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EOG Resources Announces Outstanding Third Quarter 2018 Results

 

HOUSTON, Nov. 1, 2018 /PRNewswire/ -- 

  • Exceeds High End of Oil and NGL Production Targets
  • Generates Significant Free Cash Flow
  • Achieves Improved Well Performance and Lower Costs in Delaware Basin
  • Secures 2019 Services at Competitive Prices and Raises 2018 Capex Guidance Range to $5.8-$6.0 Billion
  • Targets Further Well Cost Reductions in 2019

EOG Resources, Inc. (EOG) today reported third quarter 2018 net income of $1.2 billion, or $2.05 per share. This compares to third quarter 2017 net income of $101 million, or $0.17 per share. Net cash from operating activities in the third quarter 2018 was $2.2 billion.

Adjusted non-GAAP net income for the third quarter 2018 was $1.0 billion, or $1.75 per share, compared to adjusted non-GAAP net income of $111 million, or $0.19 per share, for the same prior year period. Please refer to the attached tables for the reconciliation of non-GAAP measures to GAAP measures.

Third Quarter Review
EOG set a company record and exceeded the high end of its target range for crude oil volumes in the third quarter 2018 by producing 415,000 barrels of oil per day (Bopd), an increase of 27 percent compared to the same prior year period. Natural gas liquids (NGL) production increased 46 percent while natural gas volumes grew 13 percent, contributing to total company production growth of 25 percent.

Per-unit operating expenses declined during the third quarter 2018 compared to the same prior year period. General and administrative expenses fell 20 percent, transportation costs declined 15 percent and depreciation, depletion and amortization expenses fell 13 percent, all on a per-unit basis.

EOG generated $2.3 billion of discretionary cash flow in the third quarter 2018. After considering exploration and development expenditures of $1.7 billion and dividend payments of $107 million, EOG produced free cash flow during the third quarter of $503 million. Please refer to the attached tables for the reconciliation of non-GAAP measures to GAAP measures.

"EOG delivered a compelling combination of production growth, high returns and free cash flow in the third quarter 2018 due to disciplined capital allocation. These results demonstrate the value of EOG's sustainable business model," said William R. "Bill" Thomas, Chairman and Chief Executive Officer. "EOG is making significant progress lowering costs and improving well performance. Our culture of innovation, experimentation and entrepreneurship combined with our ability to capture and quickly analyze real-time data and make rapid changes in the field are resulting in significant performance improvements company-wide."

Updated 2018 Outlook
EOG has raised its target for full-year 2018 crude oil production growth to 19 percent. To maintain operational continuity into 2019, the company elected to retain high performing service providers for the remainder of 2018. Approximately 65 percent of its anticipated 2019 services have been secured at competitive pricing. As a result, EOG increased its 2018 exploration and development expenditure forecast to $5.8 to $6.0 billion, excluding acquisitions and non-cash transactions. The company is on track to reduce total well costs by five percent in 2018, and targets further well cost reductions in 2019. EOG now expects to complete approximately 720 net wells in 2018, an increase of 20 net wells from its prior forecast.

"We are positioning EOG to carry the operating efficiencies gained this year into 2019. We secured a significant proportion of our service costs, which along with disciplined execution will help further reduce well costs and improve returns," Thomas continued. "With a deep inventory of premium drilling locations across multiple plays, EOG will continue to allocate capital to the highest return areas while maintaining a disciplined operating pace. EOG is well positioned to continue delivering its unique combination of high returns, disciplined growth and strong free cash flow for years to come."

Operating Highlights
EOG's South Texas Eagle Ford remained the most active area of the company in the third quarter 2018. EOG now expects to complete 290 net wells in 2018, an addition of 20 net wells from the prior forecast. EOG also continued to delineate the South Texas Austin Chalk, completing 14 wells in the third quarter.

In the Delaware Basin, EOG made significant progress on well cost reductions and optimizing targeting and development patterns. The company increased the number of wells developed in a single package and drilled longer laterals. Packages of four wells or more accounted for 87 percent of the wells brought on line in the third quarter. EOG also made additional progress towards its cost reduction goals. Drilling speeds and the pace of completion operations increased markedly during the quarter. In addition, the company now supplies nearly all of its Delaware Basin sand from local sources and has further increased its use of low-cost recycled water.

EOG continued development of its premium play in the Eastern Anadarko Basin Woodford Oil Window. EOG is testing spacing patterns and various targets across the play. The company completed 11 wells in the third quarter. EOG completed a package of four wells spaced 660 feet apart late in the second quarter. The Ted 2326 #1H-#4H were completed with an average treated lateral length of 10,000 feet per well and average 30-day initial production rates per well of 800 barrels of oil equivalent per day, or 660 Bopd, 90 barrels per day of NGLs and 0.3 million cubic feet per day of natural gas. These low-decline wells support our initial spacing assessment of 660 feet. EOG is also making significant progress reducing well costs in this new play. Recent wells have been brought to production at costs at or below the company's $7.8 million target.

EOG continued development of its premium plays across the Rocky Mountain region. The company brought 20 wells on line in the Powder River Basin during the third quarter 2018, including 13 wells from the Turner formation. In the Wyoming DJ Basin, EOG began production from 25 wells in the third quarter 2018. EOG completed 19 wells in the Williston Basin during the third quarter as part of its seasonal development program.

Financial Review
At September 30, 2018, EOG's total debt outstanding was $6.4 billion for a debt-to-total capitalization ratio of 26 percent. Considering cash on the balance sheet at the end of the third quarter, EOG's net debt was $5.2 billion for a net debt-to-total capitalization ratio of 22 percent. For a reconciliation of non-GAAP measures to GAAP measures, please refer to the attached tables.

EOG reached an agreement to divest all of its U.K. operations. Closing is anticipated in the fourth quarter 2018.

During the third quarter ended September 30, 2018, EOG entered into additional crude oil derivative contracts. A comprehensive summary of EOG's crude oil and natural gas derivative contracts is provided in the attached tables.  

Third Quarter 2018 Results Webcast
Friday, November 2, 2018, 9:00 a.m. Central time (10:00 a.m. Eastern time)
Webcast will be available on EOG website for one year.
http://investors.eogresources.com/Investors

About EOG
EOG Resources, Inc. (NYSE: EOG) is one of the largest crude oil and natural gas exploration and production companies in the United States with proved reserves in the United States, Trinidad, the United Kingdom and China. To learn more visit www.eogresources.com.

Investor Contacts
David Streit  713-571-4902
Neel Panchal  713-571-4884
John Wagner  713-571-4404

Media and Investor Contact
Kimberly Ehmer  713-571-4676

This press release 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, 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, reduce or otherwise control operating and capital costs, generate income or cash flows, pay down 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.  Furthermore, EOG has presented or referenced herein or in its accompanying disclosures certain forward-looking, non-GAAP financial measures, such as free cash flow and discretionary cash flow, and certain related estimates regarding future performance, results and financial position.  These forward-looking measures and estimates are intended to be illustrative only and are not intended to reflect the results that EOG will necessarily achieve for the period(s) presented.  EOG's actual results may differ materially from the measure and estimates presented or referenced herein.  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, 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; 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 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 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;
  • 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;
  • political conditions and developments around the world (such as 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 cyber security breaches; and
  • the other factors described under ITEM 1A, Risk Factors, on pages 14 through 23 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2017, 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 and 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.

The United States Securities and Exchange Commission (SEC) permits oil and gas companies, in their filings with the SEC, to disclose not only "proved" reserves (i.e., quantities of oil and gas that are estimated to be recoverable with a high degree of confidence), but also "probable" reserves (i.e., quantities of oil and gas that are as likely as not to be recovered) as well as "possible" reserves (i.e., additional quantities of oil and gas that might be recovered, but with a lower probability than probable reserves).  Statements of reserves are only estimates and may not correspond to the ultimate quantities of oil and gas recovered. Any reserve estimates provided in this press release that are not specifically designated as being estimates of proved reserves may include "potential" reserves and/or other estimated reserves not necessarily calculated in accordance with, or contemplated by, the SEC's latest reserve reporting guidelines.  Investors are urged to consider closely the disclosure in EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2017, available from EOG at P.O. Box 4362, Houston, Texas 77210-4362 (Attn: Investor Relations). You can also obtain this report from the SEC by calling 1-800-SEC-0330 or from the SEC's website at www.sec.gov.  In addition, reconciliation and calculation schedules for non-GAAP financial measures can be found on the EOG website at www.eogresources.com.

 

EOG RESOURCES, INC.

