|
EOG Resources Reports First Quarter 2020 Results and Updates 2020 Plan in Response to Oil Market Downturn; Company Well-Positioned to Emerge Stronger in a Recovery
HOUSTON, May 7, 2020 /PRNewswire/ --
- Reduced Full-Year 2020 Capital Plan by an Additional $1.0 Billion to $3.3 to $3.7 Billion, Representing a Total Reduction of 46% Compared with Original Plan
- Target 2020 Well Cost Savings of 8%
- Declared Unchanged Common Stock Dividend of $0.375 per Share, or $1.50 Indicated Annual Rate
- First Quarter Crude Oil Production Within Target Range with Capital Expenditures 14% Below Target Midpoint
EOG Resources, Inc. (EOG) today reported first quarter 2020 net income of $10 million, or $0.02 per share, compared with first quarter 2019 net income of $635 million, or $1.10 per share.
Adjusted non-GAAP net income for the first quarter 2020 was $318 million, or $0.55 per share, compared with adjusted non-GAAP net income of $689 million, or $1.19 per share, for the same prior year period. Please refer to the attached tables for the reconciliation of non-GAAP measures to GAAP measures.
First Quarter 2020 Review
EOG continued to deliver strong operational and financial performance in the first quarter 2020 while responding to rapidly changing market conditions. The company moved quickly to reduce activity and capital expenditures. EOG also elected to defer production by delaying the startup of new wells and shutting in production from existing wells.
Crude oil production volumes in the first quarter 2020 were in line with the target range while capital expenditures were 14 percent below the target midpoint. Total company crude oil volumes of 483,300 barrels of oil per day (Bopd) grew 11 percent compared with the first quarter 2019, despite electing to delay the startup of some new wells in the quarter and the shut-in of approximately 8,000 Bopd in March. Natural gas liquids production increased 35 percent, supported by the increased recovery of ethane in natural gas processing operations. Natural gas volumes grew five percent, contributing to total company daily production growth of 13 percent.
Cash operating expenses declined by eight percent on a per-unit basis during the first quarter 2020 compared with the same prior year period. Lower per-unit lease and well and general and administrative costs contributed to the overall cost reduction.
Net cash provided by operating activities for the first quarter 2020 was $2.6 billion. EOG generated $1.7 billion of discretionary cash flow in the first quarter 2020. The company incurred total expenditures of $1.8 billion, including $1.7 billion of capital expenditures before acquisitions, non‐cash transactions and asset retirement costs. Please refer to the attached tables for the reconciliation of non-GAAP measures to GAAP measures.
"EOG is a resilient company. During the first quarter the company adjusted operations quickly to manage extreme commodity price volatility and the challenges from the COVID-19 pandemic," said William R. "Bill" Thomas, Chairman and Chief Executive Officer. "These unprecedented market conditions have super-charged our unique culture to vigorously lower costs and generate innovative productivity gains that will make EOG a much better company as we emerge from this downturn. Our years of continuous improvement, disciplined high-return investments, free cash flow generation and focus on strengthening our balance sheet have positioned the company for sustainable success through commodity price cycles."
Updated 2020 Capital Plan
EOG has further revised its full-year 2020 plan as a result of the significant decline and increased volatility of commodity prices. The goals of the plan are to generate high rates of return on capital investments, maintain EOG's strong financial position and support the dividend. The revised plan retains funding for projects that support the long-term value of the company, including targeted infrastructure, exploration and environmental projects.
Exploration and development expenditures for 2020 are now expected to range from $3.3 billion to $3.7 billion, including facilities and gathering, processing and other expenditures, and excluding acquisitions, non‐cash transactions and asset retirement costs. This represents a reduction of $1.0 billion from the previous updated plan that was announced on March 16 and a reduction of $3.0 billion, or 46 percent, from the original plan at the start of the year.
EOG has moved quickly to reduce its operating activity. The company lowered its operated rig count from 36 rigs to eight rigs during the last six weeks, with an average of approximately six rigs expected for the remainder of 2020. EOG has identified over 4,500 net drilling locations - more than nine years of inventory at the 2020 activity pace - that are capable of generating strong rates of return at less than $30 WTI oil. The company plans to focus its 2020 activity on these high-return wells.
Driven by its innovative culture and decentralized organization, EOG is accelerating cost reductions and sustainable efficiency improvements across its operations. Targeted well costs are forecast to decline an average of eight percent compared with 2019 levels, including reductions of nine percent and seven percent, respectively, in EOG's premier Delaware Basin and South Texas Eagle Ford operations.
EOG's revised capital plan targets full-year 2020 crude oil production of approximately 390,000 Bopd, representing a decline of 15 percent compared with full-year 2019 levels. EOG currently plans to bring approximately 485 net wells onto production for the full-year 2020 compared with the original forecast of 800 net wells, with a focus on the Delaware Basin and South Texas Eagle Ford.
In order to generate higher rates of return, the company has elected to defer some of its production until oil prices recover. This includes delaying the startup of approximately 150 net new wells until the second half of 2020 and the shut-in of existing production. The net production volume associated with the shut-in of existing wells was approximately 8,000 Bopd in March, 24,000 Bopd in April and is estimated to be 125,000 Bopd in May and 100,000 Bopd in June, with an average of 40,000 Bopd for the full-year 2020.
"Our guiding principles in this environment remain consistent with EOG's long-term strategy: to make returns-based decisions and spend within our means to protect our strong balance sheet. This is intended to preserve EOG's business value and position the company to thrive in an upturn," Thomas said.
"Over the last several years as we implemented our premium strategy, EOG significantly lowered its cost structure and strengthened its financial position, giving us a distinct advantage in the current environment. Our operational flexibility, favorable hedges and strong liquidity leave us well-positioned to respond to volatile market conditions. Since the end of the first quarter, we have further bolstered our liquidity by adjusting our hedge position and issuing new long-term debt to refinance bond maturities. Because we have acted decisively, we will be able to utilize these advantages as we navigate the downturn."
"During these challenging times, our first priority is the health and safety of our employees and their families, our contractors and our communities. We are also committed to sustaining our unique culture, EOG's most important asset. I am incredibly proud of our exceptional people, who have quickly adjusted to the new environment. Our employees are the foundation of the EOG culture. Thanks to their hard work and dedication, EOG is well-positioned to emerge even stronger in the recovery."
Dividend
The board of directors declared a dividend of $0.375 per share on EOG's Common Stock. The dividend will be payable July 31, 2020, to stockholders of record as of July 17, 2020. The indicated annual rate is $1.50 per share.
Financial Review
At March 31, 2020, EOG's total debt outstanding was $5.2 billion for a debt-to-total capitalization ratio of 20 percent. Considering $2.9 billion of cash on the balance sheet at the end of the first quarter, EOG's net debt was $2.3 billion for a net debt-to-total capitalization ratio of 10 percent. EOG's liquidity is further enhanced by $2.0 billion of availability under its senior unsecured revolving credit agreement as of March 31, 2020. For a reconciliation of non-GAAP measures to GAAP measures, please refer to the attached tables.
