Contracts on the Condensed Consolidated Statements of Income and Comprehensive Income. The related cash flow impact is reflected in Cash Flows from Operating Activities on the Condensed Consolidated Statements of Cash Flows.

The total fair value of EOG's commodity derivative contracts was reflected on the Condensed Consolidated Balance Sheets at June 30, 2019, as a net asset of $135 million.

Prices received by EOG for its crude oil production generally vary from NYMEX West Texas Intermediate prices due to adjustments for delivery location (basis) and other factors. EOG has entered into crude oil basis swap contracts in order to fix the differential between pricing in Midland, Texas, and Cushing, Oklahoma (Midland Differential). Presented below is a comprehensive summary of EOG's Midland Differential basis swap contracts through July 29, 2019. The weighted average price differential expressed in dollars per barrel ($/Bbl) represents the amount of reduction to Cushing, Oklahoma, prices for the notional volumes expressed in barrels per day (Bbld) covered by the basis swap contracts.
 
Midland Differential Basis Swap Contracts
 
 
 
Volume (Bbld)
 
Weighted Average Price Differential
($/Bbl)
 
 
 
2019
 
 
 
 
 
January 1, 2019 through August 31, 2019 (closed)
 
20,000

 
$
1.075

 
September 1, 2019 through December 31, 2019
 
20,000

 
1.075


EOG has also entered into crude oil basis swap contracts in order to fix the differential between pricing in the U.S. Gulf Coast and Cushing, Oklahoma (Gulf Coast Differential). Presented below is a comprehensive summary of EOG's Gulf Coast Differential basis swap contracts through July 29, 2019. The weighted average price differential expressed in $/Bbl represents the amount of addition to Cushing, Oklahoma, prices for the notional volumes expressed in Bbld covered by the basis swap contracts.
 
Gulf Coast Differential Basis Swap Contracts
 
 
 
Volume (Bbld)
 
Weighted Average Price Differential
($/Bbl)
 
 
 
2019
 
 
 
 
 
January 1, 2019 through August 31, 2019 (closed)
 
13,000

 
$
5.572

 
September 1, 2019 through December 31, 2019
 
13,000

 
5.572


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Presented below is a comprehensive summary of EOG's crude oil price swap contracts through July 29, 2019, with notional volumes expressed in Bbld and prices expressed in $/Bbl.
Crude Oil Price Swap Contracts
 
 
Volume (Bbld)
 
Weighted Average Price ($/Bbl)
2019
 
 
 
 
April 2019 (closed)
 
25,000

 
$
60.00

May 1, 2019 through June 30, 2019 (closed)
 
150,000

 
62.50

July 1, 2019 through December 31, 2019
 
150,000

 
62.50


Presented below is a comprehensive summary of EOG's natural gas price swap contracts through July 29, 2019, with notional volumes expressed in million British thermal units (MMBtu) per day (MMBtud) and prices expressed in dollars per MMBtu ($/MMBtu).
Natural Gas Price Swap Contracts
 
 
Volume (MMBtud)
 
Weighted
Average Price
($/MMBtu)
2019
 
 
 
 
April 1, 2019 through August 31, 2019 (closed)
 
250,000

 
$
2.90

September 1, 2019 through October 31, 2019
 
250,000

 
2.90




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Information Regarding Forward-Looking Statements

This Quarterly Report on Form 10-Q includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical facts, including, among others, statements and projections regarding EOG's future financial position, operations, performance, business strategy, returns, budgets, reserves, levels of production, capital expenditures, costs and asset sales, statements regarding future commodity prices and statements regarding the plans and objectives of EOG's management for future operations, are forward-looking statements. EOG typically uses words such as "expect," "anticipate," "estimate," "project," "strategy," "intend," "plan," "target," "aims," "goal," "may," "will," "should" and "believe" or the negative of those terms or other variations or comparable terminology to identify its forward-looking statements. In particular, statements, express or implied, concerning EOG's future operating results and returns or EOG's ability to replace or increase reserves, increase production, generate returns, replace or increase drilling locations, reduce or otherwise control operating costs and capital expenditures, generate cash flows, pay down or refinance indebtedness or pay and/or increase dividends are forward-looking statements. Forward-looking statements are not guarantees of performance. Although EOG believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct. Moreover, EOG's forward-looking statements may be affected by known, unknown or currently unforeseen risks, events or circumstances that may be outside EOG's control. Important factors that could cause EOG's actual results to differ materially from the expectations reflected in EOG's forward-looking statements include, among others:

the timing, extent and duration of changes in prices for, supplies of, and demand for, crude oil and condensate, natural gas liquids, natural gas and related commodities;
the extent to which EOG is successful in its efforts to acquire or discover additional reserves;
the extent to which EOG is successful in its efforts to economically develop its acreage in, produce reserves and achieve anticipated production levels from, and maximize reserve recovery from, its existing and future crude oil and natural gas exploration and development projects;
the extent to which EOG is successful in its efforts to market its crude oil and condensate, natural gas liquids, natural gas and related commodity production;
the availability, proximity and capacity of, and costs associated with, appropriate gathering, processing, compression, storage, transportation and refining facilities;
the availability, cost, terms and timing of issuance or execution of, and competition for, mineral licenses and leases and governmental and other permits and rights-of-way, and EOG’s ability to retain mineral licenses and leases;
the impact of, and changes in, government policies, laws and regulations, including tax laws and regulations; climate change and other environmental, health and safety laws and regulations relating to air emissions, disposal of produced water, drilling fluids and other wastes, hydraulic fracturing and access to and use of water; laws and regulations imposing conditions or restrictions on drilling and completion operations and on the transportation of crude oil and natural gas; laws and regulations with respect to derivatives and hedging activities; and laws and regulations with respect to the import and export of crude oil, natural gas and related commodities;
EOG's ability to effectively integrate acquired crude oil and natural gas properties into its operations, fully identify existing and potential problems with respect to such properties and accurately estimate reserves, production and costs with respect to such properties;
the extent to which EOG's third-party-operated crude oil and natural gas properties are operated successfully and economically;
competition in the oil and gas exploration and production industry for the acquisition of licenses, leases and properties, employees and other personnel, facilities, equipment, materials and services;
the availability and cost of employees and other personnel, facilities, equipment, materials (such as water and tubulars) and services;
the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise;
weather, including its impact on crude oil and natural gas demand, and weather-related delays in drilling and in the installation and operation (by EOG or third parties) of production, gathering, processing, refining, compression, storage and transportation facilities;
the ability of EOG's customers and other contractual counterparties to satisfy their obligations to EOG and, related thereto, to access the credit and capital markets to obtain financing needed to satisfy their obligations to EOG;
EOG's ability to access the commercial paper market and other credit and capital markets to obtain financing on terms it deems acceptable, if at all, and to otherwise satisfy its capital expenditure requirements;
the extent to which EOG is successful in its completion of planned asset dispositions;
the extent and effect of any hedging activities engaged in by EOG;

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the timing and extent of changes in foreign currency exchange rates, interest rates, inflation rates, global and domestic financial market conditions and global and domestic general economic conditions;
geopolitical factors and political conditions and developments around the world (such as the imposition of tariffs or trade or other economic sanctions, political instability and armed conflict), including in the areas in which EOG operates;
the use of competing energy sources and the development of alternative energy sources;
the extent to which EOG incurs uninsured losses and liabilities or losses and liabilities in excess of its insurance coverage;
acts of war and terrorism and responses to these acts;
physical, electronic and cybersecurity breaches; and
the other factors described under ITEM 1A, Risk Factors, on pages 13 through 22 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2018, and any updates to those factors set forth in EOG's subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K.

In light of these risks, uncertainties and assumptions, the events anticipated by EOG's forward-looking statements may not occur, and, if any of such events do, we may not have anticipated the timing of their occurrence or the duration or extent of their impact on our actual results. Accordingly, you should not place any undue reliance on any of EOG's forward-looking statements. EOG's forward-looking statements speak only as of the date made, and EOG undertakes no obligation, other than as required by applicable law, to update or revise its forward-looking statements, whether as a result of new information, subsequent events, anticipated or unanticipated circumstances or otherwise.



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PART I.  FINANCIAL INFORMATION


ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
EOG RESOURCES, INC.

EOG's exposure to commodity price risk, interest rate risk and foreign currency exchange rate risk is discussed in (i) the "Derivative Transactions," "Financing," "Foreign Currency Exchange Rate Risk" and "Outlook" sections of "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity" on pages 40 through 43 of EOG's Annual Report on Form 10-K for the year ended December 31, 2018, filed on February 26, 2019 (EOG's 2018 Annual Report); and (ii) Note 12, "Risk Management Activities," to EOG's Consolidated Financial Statements on pages F-29 through F-31 of EOG's 2018 Annual Report. There have been no material changes in this information. For additional information regarding EOG's financial commodity derivative contracts and physical commodity contracts, see (i) Note 12, "Risk Management Activities," to EOG's Condensed Consolidated Financial Statements in this Quarterly Report on Form 10-Q; (ii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Results of Operations - Operating Revenues" in this Quarterly Report on Form 10-Q; and (iii) "Management's Discussion and Analysis of Financial Condition and Results of Operations - Capital Resources and Liquidity - Commodity Derivative Transactions" in this Quarterly Report on Form 10-Q.