Financial Report

(Unaudited; in millions, except per share data)

                       
 

Three Months Ended

 

Nine Months Ended

 

September 30,

 

September 30,

 

2018

 

2017

 

2018

 

2017

                       

Operating Revenues and Other

$

4,781.6

 

$

2,644.8

 

$

12,700.9

 

$

7,867.9

Net Income 

$

1,191.0

 

$

100.5

 

$

2,526.3

 

$

152.1

Net Income Per Share 

                     

        Basic

$

2.06

 

$

0.17

 

$

4.38

 

$

0.26

        Diluted

$

2.05

 

$

0.17

 

$

4.35

 

$

0.26

Average Number of Common Shares

                     

        Basic

 

577.3

   

574.8

   

576.4

   

574.4

        Diluted

 

581.6

   

578.7

   

580.4

   

578.5

                       
                       

Summary Income Statements

(Unaudited; in thousands, except per share data)

                       
 

Three Months Ended

 

Nine Months Ended

 

September 30,

 

September 30,

 

2018

 

2017

 

2018

 

2017

Operating Revenues and Other

             

        Crude Oil and Condensate

$

2,655,278

 

$

1,451,410

 

$

7,134,114

 

$

4,326,925

        Natural Gas Liquids

 

353,704

   

180,038

   

861,473

   

480,389

        Natural Gas

 

311,713

   

220,402

   

912,324

   

675,012

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

 

(52,081)

   

(6,606)

   

(297,735)

   

64,860

        Gathering, Processing and Marketing

 

1,360,992

   

784,368

   

3,899,250

   

2,289,702

        Gains (Losses) on Asset Dispositions, Net

 

115,944

   

(8,202)

   

94,658

   

(33,876)

        Other, Net

 

36,074

   

23,434

   

96,779

   

64,869

               Total

 

4,781,624

   

2,644,844

   

12,700,863

   

7,867,881

Operating Expenses

                     

        Lease and Well

 

321,568

   

251,943

   

936,236

   

762,906

        Transportation Costs

 

196,027

   

183,565

   

550,781

   

548,635

        Gathering and Processing Costs

 

114,063

   

32,590

   

324,577

   

105,480

        Exploration Costs

 

32,823

   

30,796

   

115,137

   

122,401

        Dry Hole Costs

 

358

   

50

   

5,260

   

77

        Impairments 

 

44,617

   

53,677

   

160,934

   

325,798

        Marketing Costs

 

1,326,974

   

793,536

   

3,853,827

   

2,320,671

        Depreciation, Depletion and Amortization

 

918,180

   

846,222

   

2,515,445

   

2,527,642

        General and Administrative

 

111,284

   

111,717

   

310,065

   

317,462

        Taxes Other Than Income

 

209,043

   

125,912

   

582,395

   

386,319

               Total

 

3,274,937

   

2,430,008

   

9,354,657

   

7,417,391

                       

Operating Income 

 

1,506,687

   

214,836

   

3,346,206

   

450,490

                       

Other Income (Expense), Net

 

3,308

   

226

   

(4,516)

   

8,349

                       

Income Before Interest Expense and Income Taxes

 

1,509,995

   

215,062

   

3,341,690

   

458,839

                       

Interest Expense, Net

 

63,632

   

69,082

   

189,032

   

211,010

                       

Income Before Income Taxes

 

1,446,363

   

145,980

   

3,152,658

   

247,829

                       

Income Tax Provision

 

255,411

   

45,439

   

626,386

   

95,718

                       

Net Income 

$

1,190,952

 

$

100,541

 

$

2,526,272

 

$

152,111

                       

Dividends Declared per Common Share

$

0.2200

 

$

0.1675

 

$

0.5900

 

$

0.5025

                       

EOG RESOURCES, INC.

Operating Highlights

(Unaudited)

                       
 

Three Months Ended

 

Nine Months Ended

 

September 30,

 

September 30,

 

2018

 

2017

 

2018

 

2017

Wellhead Volumes and Prices

     

Crude Oil and Condensate Volumes (MBbld) (A)

     

      United States

 

409.2

   

327.1

   

382.9

   

324.3

      Trinidad

 

0.8

   

0.8

   

0.8

   

0.8

      Other International (B)

 

5.0

   

-

   

4.1

   

1.0

            Total

 

415.0

   

327.9

   

387.8

   

326.1

                       

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

                     

      United States

$

69.53

 

$

48.06

 

$

67.35

 

$

48.61

      Trinidad

 

61.71

   

39.42

   

58.91

   

40.24

      Other International (B)

 

72.81

   

-

   

71.83

   

51.55

            Composite

 

69.55

   

48.11

   

67.38

   

48.60

                       

Natural Gas Liquids Volumes (MBbld) (A)

                     

      United States

 

127.8

   

87.4

   

113.9

   

84.3

      Other International (B)

 

-

   

-

   

-

   

-

            Total

 

127.8

   

87.4

   

113.9

   

84.3

                       

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

                     

      United States

$

30.09

 

$

22.38

 

$

27.71

 

$

20.87

      Other International (B)

 

-

   

-

   

-

   

-

            Composite

 

30.09

   

22.38

   

27.71

   

20.87

                       

Natural Gas Volumes (MMcfd) (A)

                     

      United States

 

948

   

748

   

905

   

744

      Trinidad

 

260

   

323

   

278

   

317

      Other International (B)

 

28

   

25

   

31

   

22

            Total

 

1,236

   

1,096

   

1,214

   

1,083

                       

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

                     

      United States

$

2.67

 

$

2.20

 

$

2.66

 

$

2.22

      Trinidad

 

2.88

   

2.04

   

2.91

   

2.33

      Other International (B)

 

3.83

   

3.74

   

4.10

   

3.72

            Composite

 

2.74

(D)

 

2.19

   

2.75

(D)

 

2.28

                       

Crude Oil Equivalent Volumes (MBoed) (E)

                     

      United States 

 

695.0

   

539.2

   

647.6

   

532.6

      Trinidad

 

44.1

   

54.6

   

47.2

   

53.6

      Other International (B)

 

9.7

   

4.3

   

9.2

   

4.8

            Total

 

748.8

   

598.1

   

704.0

   

591.0

                       

Total MMBoe (E)

 

68.9

   

55.0

   

192.2

   

161.3

 

(A) Thousand barrels per day or million cubic feet per day, as applicable.

(B) Other International includes EOG's United Kingdom, China and Canada operations.

(C) 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 in EOG's Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2018).

(D) Includes positive revenue adjustments of $0.49 per Mcf and $0.43 per Mcf for the three and nine months ended September 30, 2018, respectively, related to the adoption of ASU 2014-09, "Revenue From Contracts with Customers" (ASU 2014-09). (see Note 1 to the Condensed Consolidated Financial Statements in EOG's Quarterly Report on Form 10-Q for the quarterly period ended September 30, 2018).  In connection with the adoption of ASU 2014-09, EOG presents natural gas processing fees for certain processing and marketing agreements as Gathering and Processing Costs, instead of as a deduction to Revenues.

(E) 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.

 

EOG RESOURCES, INC.

Summary Balance Sheets

(Unaudited; in thousands, except share data)

           
 

September 30,

 

December 31,

 

2018

 

2017

ASSETS

Current Assets

         

     Cash and Cash Equivalents

$

1,274,132

 

$

834,228

     Accounts Receivable, Net

 

2,151,247

   

1,597,494

     Inventories

 

766,964

   

483,865

     Assets from Price Risk Management Activities

 

1,569

   

7,699

     Income Taxes Receivable

 

320,938

   

113,357

     Other

 

302,242

   

242,465

            Total

 

4,817,092

   

3,279,108

           

Property, Plant and Equipment

         

     Oil and Gas Properties (Successful Efforts Method)

 

56,799,237

   

52,555,741

     Other Property, Plant and Equipment

 

4,191,958

   

3,960,759

            Total Property, Plant and Equipment

 

60,991,195

   

56,516,500

     Less:  Accumulated Depreciation, Depletion and Amortization

 

(33,043,454)

   

(30,851,463)

            Total Property, Plant and Equipment, Net

 

27,947,741

   

25,665,037

Deferred Income Taxes

 

16,880

   

17,506

Other Assets

 

856,023

   

871,427

Total Assets

$

33,637,736

 

$

29,833,078

           

LIABILITIES AND STOCKHOLDERS' EQUITY

Current Liabilities

         

     Accounts Payable

$

2,435,773

 

$

1,847,131

     Accrued Taxes Payable

 

249,234

   

148,874

     Dividends Payable

 

126,829

   

96,410

     Liabilities from Price Risk Management Activities

 

132,618

   

50,429

     Current Portion of Long-Term Debt

 

1,262,874

   

356,235

     Other

 

217,819

   

226,463

            Total

 

4,425,147

   

2,725,542

           
           

Long-Term Debt

 

5,171,949

   

6,030,836

Other Liabilities

 

1,302,249

   

1,275,213

Deferred Income Taxes

 

4,199,921

   

3,518,214

Commitments and Contingencies

         
           

Stockholders' Equity

         

     Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and
        580,308,937 Shares Issued at September 30, 2018 and 578,827,768
        Shares Issued at December 31, 2017  

 

205,803

   

205,788

     Additional Paid in Capital

 

5,626,259

   

5,536,547

     Accumulated Other Comprehensive Loss

 

(19,458)

   

(19,297)

     Retained Earnings

 

12,778,104

   

10,593,533

     Common Stock Held in Treasury, 478,042 Shares at September 30, 2018
        and 350,961 Shares at December 31, 2017

 

(52,238)

   

(33,298)

            Total Stockholders' Equity

 

18,538,470

   

16,283,273

Total Liabilities and Stockholders' Equity

$

33,637,736

 

$

29,833,078

 

EOG RESOURCES, INC.