Subsequent to the end of the first quarter, on April 1, 2020, EOG repaid, with cash on hand, the $500 million aggregate principal amount of its 2.45% Senior Notes due 2020 that matured on that date. In addition, on April 14, 2020, EOG closed its sale of $750 million aggregate principal amount of its 4.375% Senior Notes due 2030 and $750 million aggregate principal amount of its 4.950% Senior Notes due 2050. EOG received aggregate net proceeds from the sale, after deducting underwriting discounts and estimated offering expenses, of approximately $1.48 billion.
First Quarter 2020 Results Webcast
Friday, May 8, 2020, 9:00 a.m. Central time (10:00 a.m. Eastern time)
Webcast will be available on EOG's 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, and China. To learn more visit www.eogresources.com.
Investor Contacts
David Streit 713-571-4902
Neel Panchal 713-571-4884
Media and Investor Contact
Kimberly Ehmer 713-571-4676
Source: EOG Resources, Inc.
Category: Earnings
This press release may include 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. Furthermore, this press release and any accompanying disclosures may include or reference certain forward-looking, non-GAAP financial measures, such as free cash flow or discretionary cash flow, and certain related estimates regarding future performance, results and financial position. Because we provide these measures on a forward-looking basis, we cannot reliably or reasonably predict certain of the necessary components of the most directly comparable forward-looking GAAP measures, such as future impairments and future changes in working capital. Accordingly, we are unable to present a quantitative reconciliation of such forward-looking, non-GAAP financial measures to the respective most directly comparable forward-looking GAAP financial measures. Management believes these forward-looking, non-GAAP measures may be a useful tool for the investment community in comparing EOG's forecasted financial performance to the forecasted financial performance of other companies in the industry. Any such 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 such measures and estimates. 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 (i) economically develop its acreage in, (ii) produce reserves and achieve anticipated production levels and rates of return from, (iii) decrease or otherwise control its drilling, completion, operating and capital costs related to, and (iv) maximize reserve recovery from, its existing and future crude oil and natural gas exploration and development projects and associated potential and existing drilling locations;
- 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;
- security threats, including cybersecurity threats and disruptions to our business and operations from breaches of our information technology systems, physical breaches of our facilities and other infrastructure or breaches of the information technology systems, facilities and infrastructure of third parties with which we transact business;
- 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 drilling, completing and operating 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;
- 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;
- the duration and economic and financial impact of epidemics, pandemics or other public health issues, including the COVID-19 pandemic;
- 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; and
- the other factors described under ITEM 1A, Risk Factors, on pages 13 through 23 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2019 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.
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 or resource estimates provided in this press release that are not specifically designated as being estimates of proved reserves may include "potential" reserves, "resource potential" and/or other estimated reserves or estimated resources 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, 2019, 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
|
|
|
|
March 31,
|
|
|
|
2020
|
|
2019
|
|
|
|
|
|
|
|
|
|
|
Operating Revenues and Other
|
|
$
|
4,717.7
|
|
$
|
4,058.6
|
|
|
Net Income
|
|
$
|
9.8
|
|
$
|
635.4
|
|
|
Net Income Per Share
|
|
|
|
|
|
|
|
|
Basic
|
|
$
|
0.02
|
|
$
|
1.10
|
|
|
Diluted
|
|
$
|
0.02
|
|
$
|
1.10
|
|
|
Average Number of Common Shares
|
|
|
|
|
|
|
|
|
Basic
|
|
|
578.5
|
|
|
577.2
|
|
|
Diluted
|
|
|
580.3
|
|
|
580.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Summary Income Statements
|
|
(Unaudited; in thousands, except per share data)
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
|
March 31,
|
|
|
|
2020
|
|
2019
|
|
|
Operating Revenues and Other
|
|
|
|
|
|
|
Crude Oil and Condensate
|
|
$
|
2,065,498
|
|
$
|
2,200,403
|
|
|
Natural Gas Liquids
|
|
|
160,535
|
|
|
218,638
|
|
|
Natural Gas
|
|
|
209,764
|
|
|
334,972
|
|
|
Gains (Losses) on Mark-to-Market Commodity
Derivative Contracts
|
|
|
1,205,773
|
|
|
(20,580)
|
|
|
Gathering, Processing and Marketing
|
|
|
1,038,646
|
|
|
1,285,654
|
|
|
Gains (Losses) on Asset Dispositions, Net
|
|
|
16,460
|
|
|
(3,836)
|
|
|
Other, Net
|
|
|
21,016
|
|
|
43,391
|
|
|
Total
|
|
|
4,717,692
|
|
|
4,058,642
|
|
|
Operating Expenses
|
|
|
|
|
|
|
|
|
Lease and Well
|
|
|
329,659
|
|
|
336,291
|
|
|
Transportation Costs
|
|
|
208,296
|
|
|
176,522
|
|
|
Gathering and Processing Costs
|
|
|
128,482
|
|
|
111,295
|
|
|
Exploration Costs
|
|
|
39,677
|
|
|
36,324
|
|
|
Dry Hole Costs
|
|
|
372
|
|
|
94
|
|
|
Impairments
|
|
|
1,572,935
|
|
|
72,356
|
|
|
Marketing Costs
|
|
|
1,108,993
|
|
|
1,270,057
|
|
|
Depreciation, Depletion and Amortization
|
|
|
1,000,060
|
|
|
879,595
|
|
|
General and Administrative
|
|
|
114,273
|
|
|
106,672
|
|
|
Taxes Other Than Income
|
|
|
157,360
|
|
|
192,906
|
|
|
Total
|
|
|
4,660,107
|
|
|
3,182,112
|
|
|
|
|
|
|
|
|
|
|
Operating Income
|
|
|
57,585
|
|
|
876,530
|
|
|
|
|
|
|
|
|
|
|
Other Income, Net
|
|
|
18,108
|
|
|
5,612
|
|
|
|
|
|
|
|
|
|
|
Income Before Interest Expense and Income Taxes
|
|
|
75,693
|
|
|
882,142
|
|
|
|
|
|
|
|
|
|
|
Interest Expense, Net
|
|
|
44,690
|
|
|
54,906
|
|
|
|
|
|
|
|
|
|
|
Income Before Income Taxes
|
|
|
31,003
|
|
|
827,236
|
|
|
|
|
|
|
|
|
|
|
Income Tax Provision
|
|
|
21,190
|
|
|
191,810
|
|
|
|
|
|
|
|
|
|
|
Net Income
|
|
$
|
9,813
|
|
$
|
635,426
|
|
|
|
|
|
|
|
|
|
|
Dividends Declared per Common Share
|
|
$
|
0.3750
|
|
$
|
0.2200
|
|
|
EOG RESOURCES, INC.