ITEM 4. CONTROLS AND PROCEDURES
EOG RESOURCES, INC.

Disclosure Controls and Procedures. EOG's management, with the participation of EOG's principal executive officer and principal financial officer, evaluated the effectiveness of EOG's disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) promulgated under the Securities Exchange Act of 1934, as amended (Exchange Act)) as of the end of the period covered by this Quarterly Report on Form 10-Q (Evaluation Date). Based on this evaluation, EOG's principal executive officer and principal financial officer have concluded that EOG's disclosure controls and procedures were effective as of the Evaluation Date in ensuring that information that is required to be disclosed in the reports EOG files or furnishes under the Exchange Act is (i) recorded, processed, summarized and reported within the time periods specified in the United States Securities and Exchange Commission's rules and forms and (ii) accumulated and communicated to EOG's management, as appropriate, to allow timely decisions regarding required disclosure.

Internal Control Over Financial Reporting. There were no changes in EOG's internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f) promulgated under the Exchange Act) that occurred during the quarterly period covered by this Quarterly Report on Form 10-Q that have materially affected, or are reasonably likely to materially affect, EOG's internal control over financial reporting.




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PART II. OTHER INFORMATION

EOG RESOURCES, INC.

ITEM 1.    LEGAL PROCEEDINGS
 
See Part I, Item 1, Note 8 to Condensed Consolidated Financial Statements, which is incorporated herein by reference.

ITEM 2.    UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

The following table sets forth, for the periods indicated, EOG's share repurchase activity:
Period
 
Total
Number of
Shares Purchased (1)
 
Average
Price Paid Per Share
 
Total Number of
Shares Purchased as
Part of Publicly
Announced Plans or Programs
 
Maximum Number
of Shares that May Yet
Be Purchased Under The Plans or Programs (2)
 
 
 
 
 
 
 
 
 
 
 
 
 
April 1, 2019 - April 30, 2019
 
12,203

 
$
99.42

 

 
6,386,200

May 1, 2019 - May 31, 2019
 
4,262

 
90.31

 

 
6,386,200

June 1, 2019 - June 30, 2019
 
6,093

 
88.60

 

 
6,386,200

Total
 
22,558

 
94.77

 

 
 
 
(1)
The 22,558 total shares for the quarter ended June 30, 2019, consist solely of shares that were withheld by or returned to EOG (i) in satisfaction of tax withholding obligations that arose upon the exercise of employee stock options or stock-settled stock appreciation rights or the vesting of restricted stock, restricted stock unit, or performance unit grants or (ii) in payment of the exercise price of employee stock options. These shares do not count against the 10 million aggregate share repurchase authorization by EOG's Board of Directors (Board) discussed below.
(2)
In September 2001, the Board authorized the repurchase of up to 10 million shares of EOG's common stock. During the second quarter of 2019, EOG did not repurchase any shares under the Board-authorized repurchase program.

ITEM 4.    MINE SAFETY DISCLOSURES

The information concerning mine safety violations and other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K (17 CFR 229.104) is included in Exhibit 95 to this Quarterly Report on Form 10-Q.


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ITEM 6.  EXHIBITS
Exhibit No.  
 
Description
 
 
 
    10.1
-
 
 
 
    10.2
-
 
 
 
    31.1
-
 
 
 
    31.2
-
 
 
 
    32.1
-
 
 
 
    32.2
-
 
 
 
    95
-
 
 
 
  101.INS
-
XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
 
 
 
*101.SCH
-
XBRL Schema Document.
 
 
 
*101.CAL
-
XBRL Calculation Linkbase Document.
 
 
 
*101.DEF
-
XBRL Definition Linkbase Document.
 
 
 
*101.LAB
-
XBRL Label Linkbase Document.
 
 
 
*101.PRE
-
XBRL Presentation Linkbase Document.

*Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) the Condensed Consolidated Statements of Income and Comprehensive Income - Three and Six Months Ended June 30, 2019 and 2018, (ii) the Condensed Consolidated Balance Sheets - June 30, 2019 and December 31, 2018, (iii) the Condensed Consolidated Statements of Stockholders' Equity - Six Months Ended June 30, 2019 and 2018, (iv) the Condensed Consolidated Statements of Cash Flows - Six Months Ended June 30, 2019 and 2018 and (v) the Notes to Condensed Consolidated Financial Statements.

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SIGNATURES



Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



 
 
 
EOG RESOURCES, INC.
 
 
 
(Registrant)
 
 
 
 
 
 
 
 
 
 
 
 
Date:
August 1, 2019
By:
/s/ TIMOTHY K. DRIGGERS
Timothy K. Driggers
Executive Vice President and Chief Financial Officer
(Principal Financial Officer and Duly Authorized Officer)

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