Summary Statements of Cash Flows

(Unaudited; in thousands)

           
 

Nine Months Ended

 

September 30,

 

2018

 

2017

Cash Flows from Operating Activities

         

Reconciliation of Net Income to Net Cash Provided by Operating Activities:

         

     Net Income

$

2,526,272

 

$

152,111

     Items Not Requiring (Providing) Cash

         

            Depreciation, Depletion and Amortization

 

2,515,445

   

2,527,642

            Impairments 

 

160,934

   

325,798

            Stock-Based Compensation Expenses

 

116,290

   

101,537

            Deferred Income Taxes

 

681,702

   

114,850

            (Gains) Losses on Asset Dispositions, Net

 

(94,658)

   

33,876

            Other, Net

 

15,314

   

(4,514)

     Dry Hole Costs

 

5,260

   

77

     Mark-to-Market Commodity Derivative Contracts

         

            Total (Gains) Losses

 

297,735

   

(64,860)

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

 

(180,228)

   

4,730

     Other, Net

 

1,652

   

270

     Changes in Components of Working Capital and Other Assets and Liabilities

         

            Accounts Receivable

 

(553,529)

   

(25,445)

            Inventories

 

(286,817)

   

(17,674)

            Accounts Payable

 

537,525

   

112,894

            Accrued Taxes Payable

 

(36,891)

   

(49,967)

            Other Assets

 

(103,334)

   

(83,940)

            Other Liabilities

 

(14,776)

   

(69,224)

     Changes in Components of Working Capital Associated with Investing and Financing
        Activities

 

95,484

   

(120,373)

Net Cash Provided by Operating Activities

 

5,683,380

   

2,937,788

           

Investing Cash Flows

         

     Additions to Oil and Gas Properties

 

(4,571,932)

   

(2,927,988)

     Additions to Other Property, Plant and Equipment

 

(202,384)

   

(139,558)

     Proceeds from Sales of Assets

 

11,582

   

191,593

     Other Investing Activities

 

(19,993)

   

-

     Changes in Components of Working Capital Associated with Investing Activities

 

(95,541)

   

120,469

Net Cash Used in Investing Activities

 

(4,878,268)

   

(2,755,484)

           

Financing Cash Flows

         

     Long-Term Debt Repayments

 

-

   

(600,000)

     Dividends Paid

 

(311,075)

   

(289,261)

     Treasury Stock Purchased

 

(58,558)

   

(50,374)

     Proceeds from Stock Options Exercised and Employee Stock Purchase Plan 

 

12,098

   

11,174

     Repayment of Capital Lease Obligation

 

(5,052)

   

(4,897)

     Changes in Components of Working Capital Associated with Financing Activities

 

57

   

(96)

Net Cash Used in Financing Activities

 

(362,530)

   

(933,454)

           

Effect of Exchange Rate Changes on Cash

 

(2,678)

   

(2,607)

           

Increase (Decrease) in Cash and Cash Equivalents

 

439,904

   

(753,757)

Cash and Cash Equivalents at Beginning of Period

 

834,228

   

1,599,895

Cash and Cash Equivalents at End of Period

$

1,274,132

 

$

846,138

 

EOG RESOURCES, INC.

Third Quarter 2018 Well Results by Play

(Unaudited)

                             
   

Wells Online

     

Initial Gross 30-Day Average Production Rate

   

Gross

 

Net

 

Lateral
Length
(ft)

 

Crude Oil and
Condensate
(Bbld) (A)

 

Natural Gas
Liquids
(Bbld) (A)

 

 Natural Gas
(MMcfd) (A)

 

Crude Oil
Equivalent
(Boed) (B)

Delaware Basin

                           

Wolfcamp

 

61

 

58

 

7,100

 

1,655

 

505

 

2.9

 

2,640

Bone Spring

 

4

 

4

 

5,200

 

1,135

 

270

 

1.6

 

1,675

Leonard

 

6

 

5

 

4,500

 

995

 

325

 

1.9

 

1,645

                             

South Texas Eagle Ford

 

90

 

83

 

7,300

 

1,235

 

155

 

0.9

 

1,540

                             

South Texas Austin Chalk

 

14

 

10

 

5,000

 

1,815

 

340

 

2.0

 

2,485

                             

Powder River Basin Turner

 

13

 

11

 

7,500

 

795

 

320

 

3.7

 

1,730

                             

DJ Basin Codell

 

25

 

19

 

10,100

 

915

 

105

 

0.4

 

1,090

                             

Williston Basin Bakken/Three Forks

 

19

 

12

 

9,400

 

1,135

 

130

 

0.6

 

1,370

                             

Anadarko Basin Woodford Oil Window

 

11

 

9

 

8,500

 

720

 

120

 

0.4

 

915

 

(A)  Barrels per day or million cubic feet per day, as applicable.

(B)  Barrels of oil equivalent per day; includes crude oil and condensate, natural gas liquids and natural gas.  Crude oil equivalent volumes are determined using a ratio of 1.0 barrel of crude oil and condensate or natural gas liquids to 6.0 thousand cubic feet of natural gas.

 

EOG RESOURCES, INC.

Quantitative Reconciliation of Adjusted Net Income (Non-GAAP)

To Net Income (GAAP)

(Unaudited; in thousands, except per share data)

                               
                               

The following chart adjusts the three-month and nine-month periods ended September 30, 2018 and 2017 reported Net Income (GAAP) to reflect actual net cash received from (payments for) settlements of commodity derivative contracts by eliminating the unrealized mark-to-market (gains) losses from these transactions, to eliminate the net (gains) losses on asset dispositions in 2018 and 2017, to add back impairment charges related to certain of EOG's assets in 2018 and 2017, to add back an early lease termination payment as the result of a legal settlement in 2017, to add back the transaction costs for the formation of a joint venture in 2017 and to eliminate certain adjustments in 2018 related to the 2017 U.S. tax reform.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported company earnings to match hedge realizations to production settlement months and make certain other adjustments to exclude non-recurring and certain other items.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.

                               
 

Three Months Ended 

 

Three Months Ended 

 

September 30, 2018

 

September 30, 2017

                               
     

Income

     

Diluted

     

Income

     

Diluted

 

Before

 

Tax

 

After

 

Earnings

 

Before

 

Tax

 

After

 

Earnings

 

Tax

 

Impact

 

Tax

 

per Share

 

Tax

 

Impact

 

Tax

 

per Share

Reported Net Income (GAAP)

$1,446,363

 

$(255,411)

 

$1,190,952

 

$      2.05

 

$145,980

 

$  (45,439)

 

$100,541

 

$      0.17

Adjustments:

                             

Losses on Mark-to-Market Commodity
   Derivative Contracts

52,081

 

(11,472)

 

40,609

 

0.07

 

6,606

 

(2,368)

 

4,238

 

0.01

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

(91,894)

 

20,241

 

(71,653)

 

(0.12)

 

2,139

 

(767)

 

1,372

 

-

Add:  Net (Gains) Losses on Asset Dispositions

(115,944)

 

28,934

 

(87,010)

 

(0.15)

 

8,202

 

(3,068)

 

5,134

 

0.01

Less:  Tax Reform Impact

-

 

(57,127)

 

(57,127)

 

(0.10)

 

-

 

-

 

-

 

-

Adjustments to Net Income 

(155,757)

 

(19,424)

 

(175,181)

 

(0.30)

 

16,947

 

(6,203)

 

10,744

 

0.02

                               

Adjusted Net Income (Non-GAAP)

$1,290,606

 

$(274,835)

 

$1,015,771

 

$      1.75

 

$162,927

 

$  (51,642)

 

$111,285

 

$      0.19

                               

Average Number of Common Shares (GAAP)

                             

       Basic

           

577,254

             

574,783

       Diluted

           

581,559

             

578,736

                               
                               
                               
 

Nine Months Ended 

 

Nine Months Ended 

 

September 30, 2018

 

September 30, 2017

                               
     

Income

     

Diluted

     

Income

     

Diluted

 

Before

 

Tax

 

After

 

Earnings

 

Before

 

Tax

 

After

 

Earnings

 

Tax

 

Impact

 

Tax

 

per Share

 

Tax

 

Impact

 

Tax

 

per Share

Reported Net Income (GAAP)

$3,152,658

 

$(626,386)

 

$2,526,272

 

$      4.35

 

$247,829

 

$  (95,718)

 

$152,111

 

$      0.26

Adjustments:

                             

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

297,735

 

(65,582)

 

232,153

 

0.40

 

(64,860)

 

23,249

 

(41,611)

 

(0.07)

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

(180,228)

 

39,699

 

(140,529)

 

(0.24)

 

4,730

 

(1,695)

 

3,035

 

0.01

Add:  Net (Gains) Losses on Asset Dispositions

(94,658)

 

24,235

 

(70,423)

 

(0.12)

 

33,876

 

(11,955)

 

21,921

 

0.04

Add:  Impairments

20,876

 

(4,598)

 

16,278

 

0.03

 

161,148

 

(57,764)

 

103,384

 

0.18

Add:  Legal Settlement - Early Lease Termination

-

 

-

 

-

 

-

 

10,202

 

(3,657)

 

6,545

 

0.01

Add:  Joint Venture Transaction Costs

-

 

-

 

-

 

-

 

3,056

 

(1,095)

 

1,961

 

-

Less:  Tax Reform Impact

-

 

(63,651)

 

(63,651)

 

(0.11)

 

-

 

-

 

-

 

-

Adjustments to Net Income

43,725

 

(69,897)

 

(26,172)

 

(0.04)

 

148,152

 

(52,917)

 

95,235

 

0.17

                               

Adjusted Net Income (Non-GAAP)

$3,196,383

 

$(696,283)

 

$2,500,100

 

$      4.31

 

$395,981

 

$(148,635)

 

$247,346

 

$      0.43

                               

Average Number of Common Shares (GAAP)

                             

       Basic

           

576,431

             

574,370

       Diluted

           

580,442

             

578,453

                               

 

EOG RESOURCES, INC.