|
|
Operating Highlights
|
|
(Unaudited)
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
|
March 31,
|
|
|
|
2020
|
|
2019
|
|
% Change
|
|
Wellhead Volumes and Prices
|
|
|
|
|
Crude Oil and Condensate Volumes (MBbld) (A)
|
|
|
|
|
United States
|
|
482.7
|
|
|
435.1
|
|
11%
|
|
Trinidad
|
|
0.5
|
|
|
0.7
|
|
-29%
|
|
Other International (B)
|
|
0.1
|
|
|
0.1
|
|
0%
|
|
Total
|
|
483.3
|
|
|
435.9
|
|
11%
|
|
|
|
|
|
|
|
|
|
Average Crude Oil and Condensate Prices ($/Bbl) (C)
|
|
|
|
|
|
|
|
|
United States
|
$
|
46.97
|
|
$
|
56.11
|
|
-16%
|
|
Trinidad
|
|
34.93
|
|
|
43.68
|
|
-20%
|
|
Other International (B)
|
|
57.51
|
|
|
60.13
|
|
-4%
|
|
Composite
|
|
46.96
|
|
|
56.09
|
|
-16%
|
|
|
|
|
|
|
|
|
|
Natural Gas Liquids Volumes (MBbld) (A)
|
|
|
|
|
|
|
|
|
United States
|
|
161.3
|
|
|
119.8
|
|
35%
|
|
Other International (B)
|
|
-
|
|
|
-
|
|
|
|
Total
|
|
161.3
|
|
|
119.8
|
|
35%
|
|
|
|
|
|
|
|
|
|
Average Natural Gas Liquids Prices ($/Bbl) (C)
|
|
|
|
|
|
|
|
|
United States
|
$
|
10.94
|
|
$
|
20.28
|
|
-46%
|
|
Other International (B)
|
|
-
|
|
|
-
|
|
|
|
Composite
|
|
10.94
|
|
|
20.28
|
|
-46%
|
|
|
|
|
|
|
|
|
|
Natural Gas Volumes (MMcfd) (A)
|
|
|
|
|
|
|
|
|
United States
|
|
1,139
|
|
|
1,003
|
|
14%
|
|
Trinidad
|
|
201
|
|
|
267
|
|
-25%
|
|
Other International (B)
|
|
38
|
|
|
38
|
|
0%
|
|
Total
|
|
1,378
|
|
|
1,308
|
|
5%
|
|
|
|
|
|
|
|
|
|
Average Natural Gas Prices ($/Mcf) (C)
|
|
|
|
|
|
|
|
|
United States
|
$
|
1.50
|
|
$
|
2.77
|
|
-46%
|
|
Trinidad
|
|
2.17
|
|
|
2.91
|
|
-26%
|
|
Other International (B)
|
|
4.32
|
|
|
4.37
|
|
-1%
|
|
Composite
|
|
1.67
|
|
|
2.85
|
|
-41%
|
|
|
|
|
|
|
|
|
|
Crude Oil Equivalent Volumes (MBoed) (D)
|
|
|
|
|
|
|
|
|
United States
|
|
833.8
|
|
|
722.0
|
|
15%
|
|
Trinidad
|
|
34.0
|
|
|
45.1
|
|
-25%
|
|
Other International (B)
|
|
6.3
|
|
|
6.5
|
|
-3%
|
|
Total
|
|
874.1
|
|
|
773.6
|
|
13%
|
|
|
|
|
|
|
|
|
|
Total MMBoe (D)
|
|
79.5
|
|
|
69.6
|
|
14%
|
|
|
|
|
|
|
|
|
|
(A) Thousand barrels per day or million cubic feet per day, as applicable.
|
|
(B) Other International includes EOG's 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 Consolidated Financial Statements in EOG's Annual Report on Form 10-K for the year ended December 31, 2019).
|
|
(D) 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)
|
|
|
|
|
|
|
|
March 31,
|
|
December 31,
|
|
2020
|
|
2019
|
|
ASSETS
|
|
Current Assets
|
|
|
|
|
|
|
Cash and Cash Equivalents
|
$
|
2,906,852
|
|
$
|
2,027,972
|
|
Accounts Receivable, Net
|
|
1,449,637
|
|
|
2,001,658
|
|
Inventories
|
|
662,398
|
|
|
767,297
|
|
Assets from Price Risk Management Activities
|
|
932,928
|
|
|
1,299
|
|
Income Taxes Receivable
|
|
309,328
|
|
|
151,665
|
|
Other
|
|
229,906
|
|
|
323,448
|
|
Total
|
|
6,491,049
|
|
|
5,273,339
|
|
|
|
|
|
|
|
Property, Plant and Equipment
|
|
|
|
|
|
|
Oil and Gas Properties (Successful Efforts Method)
|
|
64,046,355
|
|
|
62,830,415
|
|
Other Property, Plant and Equipment
|
|
4,648,834
|
|
|
4,472,246
|
|
Total Property, Plant and Equipment
|
|
68,695,189
|
|
|
67,302,661
|
|
Less: Accumulated Depreciation, Depletion and Amortization
|
|
(39,001,135)
|
|
|
(36,938,066)
|
|
Total Property, Plant and Equipment, Net
|
|
29,694,054
|
|
|
30,364,595
|
|
Deferred Income Taxes
|
|
2,558
|
|
|
2,363
|
|
Other Assets
|
|
1,446,423
|
|
|
1,484,311
|
|
Total Assets
|
$
|
37,634,084
|
|
$
|
37,124,608
|
|
|
|
|
|
|
|
LIABILITIES AND STOCKHOLDERS' EQUITY
|
|
Current Liabilities
|
|
|
|
|
|
|
Accounts Payable
|
$
|
2,892,320
|
|
$
|
2,429,127
|
|
Accrued Taxes Payable
|
|
200,240
|
|
|
254,850
|
|
Dividends Payable
|
|
216,933
|
|
|
166,273
|
|
Liabilities from Price Risk Management Activities
|
|
-
|
|
|
20,194
|
|
Current Portion of Long-Term Debt
|
|
519,017
|
|
|
1,014,524
|
|
Current Portion of Operating Lease Liabilities
|
|
322,367
|
|
|
369,365
|
|
Other
|
|
154,134
|
|
|
232,655
|
|
Total
|
|
4,305,011
|
|
|
4,486,988
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Long-Term Debt
|
|
4,703,152
|
|
|
4,160,919
|
|
Other Liabilities
|
|
2,064,175
|
|
|
1,789,884
|
|
Deferred Income Taxes
|
|
5,091,071
|
|
|
5,046,101
|
|
Commitments and Contingencies
|
|
|
|
|
|
|
|
|
|
|
|
|
Stockholders' Equity
|
|
|
|
|
|
|
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and
582,356,329 Shares Issued at March 31, 2020 and 582,213,016
Shares Issued at December 31, 2019
|
|
205,824
|
|
|
205,822
|
|
Additional Paid in Capital
|
|
5,852,821
|
|
|
5,817,475
|
|
Accumulated Other Comprehensive Loss
|
|
(3,305)
|
|
|
(4,652)
|
|
Retained Earnings
|
|
15,440,142
|
|
|
15,648,604
|
|
Common Stock Held in Treasury, 319,162 Shares at March 31, 2020
and 298,820 Shares at December 31, 2019
|
|
(24,807)
|
|
|
(26,533)
|
|
Total Stockholders' Equity
|
|
21,470,675
|
|
|
21,640,716
|
|
Total Liabilities and Stockholders' Equity
|
$
|
37,634,084
|
|
$
|
37,124,608
|
|
EOG RESOURCES, INC.