Quantitative Reconciliation of Discretionary Cash Flow (Non-GAAP)

To Net Cash Provided By Operating Activities (GAAP)

(Unaudited; in thousands)

                         

Calculation of Free Cash Flow (Non-GAAP)

(Unaudited; in thousands)

             

The following chart reconciles the three-month and nine-month periods ended September 30, 2018 and 2017 Net Cash Provided by Operating Activities (GAAP) to Discretionary Cash Flow (Non-GAAP).  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust Net Cash Provided by Operating Activities for Exploration Costs (excluding Stock-Based Compensation Expenses), Other Non-Current Income Taxes - Net Receivable (Payable), Changes in Components of Working Capital and Other Assets and Liabilities, and Changes in Components of Working Capital Associated with Investing and Financing Activities.  EOG defines Free Cash Flow (Non-GAAP) for a given period as Discretionary Cash Flow (Non-GAAP) (see below reconciliation) for such period less the total cash capital expenditures excluding acquisitions incurred (Non-GAAP) during such period and dividends paid (GAAP) during such period, as is illustrated below for the three months and nine months ended September 30, 2018.  EOG management uses this information for comparative purposes within the industry.

                         
   

Three Months Ended

 

Nine Months Ended

   

September 30,

 

September 30,

   

2018

 

2017

 

2018

 

2017

                         

Net Cash Provided by Operating Activities (GAAP)

$

2,189,597

 

$

961,363

 

$

5,683,380

 

$

2,937,788

                         

Adjustments:

                       

Exploration Costs (excluding Stock-Based Compensation Expenses) 

   

27,032

   

26,132

   

96,716

   

106,268

Other Non-Current Income Taxes - Net Receivable (Payable)

   

(129,941)

   

-

   

62,421

   

-

Changes in Components of Working Capital and Other Assets

                       

and Liabilities

                       

Accounts Receivable

   

243,778

   

129,231

   

553,529

   

25,445

Inventories

   

94,598

   

11,545

   

286,817

   

17,674

Accounts Payable

   

(81,548)

   

(36,190)

   

(537,525)

   

(112,894)

Accrued Taxes Payable

   

59,426

   

10,843

   

36,891

   

49,967

Other Assets

   

40,491

   

22,851

   

103,334

   

83,940

Other Liabilities

   

(38,392)

   

2,355

   

14,776

   

69,224

Changes in Components of Working Capital Associated with 

                       

Investing and Financing Activities

   

(122,763)

   

41,235

   

(95,484)

   

120,373

             

Discretionary Cash Flow (Non-GAAP)

 

$

2,282,278

 

$

1,169,365

 

$

6,204,855

 

$

3,297,785

                         

Discretionary Cash Flow (Non-GAAP) - Percentage Increase

   

95%

         

88%

     
                         
                         

Discretionary Cash Flow (Non-GAAP)

 

$

2,282,278

       

$

6,204,855

     

Less:  

                       

Total Cash Expenditures Excluding Acquisitions (Non-GAAP)(a)

   

(1,671,922)

         

(4,869,951)

     

Dividends Paid (GAAP) 

   

(107,465)

         

(311,075)

     

Free Cash Flow (Non-GAAP)

 

$

502,891

       

$

1,023,829

     
                         
                         

(a) See below reconciliation of Total Expenditures (GAAP) to Total Cash Expenditures Excluding Acquisitions (Non-GAAP) for the three months and nine months ended September 30, 2018:

                         

Total Expenditures (GAAP)

 

$

1,828,348

       

$

5,201,921

     

Less:  

                       

          Asset Retirement Costs

   

(10,834)

         

(41,789)

     

          Non-Cash Expenditures of Other Property, Plant and Equipment

   

(1,257)

         

(48,937)

     

          Non-Cash Acquisition Costs of Unproved Properties

   

(101,821)

         

(161,823)

     

          Acquisition Costs of Proved Properties

   

(42,514)

         

(79,421)

     

Total Cash Expenditures Excluding Acquisitions (Non-GAAP) 

 

$

1,671,922

       

$

4,869,951

     

 

 

 

EOG RESOURCES, INC.

Quantitative Reconciliation of Adjusted Earnings Before Interest Expense, Net,

Income Taxes, Depreciation, Depletion and Amortization, Exploration Costs, 

Dry Hole Costs, Impairments and Additional Items (Adjusted EBITDAX)

 (Non-GAAP) to Net Income (GAAP)

(Unaudited; in thousands)

                       

The following chart adjusts the three-month and nine-month periods ended September 30, 2018 and 2017 reported Net Income (GAAP) to Earnings Before Interest Expense (Net), Income Taxes (Income Tax Provision), Depreciation, Depletion and Amortization, Exploration Costs, Dry Hole Costs and Impairments (EBITDAX) (Non-GAAP) and further adjusts such amount to reflect actual net cash received from (payments for) settlements of commodity derivative contracts by eliminating the unrealized mark-to-market (MTM) (gains) losses from these transactions and to eliminate the (gains) losses on asset dispositions (Net).  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported Net Income (GAAP) to add back Interest Expense (Net), Income Taxes (Income Tax Provision), Depreciation, Depletion and Amortization, Exploration Costs, Dry Hole Costs and Impairments and further adjust such amount to match realizations to production settlement months and make certain other adjustments to exclude non-recurring and certain other items.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.

                       
 

Three Months Ended

 

Nine Months Ended

 

September 30,

 

September 30,

 

2018

 

2017

 

2018

 

2017

                       

Net Income (GAAP)

$

1,190,952

 

$

100,541

 

$

2,526,272

 

$

152,111

                       

Adjustments:

                     

     Interest Expense, Net

 

63,632

   

69,082

   

189,032

   

211,010

     Income Tax Provision 

 

255,411

   

45,439

   

626,386

   

95,718

     Depreciation, Depletion and Amortization

 

918,180

   

846,222

   

2,515,445

   

2,527,642

     Exploration Costs

 

32,823

   

30,796

   

115,137

   

122,401

     Dry Hole Costs

 

358

   

50

   

5,260

   

77

     Impairments 

 

44,617

   

53,677

   

160,934

   

325,798

           EBITDAX (Non-GAAP)

 

2,505,973

   

1,145,807

   

6,138,466

   

3,434,757

     Total (Gains) Losses on MTM Commodity Derivative Contracts  

 

52,081

   

6,606

   

297,735

   

(64,860)

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

 

(91,894)

   

2,139

   

(180,228)

   

4,730

     (Gains) Losses on Asset Dispositions, Net

 

(115,944)

   

8,202

   

(94,658)

   

33,876

                       

Adjusted EBITDAX (Non-GAAP)

$

2,350,216

 

$

1,162,754

 

$

6,161,315

 

$

3,408,503

                       

Adjusted EBITDAX (Non-GAAP) - Percentage Increase

 

102%

         

81%

     

 

 

 

EOG RESOURCES, INC.

Quantitative Reconciliation of Net Debt (Non-GAAP) and Total

Capitalization (Non-GAAP) as Used in the Calculation of

The Net Debt-to-Total Capitalization Ratio (Non-GAAP) to

Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP)

(Unaudited; in millions, except ratio data)

           

The following chart reconciles Current and Long-Term Debt (GAAP) to Net Debt (Non-GAAP) and Total Capitalization (GAAP) to Total Capitalization (Non-GAAP), as used in the Net Debt-to-Total Capitalization ratio calculation.  A portion of the cash is associated with international subsidiaries; tax considerations may impact debt paydown.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize Net Debt and Total Capitalization (Non-GAAP) in their Net Debt-to-Total Capitalization ratio calculation.  EOG management uses this information for comparative purposes within the industry.

           
 

At

 

At

 

September 30,

 

December 31,

 

2018

 

2017

           

Total Stockholders' Equity - (a)

$

18,538

 

$

16,283

           

Current and Long-Term Debt (GAAP) - (b)

 

6,435

   

6,387

Less: Cash 

 

(1,274)

   

(834)

Net Debt (Non-GAAP) - (c)

 

5,161

   

5,553

           

Total Capitalization (GAAP) - (a) + (b)

$

24,973

 

$

22,670

           

Total Capitalization (Non-GAAP) - (a) + (c)

$

23,699

 

$

21,836

           

Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]

 

26%

   

28%

           

Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]

 

22%

   

25%

 

 

 

EOG RESOURCES, INC.

Crude Oil and Natural Gas Financial Commodity

Derivative Contracts

                       

EOG accounts for financial commodity derivative contracts using the mark-to-market accounting method.  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 October 26, 2018.  The weighted average price differential expressed in $/Bbl represents the amount of reduction to Cushing, Oklahoma, prices for the notional volumes expressed in Bbld covered by the basis swap contracts.

                       
                       

Midland Differential Basis Swap Contracts

                 

Weighted

                     

Average Price

                 

Volume

 

Differential

                 

(Bbld) 

 

($/Bbl) 

2018

                   

January 1, 2018 through November 30, 2018 (closed)

     

15,000

 

$           1.063

December 2018 

           

15,000

 

1.063

                       

2019

                   

January 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 October 26, 2018.  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

                 

Weighted

                     

Average Price

                 

Volume

 

Differential

                 

(Bbld) 

 

($/Bbl) 

2018

                   

January 1, 2018 through September 30, 2018 (closed)

     

37,000

 

$           3.818

October 1, 2018 through November 30, 2018 (closed)

     

52,000

 

3.911

December 2018 

           

52,000

 

3.911

                       

2019

                   

January 1, 2019 through December 31, 2019 

     

13,000

 

$           5.572

                       
                       

Presented below is a comprehensive summary of EOG's crude oil price swap contracts through October 26, 2018, with notional volumes expressed in Bbld and prices expressed in $/Bbl.  

                       
                       

Crude Oil Price Swap Contracts

                 

Weighted

                 

Volume

 

Average Price

                 

(Bbld) 

 

($/Bbl) 

2018

                   

January 1, 2018 through September 30, 2018 (closed)

     

134,000

 

$           60.04

October 1, 2018 through December 31, 2018

     

134,000

 

60.04

                       
                       

Presented below is a comprehensive summary of EOG's natural gas price swap contracts through October 26, 2018, with notional volumes expressed in MMBtud and prices expressed in $/MMBtu.

                       
                       

Natural Gas Price Swap Contracts

                     

Weighted

                 

Volume

 

Average Price

                 

(MMBtud)

 

($/MMBtu)

2018

                   

March 1, 2018 through October 31, 2018 (closed)

     

35,000

 

$             3.00

November 2018

           

35,000

 

3.00

                       
                       

EOG has sold call options which establish a ceiling price for the sale of notional volumes of natural gas as specified in the call option contracts.  The call options require that EOG pay the difference between the call option strike price and either the average or last business day NYMEX Henry Hub natural gas price for the contract month (Henry Hub Index Price) in the event the Henry Hub Index Price is above the call option strike price. 

                       

In addition, EOG has purchased put options which establish a floor price for the sale of notional volumes of natural gas as specified in the put option contracts.  The put options grant EOG the right to receive the difference between the put option strike price and the Henry Hub Index Price in the event the Henry Hub Index Price is below the put option strike price.  Presented below is a comprehensive summary of EOG's natural gas call and put option contracts through October 26, 2018, with notional volumes expressed in MMBtud and prices expressed in $/MMBtu.

                       
                       

Natural Gas Option Contracts

         

Call Options Sold

 

Put Options Purchased

             

Weighted

     

Weighted

         

Volume

 

Average Price

 

Volume

 

Average Price

         

(MMBtud) 

 

($/MMBtu) 

 

(MMBtud)

 

($/MMBtu)

2018

                   

March 1, 2018 through October 31, 2018 (closed)

   

120,000

 

$             3.38

 

96,000

 

$             2.94

November 2018 

   

120,000

 

3.38

 

96,000

 

2.94

                       
                       

Definitions

                   

Bbld

Barrels per day

                 

$/Bbl

Dollars per barrel

                 

MMBtud      

Million British thermal units per day

                 

$/MMBtu

Dollars per million British thermal units

                 

NYMEX

U.S. New York Mercantile Exchange

                 

 

 

 

EOG RESOURCES, INC.

Direct After-Tax Rate of Return (ATROR)

 

The calculation of our direct after-tax rate of return (ATROR) with respect to our capital expenditure program for a particular play or well is based on the estimated recoverable reserves ("net" to EOG's interest) for all wells in such play or such well (as the case may be), the estimated net present value (NPV) of the future net cash flows from such reserves (for which we utilize certain assumptions regarding future commodity prices and operating costs) and our direct net costs incurred in drilling or acquiring (as the case may be) such wells or well (as the case may be).  As such, our direct ATROR with respect to our capital expenditures for a particular play or well cannot be calculated from our consolidated financial statements. 

 
 

Direct ATROR

Based on Cash Flow and Time Value of Money

  - Estimated future commodity prices and operating costs

  - Costs incurred to drill, complete and equip a well, including facilities

Excludes Indirect Capital

  - Gathering and Processing and other Midstream

  - Land, Seismic, Geological and Geophysical

 

Payback ~12 Months on 100% Direct ATROR Wells

First Five Years ~1/2 Estimated Ultimate Recovery Produced but ~3/4 of NPV Captured

 
 

Return on Equity / Return on Capital Employed 

Based on GAAP Accrual Accounting

Includes All Indirect Capital and Growth Capital for Infrastructure

  - Eagle Ford, Bakken, Permian Facilities

  - Gathering and Processing

Includes Legacy Gas Capital and Capital from Mature Wells

 

EOG RESOURCES, INC.

Quantitative Reconciliation of After-Tax Net Interest Expense (Non-GAAP), Adjusted Net Income (Loss)

(Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP) as used in the Calculations of

Return on Capital Employed (Non-GAAP) and Return on Equity (Non-GAAP) to Net Interest Expense (GAAP),

Net Income (Loss) (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP), Respectively

(Unaudited; in millions, except ratio data)

                             

The following chart reconciles Net Interest Expense (GAAP), Net Income (Loss) (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Adjusted Net Income (Loss) (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) and Return on Equity (ROE) calculations.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Adjusted Net Income (Loss), Net Debt and Total Capitalization (Non-GAAP) in their ROCE and ROE calculations.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.

                             
   

2017

   

2016

   

2015

   

2014

   

2013

Return on Capital Employed (ROCE) (Non-GAAP)

                           
                             

Net Interest Expense (GAAP)

$

274

 

$

282

 

$

237

 

$

201

     

Tax Benefit Imputed (based on 35%) 

 

(96)

   

(99)

   

(83)

   

(70)

     

After-Tax Net Interest Expense (Non-GAAP) - (a) 

$

178

 

$

183

 

$

154

 

$

131

     
                             

Net Income (Loss) (GAAP) - (b)                                                   

$

2,583

 

$

(1,097)

 

$

(4,525)

 

$

2,915

     

Adjustments to Net Income (Loss), Net of Tax (See Accompanying Schedules)

 

(1,934)

 (a) 

 

204

 (b) 

 

4,559

 (c) 

 

(199)

 (d) 

   

Adjusted Net Income (Loss) (Non-GAAP) - (c)   

$

649

 

$

(893)

 

$

34

 

$

2,716

     
                             

Total Stockholders' Equity Before Retained Earnings Adjustment (GAAP) - (d)   

$

16,283

 

$

13,982

 

$

12,943

 

$

17,713

 

$

15,418

Less: Tax Reform Impact

 

(2,169)

   

-

   

-

   

-

   

-

Total Stockholders' Equity (Non-GAAP) - (e)   

$

14,114

 

$

13,982

 

$

12,943

 

$

17,713

 

$

15,418

                             

Average Total Stockholders' Equity (GAAP) * - (f)   

$

15,133

 

$

13,463

 

$

15,328

 

$

16,566

     
                             

Average Total Stockholders' Equity (Non-GAAP) * - (g)   

$

14,048

 

$

13,463

 

$

15,328

 

$

16,566

     
                             

Current and Long-Term Debt (GAAP) - (h) 

$

6,387

 

$

6,986

 

$

6,655

 

$

5,906

 

$

5,909

Less: Cash                                                       

 

(834)

   

(1,600)

   

(719)

   

(2,087)

   

(1,318)

Net Debt (Non-GAAP) - (i) 

$

5,553

 

$

5,386

 

$

5,936

 

$

3,819

 

$

4,591

                             

Total Capitalization (GAAP) - (d) + (h)  

$

22,670

 

$

20,968

 

$

19,598

 

$

23,619

 

$

21,327

                             

Total Capitalization (Non-GAAP) - (e) + (i) 

$

19,667

 

$

19,368

 

$

18,879

 

$

21,532

 

$

20,009

                             

Average Total Capitalization (Non-GAAP) * - (j)   

$

19,518

 

$

19,124

 

$

20,206

 

$

20,771

     
                             

ROCE (GAAP Net Income) - [(a) + (b)] / (j)       

 

14.1%

   

-4.8%

   

-21.6%

   

14.7%

     
                             

ROCE (Non-GAAP Adjusted Net Income) - [(a) + (c)] / (j)       

 

4.2%

   

-3.7%

   

0.9%

   

13.7%

     
                             

Return on Equity (ROE)

                           
                             

ROE (GAAP) (GAAP Net Income) - (b) / (f)

 

17.1%

   

-8.1%

   

-29.5%

   

17.6%

     
                             

ROE (Non-GAAP) (Non-GAAP Adjusted Net Income) - (c) / (g)

 

4.6%

   

-6.6%

   

0.2%

   

16.4%

     
 

* Average for the current and immediately preceding year

                             
                             
                             
                             
                             

Adjustments to Net Income (Loss) (GAAP)

                             
                             

(a) See below schedule for detail of adjustments to Net Income (Loss) (GAAP) in 2017:

   

Year Ended December 31, 2017

           
   

 Before 

   

 Income Tax  

   

 After 

           
   

 Tax 

   

 Impact 

   

 Tax 

           

Adjustments:

                           

    Add:   Mark-to-Market Commodity Derivative Contracts Impact

$

(12)

 

$

4

 

$

(8)

           

    Add:   Impairments of Certain Assets

 