|
|
Summary Statements of Cash Flows
|
|
(Unaudited; in thousands)
|
|
|
|
|
|
|
|
Three Months Ended
|
|
March 31,
|
|
2020
|
|
2019
|
|
Cash Flows from Operating Activities
|
|
|
|
|
|
|
Reconciliation of Net Income to Net Cash Provided by Operating Activities:
|
|
|
|
|
|
|
Net Income
|
$
|
9,813
|
|
$
|
635,426
|
|
Items Not Requiring (Providing) Cash
|
|
|
|
|
|
|
Depreciation, Depletion and Amortization
|
|
1,000,060
|
|
|
879,595
|
|
Impairments
|
|
1,572,935
|
|
|
72,356
|
|
Stock-Based Compensation Expenses
|
|
40,072
|
|
|
39,087
|
|
Deferred Income Taxes
|
|
44,774
|
|
|
106,324
|
|
(Gains) Losses on Asset Dispositions, Net
|
|
(16,460)
|
|
|
3,836
|
|
Other, Net
|
|
(8,815)
|
|
|
2,952
|
|
Dry Hole Costs
|
|
372
|
|
|
94
|
|
Mark-to-Market Commodity Derivative Contracts
|
|
|
|
|
|
|
Total (Gains) Losses
|
|
(1,205,773)
|
|
|
20,580
|
|
Net Cash Received from Settlements of Commodity Derivative Contracts
|
|
84,373
|
|
|
20,846
|
|
Other, Net
|
|
(355)
|
|
|
976
|
|
Changes in Components of Working Capital and Other Assets and Liabilities
|
|
|
|
|
|
|
Accounts Receivable
|
|
722,163
|
|
|
(308,996)
|
|
Inventories
|
|
102,670
|
|
|
(18,979)
|
|
Accounts Payable
|
|
433,558
|
|
|
194,082
|
|
Accrued Taxes Payable
|
|
(54,605)
|
|
|
114,998
|
|
Other Assets
|
|
58,296
|
|
|
(6,935)
|
|
Other Liabilities
|
|
(66,078)
|
|
|
(54,092)
|
|
Changes in Components of Working Capital Associated with Investing
Activities
|
|
(132,082)
|
|
|
(94,381)
|
|
Net Cash Provided by Operating Activities
|
|
2,584,918
|
|
|
1,607,769
|
|
|
|
|
|
|
|
Investing Cash Flows
|
|
|
|
|
|
|
Additions to Oil and Gas Properties
|
|
(1,566,051)
|
|
|
(1,939,473)
|
|
Additions to Other Property, Plant and Equipment
|
|
(122,775)
|
|
|
(60,963)
|
|
Proceeds from Sales of Assets
|
|
25,801
|
|
|
15,049
|
|
Changes in Components of Working Capital Associated with Investing Activities
|
|
132,082
|
|
|
94,381
|
|
Net Cash Used in Investing Activities
|
|
(1,530,943)
|
|
|
(1,891,006)
|
|
|
|
|
|
|
|
Financing Cash Flows
|
|
|
|
|
|
|
Dividends Paid
|
|
(167,058)
|
|
|
(127,546)
|
|
Treasury Stock Purchased
|
|
(4,655)
|
|
|
(6,248)
|
|
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan
|
|
66
|
|
|
403
|
|
Repayment of Finance Lease Liabilities
|
|
(3,621)
|
|
|
(3,190)
|
|
Net Cash Used in Financing Activities
|
|
(175,268)
|
|
|
(136,581)
|
|
|
|
|
|
|
|
Effect of Exchange Rate Changes on Cash
|
|
173
|
|
|
(6)
|
|
|
|
|
|
|
|
Increase (Decrease) in Cash and Cash Equivalents
|
|
878,880
|
|
|
(419,824)
|
|
Cash and Cash Equivalents at Beginning of Period
|
|
2,027,972
|
|
|
1,555,634
|
|
Cash and Cash Equivalents at End of Period
|
$
|
2,906,852
|
|
$
|
1,135,810
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of Adjusted Net Income
|
|
(Unaudited; in thousands, except per share data)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The following chart adjusts the three-month periods ended March 31, 2020 and 2019 reported Net Income (GAAP) to reflect actual net cash received from 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 2020 and 2019 and to add back impairment charges related to certain of EOG's assets in 2020 and 2019. 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
|
|
March 31, 2020
|
|
March 31, 2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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)
|
$ 31,003
|
|
$(21,190)
|
|
$ 9,813
|
|
$ 0.02
|
|
$827,236
|
|
$(191,810)
|
|
$635,426
|
|
$ 1.10
|
|
Adjustments:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(Gains) Losses on Mark-to-Market Commodity
Derivative Contracts
|
(1,205,773)
|
|
264,643
|
|
(941,130)
|
|
(1.62)
|
|
20,580
|
|
(4,533)
|
|
16,047
|
|
0.02
|
|
Net Cash Received from Settlements of
Commodity Derivative Contracts
|
84,373
|
|
(18,518)
|
|
65,855
|
|
0.11
|
|
20,846
|
|
(4,592)
|
|
16,254
|
|
0.03
|
|
Add: (Gains) Losses on Asset Dispositions, Net
|
(16,460)
|
|
3,613
|
|
(12,847)
|
|
(0.02)
|
|
3,836
|
|
(736)
|
|
3,100
|
|
0.01
|
|
Add: Impairments
|
1,516,316
|
|
(319,973)
|
|
1,196,343
|
|
2.06
|
|
23,745
|
|
(5,230)
|
|
18,515
|
|
0.03
|
|
Adjustments to Net Income
|
378,456
|
|
(70,235)
|
|
308,221
|
|
0.53
|
|
69,007
|
|
(15,091)
|
|
53,916
|
|
0.09
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted Net Income (Non-GAAP)
|
$ 409,459
|
|
$(91,425)
|
|
$ 318,034
|
|
$ 0.55
|
|
$896,243
|
|
$(206,901)
|
|
$689,342
|
|
$ 1.19
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Number of Common Shares (GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Basic
|
|
|
|
|
|
|
578,462
|
|
|
|
|
|
|
|
577,207
|
|
Diluted
|
|
|
|
|
|
|
580,283
|
|
|
|
|
|
|
|
580,222
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of Discretionary Cash Flow
|
|
(Unaudited; in thousands)
|
|
|
|
|
|
|
Calculation of Free Cash Flow
|
|
(Unaudited; in thousands)
|
|
|
|
|
|
|
The following chart reconciles the three-month periods ended March 31, 2020 and 2019 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, Changes in Components of Working Capital and Other Assets and Liabilities, and Changes in Components of Working Capital Associated with Investing 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 (before acquisitions) incurred (Non-GAAP) during such period, as is illustrated below for the three months ended March 31, 2020 and 2019. EOG management uses this information for comparative purposes within the industry.