261

   

(93)

   

168

           

    Add:   Net Losses on Asset Dispositions

 

99

   

(35)

   

64

           

    Add:   Legal Settlement - Early Lease Termination

 

10

   

(4)

   

6

           

    Add:   Joint Venture Transaction Costs

 

3

   

(1)

   

2

           

    Add:   Joint Interest Billings Deemed Uncollectible

 

5

   

(2)

   

3

           

    Less:  Tax Reform Impact

 

-

   

(2,169)

   

(2,169)

           

Total

$

366

 

$

(2,300)

 

$

(1,934)

           
                             

(b) See below schedule for detail of adjustments to Net Income (Loss) (GAAP) in 2016:

   

Year Ended December 31, 2016

           
   

 Before 

   

 Income Tax  

   

 After 

           
   

 Tax 

   

 Impact 

   

 Tax 

           

Adjustments:

                           

    Add:   Mark-to-Market Commodity Derivative Contracts Impact

$

77

 

$

(28)

 

$

49

           

    Add:   Impairments of Certain Assets

 

321

   

(113)

   

208

           

    Less:  Net Gains on Asset Dispositions

 

(206)

   

62

   

(144)

           

    Add:   Trinidad Tax Settlement

 

-

   

43

   

43

           

    Add:   Voluntary Retirement Expense

 

42

   

(15)

   

27

           

    Add:   Acquisition - State Apportionment Change

 

-

   

16

   

16

           

    Add:   Acquisition Costs

 

5

   

-

   

5

           

Total

$

239

 

$

(35)

 

$

204

           
                             

(c) See below schedule for detail of adjustments to Net Income (Loss) (GAAP) in 2015:

   

Year Ended December 31, 2015

           
   

 Before 

   

 Income Tax  

   

 After 

           
   

 Tax 

   

 Impact 

   

 Tax 

           

Adjustments:

                           

    Add:   Mark-to-Market Commodity Derivative Contracts Impact

$

668

 

$

(238)

 

$

430

           

    Add:   Impairments of Certain Assets

 

6,308

   

(2,183)

   

4,125

           

    Less:  Texas Margin Tax Rate Reduction

 

-

   

(20)

   

(20)

           

    Add:   Legal Settlement - Early Leasehold Termination

 

19

   

(6)

   

13

           

    Add:   Severance Costs

 

9

   

(3)

   

6

           

    Add:   Net Losses on Asset Dispositions

 

9

   

(4)

   

5

           

Total

$

7,013

 

$

(2,454)

 

$

4,559

           
                             

(d) See below schedule for detail of adjustments to Net Income (Loss) (GAAP) in 2014:

   

Year Ended December 31, 2014

           
   

 Before 

   

 Income Tax  

   

 After 

           
   

 Tax 

   

 Impact 

   

 Tax 

           

Adjustments:

                           

    Less:  Mark-to-Market Commodity Derivative Contracts Impact

$

(800)

 

$

285

 

$

(515)

           

    Add:   Impairments of Certain Assets

 

824

   

(271)

   

553

           

    Less:  Net Gains on Asset Dispositions

 

(508)

   

21

   

(487)

           

    Add:   Tax Expense Related to the Repatriation of Accumulated
                 Foreign Earnings in Future Years

 

-

   

250

   

250

           

Total

$

(484)

 

$

285

 

$

(199)

           

 

EOG RESOURCES, INC.

Quantitative Reconciliation of After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total

Capitalization (Non-GAAP) as used in the Calculation of Return on Capital Employed (Non-GAAP) to Net Interest

Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP), Respectively

(Unaudited; in millions, except ratio data)

                                   

The following chart reconciles Net Interest Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) (Non-GAAP) calculation.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Net Debt and Total Capitalization (Non-GAAP) in their ROCE calculation.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.

                                   
   

2013

   

2012

   

2011

   

2010

   

2009

   

2008

Return on Capital Employed (ROCE) (Non-GAAP)

                                 

(Calculated Using GAAP Net Income)

                                 
                                   

Net Interest Expense (GAAP)

$

235

 

$

214

 

$

210

 

$

130

 

$

101

 

$

52

Tax Benefit Imputed (based on 35%) 

 

(82)

   

(75)

   

(74)

   

(46)

   

(35)

   

(18)

After-Tax Net Interest Expense (Non-GAAP) - (a) 

$

153

 

$

139

 

$

136

 

$

84

 

$

66

 

$

34

                                   

Net Income (Loss) (GAAP) - (b)                                                   

$

2,197

 

$

570

 

$

1,091

 

$

161

 

$

547

 

$

2,437

                                   

Total Stockholders' Equity (GAAP) - (d)   

$

15,418

 

$

13,285

 

$

12,641

 

$

10,232

 

$

9,998

 

$

9,015

                                   

Average Total Stockholders' Equity (GAAP) * - (f)   

$

14,352

 

$

12,963

 

$

11,437

 

$

10,115

 

$

9,507

 

$

8,003

                                   

Current and Long-Term Debt (GAAP) - (h) 

$

5,909

 

$

6,312

 

$

5,009

 

$

5,223

 

$

2,797

 

$

1,897

Less: Cash                                                       

 

(1,318)

   

(876)

   

(616)

   

(789)

   

(686)

   

(331)

Net Debt (Non-GAAP) - (i) 

$

4,591

 

$

5,436

 

$

4,393

 

$

4,434

 

$

2,111

 

$

1,566

                                   

Total Capitalization (GAAP) - (d) + (h)  

$

21,327

 

$

19,597

 

$

17,650

 

$

15,455

 

$

12,795

 

$

10,912

                                   

Total Capitalization (Non-GAAP) - (d) + (i) 

$

20,009

 

$

18,721

 

$

17,034

 

$

14,666

 

$

12,109

 

$

10,581

                                   

Average Total Capitalization (Non-GAAP) * - (j)   

$

19,365

 

$

17,878

 

$

15,850

 

$

13,388

 

$

11,345

 

$

9,351

                                   

ROCE (GAAP Net Income) - [(a) + (b)] / (j)       

 

12.1%

   

4.0%

   

7.7%

   

1.8%

   

5.4%

   

26.4%

                                   
                                   

Return on Equity (ROE) (GAAP)

                                 
                                   

ROE (GAAP Net Income) - (b) / (f)

 

15.3%

   

4.4%

   

9.5%

   

1.6%

   

5.8%

   

30.5%

                                   
                                   

* Average for the current and immediately preceding year

                                   
                                   

EOG RESOURCES, INC.

Quantitative Reconciliation of After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total

Capitalization (Non-GAAP) as used in the Calculation of Return on Capital Employed (Non-GAAP) to Net Interest

Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP), Respectively

(Unaudited; in millions, except ratio data)

                                   

The following chart reconciles Net Interest Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) (Non-GAAP) calculation.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Net Debt and Total Capitalization (Non-GAAP) in their ROCE calculation.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.

                                   
   

2007

   

2006

   

2005

   

2004

   

2003

   

2002

Return on Capital Employed (ROCE) (Non-GAAP)

                                 

(Calculated Using GAAP Net Income)

                                 
                                   

Net Interest Expense (GAAP)

$

47

 

$

43

 

$

63

 

$

63

 

$

59

 

$

60

Tax Benefit Imputed (based on 35%) 

 

(16)

   

(15)

   

(22)

   

(22)

   

(21)

   

(21)

After-Tax Net Interest Expense (Non-GAAP) - (a) 

$

31

 

$

28

 

$

41

 

$

41

 

$

38

 

$

39

                                   

Net Income (Loss) (GAAP) - (b)                                                   

$

1,090

 

$

1,300

 

$

1,260

 

$

625

 

$

430

 

$

87

                                   

Total Stockholders' Equity (GAAP)- (d)   

$

6,990

 

$

5,600

 

$

4,316

 

$

2,945

 

$

2,223

 

$

1,672

                                   

Average Total Stockholders' Equity (GAAP) * - (f)   

$

6,295

 

$

4,958

 

$

3,631

 

$

2,584

 

$

1,948

 

$

1,658

                                   

Current and Long-Term Debt (GAAP) - (h) 

$

1,185

 

$

733

 

$

985

 

$

1,078

 

$

1,109

 

$

1,145

Less: Cash                                                       

 

(54)

   

(218)

   

(644)

   

(21)

   

(4)

   

(10)

Net Debt (Non-GAAP) - (i) 

$

1,131

 

$

515

 

$

341

 

$

1,057

 

$

1,105

 

$

1,135

                                   

Total Capitalization (GAAP) - (d) + (h)  

$

8,175

 

$

6,333

 

$

5,301

 

$

4,023

 

$

3,332

 

$

2,817

                                   

Total Capitalization (Non-GAAP) - (d) + (i) 

$

8,121

 

$

6,115

 

$

4,657

 

$

4,002

 

$

3,328

 

$

2,807

                                   

Average Total Capitalization (Non-GAAP) * - (j)   

$

7,118

 

$

5,386

 

$

4,330

 

$

3,665

 

$

3,068

 

$

2,652

                                   

ROCE (GAAP Net Income) - [(a) + (b)] / (j)       

 

15.7%

   

24.7%

   

30.0%

   

18.2%

   

15.3%

   

4.8%

                                   
                                   

Return on Equity (ROE) (GAAP)

                                 
                                   

ROE (GAAP Net Income) - (b) / (f)

 

17.3%

   

26.2%

   

34.7%

   

24.2%

   

22.1%

   

5.2%

                                   
                                   

* Average for the current and immediately preceding year

                                   
                                   

EOG RESOURCES, INC.