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
March 31,
|
|
|
2020
|
|
2019
|
|
|
|
|
|
|
Net Cash Provided by Operating Activities (GAAP)
|
|
$2,584,918
|
|
$1,607,769
|
|
|
|
|
|
|
Adjustments:
|
|
|
|
|
|
Exploration Costs (excluding Stock-Based Compensation Expenses)
|
|
32,482
|
|
29,787
|
|
Other Non-Current Income Taxes - Net Receivable
|
|
112,704
|
|
102,918
|
|
Changes in Components of Working Capital and Other Assets
|
|
|
|
|
|
and Liabilities
|
|
|
|
|
|
Accounts Receivable
|
|
(722,163)
|
|
308,996
|
|
Inventories
|
|
(102,670)
|
|
18,979
|
|
Accounts Payable
|
|
(433,558)
|
|
(194,082)
|
|
Accrued Taxes Payable
|
|
54,605
|
|
(114,998)
|
|
Other Assets
|
|
(58,296)
|
|
6,935
|
|
Other Liabilities
|
|
66,078
|
|
54,092
|
|
Changes in Components of Working Capital Associated with
|
|
|
|
|
|
Investing Activities
|
|
132,082
|
|
94,381
|
|
|
|
|
|
|
Discretionary Cash Flow (Non-GAAP)
|
|
$1,666,182
|
|
$1,914,777
|
|
|
|
|
|
|
Discretionary Cash Flow (Non-GAAP) - Percentage Decrease
|
|
-13%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Discretionary Cash Flow (Non-GAAP)
|
|
$1,666,182
|
|
$1,914,777
|
|
Less:
|
|
|
|
|
|
Total Cash Capital Expenditures Before Acquisitions (Non-GAAP)(a)
|
|
(1,684,720)
|
|
(1,732,476)
|
|
Free Cash Flow (Non-GAAP)(b)
|
|
$ (18,538)
|
|
$ 182,301
|
|
|
|
|
|
|
|
|
|
|
|
(a) See below reconciliation of Total Expenditures (GAAP) to Total Cash Capital Expenditures Before Acquisitions (Non-GAAP) for the three-month periods ended March 31, 2020 and 2019:
|
|
|
|
|
|
|
Total Expenditures (GAAP)
|
|
$1,825,778
|
|
$2,101,919
|
|
Less:
|
|
|
|
|
|
Asset Retirement Costs
|
|
(19,608)
|
|
(5,156)
|
|
Non-Cash Expenditures of Other Property, Plant and Equipment
|
|
-
|
|
-
|
|
Non-Cash Acquisition Costs of Unproved Properties
|
|
(24,488)
|
|
(43,481)
|
|
Non-Cash Finance Leases
|
|
(48,958)
|
|
-
|
|
Acquisition Costs of Proved Properties
|
|
(48,004)
|
|
(320,806)
|
|
Total Cash Capital Expenditures Before Acquisitions (Non-GAAP)
|
|
$1,684,720
|
|
$1,732,476
|
|
|
|
|
|
|
(b) To better align the presentation of free cash flow for comparative purposes within the industry, free cash flow has been updated to exclude dividends paid (GAAP) as a reconciling item for the three-month period ending March 31, 2020. The comparative prior period has been revised for this change in presentation.
|
|
|
|
|
|
|
|
|
|
|
|
Maintenance Capital Expenditures
|
|
|
|
|
|
|
The capital expenditures required to fund drilling and infrastructure requirements to keep U.S. oil production in 2021 flat relative to anticipated 4Q 2020 U.S. oil production.
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of Discretionary Cash Flow
|
|
(Unaudited; in thousands)
|
|
|
|
|
|
|
|
Calculation of Free Cash Flow
|
|
(Unaudited; in thousands)
|
|
|
|
|
|
|
|
The following chart reconciles the twelve-month periods ended December 31, 2019, 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 (Payable) Receivable, 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 (before acquisitions) incurred (Non-GAAP) during such period, as is illustrated below for the twelve months ended December 31, 2019, 2018 and 2017. EOG management uses this information for comparative purposes within the industry.
|
|
|
|
|
|
|
|
Twelve Months Ended
|
|
December 31,
|
|
2019
|
|
2018
|
|
2017
|
|
|
|
|
|
|
|
Net Cash Provided by Operating Activities (GAAP)
|
$ 8,163,180
|
|
$ 7,768,608
|
|
$ 4,265,336
|
|
|
|
|
|
|
|
Adjustments:
|
|
|
|
|
|
|
Exploration Costs (excluding Stock-Based Compensation Expenses)
|
113,733
|
|
123,986
|
|
122,688
|
|
Other Non-Current Income Taxes - Net (Payable) Receivable
|
238,711
|
|
148,993
|
|
(513,404)
|
|
Changes in Components of Working Capital and Other Assets
|
|
|
|
|
|
|
and Liabilities
|
|
|
|
|
|
|
Accounts Receivable
|
91,792
|
|
368,180
|
|
392,131
|
|
Inventories
|
(90,284)
|
|
395,408
|
|
174,548
|
|
Accounts Payable
|
(168,539)
|
|
(439,347)
|
|
(324,192)
|
|
Accrued Taxes Payable
|
(40,122)
|
|
92,461
|
|
63,937
|
|
Other Assets
|
(358,001)
|
|
125,435
|
|
658,609
|
|
Other Liabilities
|
56,619
|
|
(10,949)
|
|
89,871
|
|
Changes in Components of Working Capital Associated with
|
|
|
|
|
|
|
Investing and Financing Activities
|
115,061
|
|
(301,083)
|
|
(89,992)
|
|
|
|
|
|
|
|
Discretionary Cash Flow (Non-GAAP)
|
$ 8,122,150
|
|
$ 8,271,692
|
|
$ 4,839,532
|
|
|
|
|
|
|
|
Discretionary Cash Flow (Non-GAAP) - Percentage Increase/Decrease
|
-2%
|
|
71%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Discretionary Cash Flow (Non-GAAP)
|
$ 8,122,150
|
|
$ 8,271,692
|
|
$ 4,839,532
|
|
Less:
|
|
|
|
|
|
|
Total Cash Capital Expenditures Before Acquisitions (Non-GAAP)(a)
|
(6,234,454)
|
|
(6,172,950)
|
|
(4,228,859)
|
|
Free Cash Flow (Non-GAAP)(b)
|
$ 1,887,696
|
|
$ 2,098,742
|
|
$ 610,673
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a) See below reconciliation of Total Expenditures (GAAP) to Total Cash Capital Expenditures Before Acquisitions (Non-GAAP) for the twelve-month periods ended December 31, 2019, 2018 and 2017:
|
|
|
|
|
|
|
|
Total Expenditures (GAAP)
|
$ 6,900,450
|
|
$ 6,706,359
|
|
$ 4,612,746
|
|
Less:
|
|
|
|
|
|
|
Asset Retirement Costs
|
(186,088)
|
|
(69,699)
|
|
(55,592)
|
|
Non-Cash Expenditures of Other Property, Plant and Equipment
|
(2,266)
|
|
(49,484)
|
|
-
|
|
Non-Cash Acquisition Costs of Unproved Properties
|
(97,704)
|
|
(290,542)
|
|
(255,711)
|
|
Acquisition Costs of Proved Properties
|
(379,938)
|
|
(123,684)
|
|
(72,584)
|
|
Total Cash Capital Expenditures Before Acquisitions (Non-GAAP)
|
$ 6,234,454
|
|
$ 6,172,950
|
|
$ 4,228,859
|
|
|
|
|
|
|
|
(b) To better align the presentation of free cash flow for comparative purposes within the industry, free cash flow has been updated to exclude dividends paid (GAAP) as a reconciling item for the twelve-month period ending December 31, 2019. Comparative prior periods have been revised for this change in presentation.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of Discretionary Cash Flow
|
|
(Unaudited; in thousands)
|
|
|
|
|
|
|
|
Calculation of Free Cash Flow
|
|
(Unaudited; in thousands)
|
|
|
|
|
|
|
|
The following chart reconciles the twelve-month periods ended December 31, 2014, 2013 and 2012 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), Excess Tax Benefits from Stock-Based Compensation, 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 (before acquisitions) incurred (Non-GAAP) during such period, as is illustrated below for the twelve months ended December 31, 2014, 2013 and 2012. EOG management uses this information for comparative purposes within the industry.