Quantitative Reconciliation of After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total

Capitalization (Non-GAAP) as used in the Calculation of Return on Capital Employed (Non-GAAP) to Net Interest

Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP), Respectively

(Unaudited; in millions, except ratio data)

                                   

The following chart reconciles Net Interest Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) (Non-GAAP) calculation.  EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Net Debt and Total Capitalization (Non-GAAP) in their ROCE calculation.  EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry.

                                   
   

2001

   

2000

   

1999

   

1998

   

1997

     

Return on Capital Employed (ROCE) (Non-GAAP)

                                 

(Calculated Using GAAP Net Income)

                                 
                                   

Net Interest Expense (GAAP)

$

45

 

$

61

 

$

62

 

$

49

           

Tax Benefit Imputed (based on 35%) 

 

(16)

   

(21)

   

(22)

   

(17)

           

After-Tax Net Interest Expense (Non-GAAP) - (a) 

$

29

 

$

40

 

$

40

 

$

32

           
                                   

Net Income (Loss) (GAAP) - (b)                                                   

$

399

 

$

397

 

$

569

 

$

56

           
                                   

Total Stockholders' Equity (GAAP)- (d)   

$

1,643

 

$

1,381

 

$

1,130

 

$

1,280

 

$

1,281

     
                                   

Average Total Stockholders' Equity (GAAP) * - (f)   

$

1,512

 

$

1,256

 

$

1,205

 

$

1,281

           
                                   

Current and Long-Term Debt (GAAP) - (h) 

$

856

 

$

859

 

$

990

 

$

1,143

 

$

745

     

Less: Cash                                                       

 

(3)

   

(20)

   

(25)

   

(6)

   

(9)

     

Net Debt (Non-GAAP) - (i) 

$

853

 

$

839

 

$

965

 

$

1,137

 

$

736

     
                                   

Total Capitalization (GAAP) - (d) + (h)  

$

2,499

 

$

2,240

 

$

2,120

 

$

2,423

 

$

2,026

     
                                   

Total Capitalization (Non-GAAP) - (d) + (i) 

$

2,496

 

$

2,220

 

$

2,095

 

$

2,417

 

$

2,017

     
                                   

Average Total Capitalization (Non-GAAP) * - (j)   

$

2,358

 

$

2,158

 

$

2,256

 

$

2,217

           
                                   

ROCE (GAAP Net Income) - [(a) + (b)] / (j)       

 

18.2%

   

20.2%

   

27.0%

   

4.0%

           
                                   
                                   

Return on Equity (ROE) (GAAP)

                                 
                                   

ROE (GAAP Net Income) - (b) / (f)

 

26.4%

   

31.6%

   

47.2%

   

4.4%

           
                                   
                                   

* Average for the current and immediately preceding year

 

EOG RESOURCES, INC.

Cash Operating Expenses per Barrel of Oil Equivalent (Boe)

(Unaudited; in thousands, except per Boe amounts)

                       
                       
   

Year-To-Date (YTD)

 

Year Ended 

 
   

September 30,

 

December 31,

 
   

2018

 

2017

 

2016

 

2015

 

2014

 
                       

Cash Operating Expenses (GAAP)*

                     

Lease and Well

 

$               936,236

 

$  1,044,847

 

$    927,452

 

$  1,182,282

 

$  1,416,413

 

Transportation Costs

 

550,781

 

740,352

 

764,106

 

849,319

 

972,176

 

General and Administrative

 

310,065

 

434,467

 

394,815

 

366,594

 

402,010

 

     Cash Operating Expenses

 

1,797,082

 

2,219,666

 

2,086,373

 

2,398,195

 

2,790,599

 

Less:  Legal Settlement - Early Leasehold Termination

 

-

 

(10,202)

 

-

 

(19,355)

 

-

 

Less:  Voluntary Retirement Expense

 

-

 

-

 

(42,054)

 

-

 

-

 

Less:  Acquisition Costs - Yates Transaction

 

-

 

-

 

(5,100)

 

-

 

-

 

Less:  Joint Venture Transaction Costs

 

-

 

(3,056)

 

-

 

-

 

-

 

Less:  Joint Interest Billings Deemed Uncollectible

 

-

 

(4,528)

 

-

 

-

 

-

 

     Adjusted Cash Operating Expenses (Non-GAAP) - (a)

 

$            1,797,082

 

$  2,201,880

 

$  2,039,219

 

$  2,378,840

 

$  2,790,599

 
                       

Volume - Thousand Barrels of Oil Equivalent - (b)

 

192,182

 

222,251

 

204,929

 

208,862

 

217,073

 
                       

Adjusted Cash Operating Expenses Per Boe (Non-GAAP) - (a) / (b)

 

$                    9.35

 

$          9.91

(c)

$          9.95

(d)

$        11.39

(e)

$        12.86

(f)

                       

Adjusted Cash Operating Expenses Per Boe (Non-GAAP) -
   Percentage Decrease

                     

YTD 2017 compared to YTD 2016 - [(c) - (d)] / (d)       

 

0%

                 

YTD 2017 compared to YTD 2015 - [(c) - (e)] / (e)       

 

-13%

                 

YTD 2017 compared to YTD 2014 - [(c) - (f)] / (f)       

 

-23%

                 
                       

* Includes stock compensation expense and other non-cash items.

 

EOG RESOURCES, INC.

Cost per Barrel of Oil Equivalent (Boe)

(Unaudited; in thousands, except per Boe amounts)

                 
                 
   

Year Ended

   

December 31,

   

2014

 

2015

 

2016

 

2017

                 

Volume - Thousand Barrels of Oil Equivalent 

 

217,073

 

208,862

 

204,929

 

222,251

                 

Total Wellhead Revenues

 

$  12,592,917

 

$  6,403,258

 

$     5,496,743

 

$     7,907,891

                 

Composite Average Wellhead Revenue per Boe

 

$          58.01

 

$        30.66

 

$            26.82

 

$            35.58

                 

Operating Costs

               

     Lease and Well

 

$    1,416,413

 

$  1,182,282

 

$        927,452

 

$     1,044,847

     Transportation Costs

 

972,176

 

849,319

 

764,106

 

740,352

     Gathering and Processing Costs

 

145,800

 

146,156

 

122,901

 

148,775

                 

     General and Administrative

 

402,010

 

366,594

 

394,815

 

434,467

          Less:  Voluntary Retirement Expense

 

-

 

-

 

(42,054)

 

-

          Less:  Acquisition Costs

 

-

 

-

 

(5,100)

 

-

          Less:  Legal Settlement - Early Leasehold Termination

 

-

 

(19,355)

 

-

 

(10,202)

          Less:  Joint Venture Transaction Costs

 

-

 

-

 

-

 

(3,056)

          Less:  Joint Interest Billings Deemed Uncollectible

 

-

 

-

 

-

 

(4,528)

     General and Administrative (Non-GAAP)

 

402,010

 

347,239

 

347,661

 

416,681

                 

     Taxes Other Than Income

 

757,564

 

421,744

 

349,710

 

544,662

     Interest Expense, Net

 

201,458

 

237,393

 

281,681

 

274,372

Total Cash Operating Cost (Non-GAAP) (excluding
   DD&A and Exploration Costs)

 

$    3,895,421

 

$  3,184,133

 

$     2,793,511

 

$     3,169,689

                 

Total Cash Operating Cost per Boe (Non-GAAP)
   (excluding DD&A and Exploration Costs)

 

$          17.95

 

$        15.25

 

$            13.64

 

$            14.25

                 

Composite Average Margin per Boe (Non-
   GAAP) (excluding DD&A and Exploration Costs)

 

$          40.06

 

$        15.41

 

$            13.18

 

$            21.33

                 

     Depreciation, Depletion and Amortization (DD&A)

 

3,997,041

 

3,313,644

 

3,553,417

 

3,409,387

Total Operating Cost (Non-GAAP) (excluding Exploration
   Costs)

 

$    7,892,462

 

$  6,497,777

 

$     6,346,928

 

$     6,579,076

                 

Total Operating Cost per Boe (Non-GAAP) (excluding
   Exploration Costs)

 

$          36.38

 

$        31.11

 

$            30.98

 

$            29.59

                 

Composite Average Margin per Boe (Non-GAAP)
   (excluding Exploration Costs)

 

$          21.63

 

$         (0.45)

 

$            (4.16)

 

$             5.99

                 

     Total Exploration Costs

 

976,453

 

6,777,786

 

755,877

 

629,191

          Less:  Impairments

 

(824,312)

 

(6,307,593)

 

(320,617)

 

(261,452)

     Total Exploration Costs (Non-GAAP)

 

152,141

 

470,193

 

435,260

 

367,739

                 

Total Operating Cost (Non-GAAP) (including Exploration
   Costs) 

 

$    8,044,603

 

$  6,967,970

 

$     6,782,188

 

$     6,946,815

                 

Total Operating Cost per Boe (Non-GAAP) (including
   Exploration Costs) 

 

$          37.08

 

$        33.36

 

$            33.10

 

$            31.24

                 

Composite Average Margin per Boe (Non-GAAP)
   (including Exploration Costs) 

 

$          20.93

 

$         (2.70)

 

$            (6.28)

 

$             4.34

                 
                 

EOG RESOURCES, INC.