|
|
|
|
|
|
|
|
Twelve Months Ended
|
|
December 31,
|
|
2014
|
|
2013
|
|
2012
|
|
|
|
|
|
|
|
Net Cash Provided by Operating Activities (GAAP)
|
$ 8,649,155
|
|
$ 7,329,414
|
|
$ 5,236,777
|
|
|
|
|
|
|
|
Adjustments:
|
|
|
|
|
|
|
Exploration Costs (excluding Stock-Based Compensation Expenses)
|
157,453
|
|
134,531
|
|
159,182
|
|
Excess Tax Benefits from Stock-Based Compensation
|
99,459
|
|
55,831
|
|
67,035
|
|
Changes in Components of Working Capital and Other Assets
|
|
|
|
|
|
|
and Liabilities
|
|
|
|
|
|
|
Accounts Receivable
|
(84,982)
|
|
23,613
|
|
178,683
|
|
Inventories
|
161,958
|
|
(53,402)
|
|
156,762
|
|
Accounts Payable
|
(543,630)
|
|
(178,701)
|
|
17,150
|
|
Accrued Taxes Payable
|
(16,486)
|
|
(75,142)
|
|
(78,094)
|
|
Other Assets
|
14,448
|
|
109,567
|
|
118,520
|
|
Other Liabilities
|
(75,420)
|
|
20,382
|
|
(36,114)
|
|
Changes in Components of Working Capital Associated with
|
|
|
|
|
|
|
Investing and Financing Activities
|
103,414
|
|
51,361
|
|
(74,158)
|
|
|
|
|
|
|
|
Discretionary Cash Flow (Non-GAAP)
|
$ 8,465,369
|
|
$ 7,417,454
|
|
$ 5,745,743
|
|
|
|
|
|
|
|
Discretionary Cash Flow (Non-GAAP) - Percentage Increase
|
14%
|
|
29%
|
|
|
|
|
|
|
|
|
|
Discretionary Cash Flow (Non-GAAP)
|
$ 8,465,369
|
|
$ 7,417,454
|
|
$ 5,745,743
|
|
Less:
|
|
|
|
|
|
|
Total Cash Capital Expenditures Before Acquisitions (Non-GAAP)(a)
|
(8,292,090)
|
|
(7,101,791)
|
|
(7,539,994)
|
|
Free Cash Flow (Non-GAAP)(b)
|
$ 173,279
|
|
$ 315,663
|
|
$ (1,794,251)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a) See below reconciliation of Total Expenditures (GAAP) to Total Cash Capital Expenditures Before Acquisitions (Non-GAAP) for the twelve-month periods ended December 31, 2014, 2013 and 2012:
|
|
|
|
|
|
|
|
Total Expenditures (GAAP)
|
$ 8,631,906
|
|
$ 7,361,457
|
|
$ 7,753,828
|
|
Less:
|
|
|
|
|
|
|
Asset Retirement Costs
|
(195,630)
|
|
(134,445)
|
|
(126,987)
|
|
Non-Cash Expenditures of Other Property, Plant and Equipment
|
-
|
|
-
|
|
(65,791)
|
|
Non-Cash Acquisition Costs of Unproved Properties
|
(5,085)
|
|
(5,007)
|
|
(20,317)
|
|
Acquisition Costs of Proved Properties
|
(139,101)
|
|
(120,214)
|
|
(739)
|
|
Total Cash Capital Expenditures Before Acquisitions (Non-GAAP)
|
$ 8,292,090
|
|
$ 7,101,791
|
|
$ 7,539,994
|
|
|
|
|
|
|
|
(b) To better align the presentation of free cash flow for comparative purposes within the industry, free cash flow has been updated to exclude dividends paid (GAAP) as a reconciling item. Comparative prior periods presented herein have been revised for this change in presentation.
|
|
EOG RESOURCES, INC.
|
|
Total Expenditures
|
|
(Unaudited; in millions)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
Twelve Months Ended
|
|
|
March 31,
|
|
December 31,
|
|
|
2020
|
|
2019
|
|
2019
|
|
2018
|
|
2017
|
|
|
|
|
|
|
|
|
|
|
|
|
Exploration and Development Drilling
|
|
$1,313
|
|
$1,402
|
|
$4,951
|
|
$4,935
|
|
$3,132
|
|
Facilities
|
|
179
|
|
164
|
|
629
|
|
625
|
|
575
|
|
Leasehold Acquisitions
|
|
45
|
|
107
|
|
276
|
|
488
|
|
427
|
|
Property Acquisitions
|
|
48
|
|
321
|
|
380
|
|
124
|
|
73
|
|
Capitalized Interest
|
|
9
|
|
7
|
|
38
|
|
24
|
|
27
|
|
Subtotal
|
|
1,594
|
|
2,001
|
|
6,274
|
|
6,196
|
|
4,234
|
|
Exploration Costs
|
|
40
|
|
36
|
|
140
|
|
149
|
|
145
|
|
Dry Hole Costs
|
|
-
|
|
-
|
|
28
|
|
5
|
|
5
|
|
Exploration and Development Expenditures
|
|
1,634
|
|
2,037
|
|
6,442
|
|
6,350
|
|
4,384
|
|
Asset Retirement Costs
|
|
20
|
|
4
|
|
186
|
|
70
|
|
56
|
|
Total Exploration and Development Expenditures
|
|
1,654
|
|
2,041
|
|
6,628
|
|
6,420
|
|
4,440
|
|
Other Property, Plant and Equipment
|
|
172
|
|
61
|
|
272
|
|
286
|
|
173
|
|
Total Expenditures
|
|
$1,826
|
|
$2,102
|
|
$6,900
|
|
$6,706
|
|
$4,613
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of Adjusted EBITDAX
|
|
(Unaudited; in thousands)
|
|
|
|
|
|
|
|
|
The following chart adjusts the three-month periods ended March 31, 2020 and 2019 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 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
|
|
|
March 31,
|
|
|
2020
|
|
2019
|
|
|
|
|
|
|
|
|
|
Net Income (GAAP)
|
$
|
9,813
|
|
$
|
635,426
|
|
|
|
|
|
|
|
|
|
Adjustments:
|
|
|
|
|
|
|
|
Interest Expense, Net
|
|
44,690
|
|
|
54,906
|
|
|
Income Tax Provision
|
|
21,190
|
|
|
191,810
|
|
|
Depreciation, Depletion and Amortization
|
|
1,000,060
|
|
|
879,595
|
|
|
Exploration Costs
|
|
39,677
|
|
|
36,324
|
|
|
Dry Hole Costs
|
|
372
|
|
|
94
|
|
|
Impairments
|
|
1,572,935
|
|
|
72,356
|
|
|
EBITDAX (Non-GAAP)
|
|
2,688,737
|
|
|
1,870,511
|
|
|
Total (Gains) Losses on MTM Commodity Derivative Contracts
|
|
(1,205,773)
|
|
|
20,580
|
|
|
Net Cash Received from Settlements of Commodity
Derivative Contracts
|
|
84,373
|
|
|
20,846
|
|
|
(Gains) Losses on Asset Dispositions, Net
|
|
(16,460)
|
|
|
3,836
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDAX (Non-GAAP)
|
$
|
1,550,877
|
|
$
|
1,915,773
|
|
|
|
|
|
|
|
|
|
Adjusted EBITDAX (Non-GAAP) - Percentage Decrease
|
|
-19%
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of Net Debt and Total Capitalization
|
|
Calculation of Net Debt-to-Total Capitalization Ratio
|
|
(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
|
|
At
|
|
At
|
|
At
|
|
March 31,
|
|
December 31,
|
|
September 30,
|
|
June 30,
|
|
March 31,
|
|
2020
|
|
2019
|
|
2019
|
|
2019
|
|
2019
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders' Equity - (a)
|
$ 21,471
|
|
$ 21,641
|
|
$ 21,124
|
|
$ 20,630
|
|
$ 19,904
|
|
|
|
|
|
|
|
|
|
|
|
Current and Long-Term Debt (GAAP) - (b)
|
5,222
|
|
5,175
|
|
5,177
|
|
5,179
|
|
6,081
|
|
Less: Cash
|
(2,907)
|
|
(2,028)
|
|
(1,583)
|
|
(1,160)
|
|
(1,136)
|
|
Net Debt (Non-GAAP) - (c)
|
2,315
|
|
3,147
|
|
3,594
|
|
4,019
|
|
4,945
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (GAAP) - (a) + (b)
|
$ 26,693
|
|
$ 26,816
|
|
$ 26,301
|
|
$ 25,809
|
|
$ 25,985
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (Non-GAAP) - (a) + (c)
|
$ 23,786
|
|
$ 24,788
|
|
$ 24,718
|
|
$ 24,649
|
|
$ 24,849
|
|
|
|
|
|
|
|
|
|
|
|
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]
|
20%
|
|
19%
|
|
20%
|
|
20%
|
|
23%
|
|
|
|
|
|
|
|
|
|
|
|
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]
|
10%
|
|
13%
|
|
15%
|
|
16%
|
|
20%
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
|
|
Reconciliation of Net Debt and Total Capitalization
|
|
|
|
Calculation of Net Debt-to-Total Capitalization Ratio
|
|
|
|
(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
|
|
At
|
|
At
|
|
|
|
December 31,
|
|
September 30,
|
|
June 30,
|
|
March 31,
|
|
|
|
2018
|
|
2018
|
|
2018
|
|
2018
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders' Equity - (a)
|
$ 19,364
|
|
$ 18,538
|
|
$ 17,452
|
|
$ 16,841
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current and Long-Term Debt (GAAP) - (b)
|
6,083
|
|
6,435
|
|
6,435
|
|
6,435
|
|
|
|
Less: Cash
|
(1,556)
|
|
(1,274)
|
|
(1,008)
|
|
(816)
|
|
|
|
Net Debt (Non-GAAP) - (c)
|
4,527
|
|
5,161
|
|
5,427
|
|
5,619
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (GAAP) - (a) + (b)
|
$ 25,447
|
|
$ 24,973
|
|
$ 23,887
|
|
$ 23,276
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (Non-GAAP) - (a) + (c)
|
$ 23,891
|
|
$ 23,699
|
|
$ 22,879
|
|
$ 22,460
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]
|
24%
|
|
26%
|
|
27%
|
|
28%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]
|
19%
|
|
22%
|
|
24%
|
|
25%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
|
|
Reconciliation of Net Debt and Total Capitalization
|
|
|
|
Calculation of Net Debt-to-Total Capitalization Ratio
|
|
|
|
(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
|
|
At
|
|
At
|
|
|
|
December 31,
|
|
September 30,
|
|
June 30,
|
|
March 31,
|
|
|
|
2017
|
|
2017
|
|
2017
|
|
2017
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders' Equity - (a)
|
$ 16,283
|
|
$ 13,922
|
|
$ 13,902
|
|
$ 13,928
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current and Long-Term Debt (GAAP) - (b)
|
6,387
|
|
6,387
|
|
6,987
|
|
6,987
|
|
|
|
Less: Cash
|
(834)
|
|
(846)
|
|
(1,649)
|
|
(1,547)
|
|
|
|
Net Debt (Non-GAAP) - (c)
|
5,553
|
|
5,541
|
|
5,338
|
|
5,440
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (GAAP) - (a) + (b)
|
$ 22,670
|
|
$ 20,309
|
|
$ 20,889
|
|
$ 20,915
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (Non-GAAP) - (a) + (c)
|
$ 21,836
|
|
$ 19,463
|
|
$ 19,240
|
|
$ 19,368
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]
|
28%
|
|
31%
|
|
33%
|
|
33%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]
|
25%
|
|
28%
|
|
28%
|
|
28%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of Net Debt and Total Capitalization
|
|
Calculation of Net Debt-to-Total Capitalization Ratio
|
|
(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
|
|
At
|
|
At
|
|
At
|
|
December 31,
|
|
September 30,
|
|
June 30,
|
|
March 31,
|
|
December 31,
|
|
2016
|
|