Cost per Barrel of Oil Equivalent (Boe)

(Unaudited; in thousands, except per Boe amounts)

                 
                 
   

Three Months Ended

 

Year-To-Date

   

March 31,

 

June 30,

 

September 30,

 

September 30,

   

2018

 

2018

 

2018

 

2018

                 

Volume - Thousand Barrels of Oil Equivalent 

 

59,394

 

63,898

 

68,890

 

192,182

                 

Total Wellhead Revenues

 

$    2,622,489

 

$  2,964,727

 

$     3,320,695

 

$     8,907,911

                 

Composite Average Wellhead Revenue per Boe

 

$          44.15

 

$        46.40

 

$            48.20

 

$            46.35

                 

Operating Costs

               

     Lease and Well

 

$      300,064

 

$    314,604

 

$        321,568

 

$        936,236

     Transportation Costs

 

176,957

 

177,797

 

196,027

 

550,781

     Gathering and Processing Costs

 

101,345

 

109,169

 

114,063

 

324,577

     General and Administrative

 

94,698

 

104,083

 

111,284

 

310,065

     Taxes Other Than Income

 

179,084

 

194,268

 

209,043

 

582,395

     Interest Expense, Net

 

61,956

 

63,444

 

63,632

 

189,032

Total Cash Operating Cost (excluding
   DD&A and Exploration Costs)

 

$      914,104

 

$    963,365

 

$     1,015,617

 

$     2,893,086

                 

Total Cash Operating Cost per Boe
   (excluding DD&A and Exploration Costs)

 

$          15.39

 

$        15.07

 

$            14.75

 

$            15.05

                 

Composite Average Margin per Boe
   (excluding DD&A and Exploration Costs)

 

$          28.76

 

$        31.33

 

$            33.45

 

$            31.30

                 

     Depreciation, Depletion and Amortization (DD&A)

 

748,591

 

848,674

 

918,180

 

2,515,445

Total Operating Cost (excluding Exploration
   Costs)

 

$    1,662,695

 

$  1,812,039

 

$     1,933,797

 

$     5,408,531

                 

Total Operating Cost per Boe (excluding
   Exploration Costs)

 

$          27.99

 

$        28.35

 

$            28.08

 

$            28.14

                 

Composite Average Margin per Boe
   (excluding Exploration Costs)

 

$          16.16

 

$        18.05

 

$            20.12

 

$            18.21

                 

     Total Exploration Costs

 

99,445

 

104,088

 

77,798

 

281,331

          Less:  Impairments

 

(20,876)

 

-

 

-

 

(20,876)

     Total Exploration Costs (Non-GAAP)

 

78,569

 

104,088

 

77,798

 

260,455

                 

Total Operating Cost (Non-GAAP) (including Exploration
   Costs) 

 

$    1,741,264

 

$  1,916,127

 

$     2,011,595

 

$     5,668,986

                 

Total Operating Cost per Boe (Non-GAAP) (including
   Exploration Costs) 

 

$          29.31

 

$        29.98

 

$            29.21

 

$            29.50

                 

Composite Average Margin per Boe (Non-GAAP)
   (including Exploration Costs) 

 

$          14.84

 

$        16.42

 

$            18.99

 

$            16.85

 

EOG RESOURCES, INC.

Fourth Quarter and Full Year 2018 Forecast and Benchmark Commodity Pricing

                       

     (a)  Fourth Quarter and Full Year 2018 Forecast

                       

The forecast items for the fourth quarter and full year 2018 set forth below for EOG Resources, Inc. (EOG) are based on current available information and expectations as of the date of the accompanying press release.  EOG undertakes no obligation, other than as required by applicable law, to update or revise this forecast, whether as a result of new information, subsequent events, anticipated or unanticipated circumstances or otherwise.  This forecast, which should be read in conjunction with the accompanying press release and EOG's related Current Report on Form 8-K filing, replaces and supersedes any previously issued guidance or forecast.

                       

     (b)  Benchmark Commodity Pricing

                       

EOG bases United States and Trinidad crude oil and condensate price differentials upon the West Texas Intermediate crude oil price at Cushing, Oklahoma, using the simple average of the NYMEX settlement prices for each trading day within the applicable calendar month.

                       

EOG bases United States natural gas price differentials upon the natural gas price at Henry Hub, Louisiana, using the simple average of the NYMEX settlement prices for the last three trading days of the applicable month.

                       
           

Estimated Ranges

         
           

(Unaudited)

         
   

4Q 2018

   

Full Year 2018

Daily Sales Volumes

                     

     Crude Oil and Condensate Volumes (MBbld)

                     

          United States

 

425.0

-

 

430.0

   

393.5

-

 

394.8

          Trinidad

 

0.5

-

 

0.7

   

0.7

-

 

0.9

          Other International

 

3.0

-

 

5.0

   

3.8

-

 

4.3

               Total

 

428.5

-

 

435.7

   

398.0

-

 

400.0

                       

     Natural Gas Liquids Volumes (MBbld)

                     

               Total

 

115.0

-

 

125.0

   

114.1

-

 

116.7

                       

     Natural Gas Volumes (MMcfd)

                     

          United States

 

975

-

 

1,025

   

923

-

 

935

          Trinidad

 

220

-

 

250

   

264

-

 

271

          Other International

 

30

-

 

40

   

30

-

 

33

               Total

 

1,225

-

 

1,315

   

1,217

-

 

1,239

                       

     Crude Oil Equivalent Volumes (MBoed)  

                     

          United States

 

702.5

-

 

725.8

   

661.5

-

 

667.3

          Trinidad

 

37.2

-

 

42.4

   

44.6

-

 

46.1

          Other International

 

8.0

-

 

11.7

   

8.8

-

 

9.8

               Total

 

747.7

-

 

779.9

   

714.9

-

 

723.2

                       
           

Estimated Ranges

         
           

(Unaudited)

         
 

4Q 2018

   

Full Year 2018

Operating Costs

                     

     Unit Costs ($/Boe)

                     

          Lease and Well

$

4.45

-

$

4.85

 

$

4.80

-

$

4.90

          Transportation Costs

$

2.45

-

$

2.85

 

$

2.75

-

$

2.85

          Depreciation, Depletion and Amortization

$

13.60

-

$

13.95

 

$

13.23

-

$

13.32

                       

Expenses ($MM)

                     

     Exploration, Dry Hole and Impairment

$

105

-

$

125

 

$

365

-

$

385

     General and Administrative

$

105

-

$

115

 

$

415

-

$

425

     Gathering and Processing 

$

110

-

$

130

 

$

435

-

$

455

     Capitalized Interest

$

5

-

$

7

 

$

23

-

$

25

     Net Interest

$

55

-

$

58

 

$

244

-

$

247

                       

Taxes Other Than Income (% of Wellhead Revenue)

 

6.5%

-

 

6.8%

   

6.5%

-

 

6.7%

                       

Income Taxes

                     

     Effective Rate 

 

20%

-

 

25%

   

19%

-

 

24%

     Current Tax (Benefit) / Expense ($MM)

$

(70)

-

$

(30)

 

$

(190)

-

$

(150)

                       

Capital Expenditures (Excluding Acquisitions, $MM)

                     

     Exploration and Development, Excluding Facilities

           

$

4,900

-

$

5,000

     Exploration and Development Facilities

           

$

600

-

$

650

     Gathering, Processing and Other

           

$

300

-

$

350

                       

Pricing - (Refer to Benchmark Commodity Pricing in text)

                     

     Crude Oil and Condensate ($/Bbl)

                     

          Differentials

                     

               United States - above (below) WTI

$

0.00

-

$

2.00

 

$

0.50

-

$

1.05

               Trinidad - above (below) WTI

$

(11.00)

-

$

(9.00)

 

$

(9.00)

-

$

(8.00)

               Other International - above (below) WTI

$

0.00

-

$

7.00

 

$

3.80

-

$

5.60

                       

     Natural Gas Liquids

                     

          Realizations as % of WTI

 

38%

-

 

46%

   

41%

-

 

43%

                       

     Natural Gas ($/Mcf)

                     

          Differentials

                     

               United States - above (below) NYMEX Henry Hub

$

(0.40)

-

$

0.00

 

$

(0.25)

-

$

(0.15)

                       

          Realizations

                     

               Trinidad

$

2.40

-

$

2.80

 

$

2.80

-

$

2.90

               Other International

$

4.15

-

$

4.65

 

$

4.10

-

$

4.25

                       

Definitions

                     

$/Bbl         U.S. Dollars per barrel

                     

$/Boe        U.S. Dollars per barrel of oil equivalent

                     

$/Mcf         U.S. Dollars per thousand cubic feet

                     

$MM          U.S. Dollars in millions

                     

MBbld       Thousand barrels per day

                     

MBoed      Thousand barrels of oil equivalent per day

                     

MMcfd       Million cubic feet per day

                     

NYMEX     U.S. New York Mercantile Exchange

                     

WTI           West Texas Intermediate

                     

 

 

Cision View original content:http://www.prnewswire.com/news-releases/eog-resources-announces-outstanding-third-quarter-2018-results-300742708.html

SOURCE EOG Resources, Inc.