2016
|
|
2016
|
|
2016
|
|
2015
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders' Equity - (a)
|
$ 13,982
|
|
$ 11,798
|
|
$ 12,057
|
|
$ 12,405
|
|
12,943
|
|
|
|
|
|
|
|
|
|
|
|
Current and Long-Term Debt (GAAP) - (b)
|
6,986
|
|
6,986
|
|
6,986
|
|
6,986
|
|
6,660
|
|
Less: Cash
|
(1,600)
|
|
(1,049)
|
|
(780)
|
|
(668)
|
|
(719)
|
|
Net Debt (Non-GAAP) - (c)
|
5,386
|
|
5,937
|
|
6,206
|
|
6,318
|
|
5,941
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (GAAP) - (a) + (b)
|
$ 20,968
|
|
$ 18,784
|
|
$ 19,043
|
|
$ 19,391
|
|
19,603
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (Non-GAAP) - (a) + (c)
|
$ 19,368
|
|
$ 17,735
|
|
$ 18,263
|
|
$ 18,723
|
|
18,884
|
|
|
|
|
|
|
|
|
|
|
|
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)]
|
33%
|
|
37%
|
|
37%
|
|
36%
|
|
34%
|
|
|
|
|
|
|
|
|
|
|
|
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)]
|
28%
|
|
33%
|
|
34%
|
|
34%
|
|
31%
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of Total Exploration and Development Expenditures
|
|
For Drilling Only and Total Exploration and Development Expenditures
|
|
Calculation of Reserve Replacement Costs ($ / BOE)
|
|
(Unaudited; in millions, except ratio data)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The following chart reconciles Total Costs Incurred in Exploration and Development Activities (GAAP) to Total Exploration and Development Expenditures for Drilling Only (Non-GAAP) and Total Exploration and Development Expenditures (Non-GAAP), as used in the calculation of Reserve Replacement Costs per Boe. There are numerous ways that industry participants present Reserve Replacement Costs, including "Drilling Only" and "All-In", which reflect total exploration and development expenditures divided by total net proved reserve additions from extensions and discoveries only, or from all sources. Combined with Reserve Replacement, these statistics provide management and investors with an indication of the results of the current year capital investment program. Reserve Replacement Cost statistics are widely recognized and reported by industry participants and are used by EOG management and other third parties for comparative purposes within the industry. Please note that the actual cost of adding reserves will vary from the reported statistics due to timing differences in reserve bookings and capital expenditures. Accordingly, some analysts use three or five year averages of reported statistics, while others prefer to estimate future costs. EOG has not included future capital costs to develop proved undeveloped reserves in exploration and development expenditures.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2019
|
|
2018
|
|
2017
|
|
2016
|
|
2015
|
|
2014
|
|
|
|
|
|
|
Total Costs Incurred in Exploration and Development Activities (GAAP)
|
|
$ 6,628.2
|
|
$ 6,419.7
|
|
$ 4,439.4
|
|
$ 6,445.2
|
|
$ 4,928.3
|
|
$ 7,904.8
|
|
Less: Asset Retirement Costs
|
|
(186.1)
|
|
(69.7)
|
|
(55.6)
|
|
19.9
|
|
(53.5)
|
|
(195.6)
|
|
Non-Cash Acquisition Costs of Unproved Properties
|
|
(97.7)
|
|
(290.5)
|
|
(255.7)
|
|
(3,101.8)
|
|
-
|
|
-
|
|
Acquisition Costs of Proved Properties
|
|
(379.9)
|
|
(123.7)
|
|
(72.6)
|
|
(749.0)
|
|
(480.6)
|
|
(139.1)
|
|
Total Exploration and Development Expenditures for Drilling Only (Non-GAAP) - (a)
|
|
$ 5,964.5
|
|
$ 5,935.8
|
|
$ 4,055.5
|
|
$ 2,614.3
|
|
$ 4,394.2
|
|
$ 7,570.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Costs Incurred in Exploration and Development Activities (GAAP)
|
|
$ 6,628.2
|
|
$ 6,419.7
|
|
$ 4,439.4
|
|
$ 6,445.2
|
|
$ 4,928.3
|
|
$ 7,904.8
|
|
Less: Asset Retirement Costs
|
|
(186.1)
|
|
(69.7)
|
|
(55.6)
|
|
19.9
|
|
(53.5)
|
|
(195.6)
|
|
Non-Cash Acquisition Costs of Unproved Properties
|
|
(97.7)
|
|
(290.5)
|
|
(255.7)
|
|
(3,101.8)
|
|
-
|
|
-
|
|
Non-Cash Acquisition Costs of Proved Properties
|
|
(52.3)
|
|
(70.9)
|
|
(26.2)
|
|
(732.3)
|
|
-
|
|
-
|
|
Total Exploration and Development Expenditures (Non-GAAP) - (b)
|
|
$ 6,292.1
|
|
$ 5,988.6
|
|
$ 4,101.9
|
|
$ 2,631.0
|
|
$ 4,874.8
|
|
$ 7,709.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Proved Reserve Additions From All Sources - Oil Equivalents (MMBoe)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Revisions Due to Price - (c)
|
|
(59.7)
|
|
34.8
|
|
154.0
|
|
(100.7)
|
|
(573.8)
|
|
52.2
|
|
Revisions Other Than Price
|
|
(0.3)
|
|
(39.5)
|
|
48.0
|
|
252.9
|
|
107.2
|
|
48.4
|
|
Purchases in Place
|
|
16.8
|
|
11.6
|
|
2.3
|
|
42.3
|
|
56.2
|
|
14.4
|
|
Extensions, Discoveries and Other Additions - (d)
|
|
750.0
|
|
669.7
|
|
420.8
|
|
209.0
|
|
245.9
|
|
519.2
|
|
Total Proved Reserve Additions - (e)
|
|
706.8
|
|
676.6
|
|
625.1
|
|
403.5
|
|
(164.5)
|
|
634.2
|
|
Sales in Place
|
|
(4.6)
|
|
(10.8)
|
|
(20.7)
|
|
(167.6)
|
|
(3.5)
|
|
(36.3)
|
|
Net Proved Reserve Additions From All Sources
|
|
702.2
|
|
665.8
|
|
604.4
|
|
235.9
|
|
(168.0)
|
|
597.9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Production
|
|
300.9
|
|
265.0
|
|
224.4
|
|
207.1
|
|
211.2
|
|
219.1
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
RESERVE REPLACEMENT COSTS ($ / Boe)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Drilling, Before Revisions - (a / d)
|
|
$ 7.95
|
|
$ 8.86
|
|
$ 9.64
|
|
$ 12.51
|
|
$ 17.87
|
|
$ 14.58
|
|
All-in Total, Net of Revisions - (b / e)
|
|
$ 8.90
|
|
$ 8.85
|
|
$ 6.56
|
|
$ 6.52
|
|
$ (29.63)
|
|
$ 12.16
|
|
All-in Total, Excluding Revisions Due to Price - (b / (e - c))
|
|
$ 8.21
|
|
$ 9.33
|
|
$ 8.71
|
|
$ 5.22
|
|
$ 11.91
|
|
$ 13.25
|
|
EOG RESOURCES, INC.
|
|
Crude Oil, NGLs 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 WTI 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 Intercontinental Exchange (ICE) Brent pricing and pricing in Cushing, Oklahoma (ICE Brent Differential). Presented below is a comprehensive summary of EOG's ICE Brent Differential basis swap contracts through May 5, 2020. The weighted average price differential expressed in $/Bbl represents the amount of addition to Cushing, Oklahoma, prices for the notional volumes expressed in Bbld covered by the basis swap contracts.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ICE Brent Differential Basis Swap Contracts
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Differential
|
|
|
|
|
|
|
|
|
|
(Bbld)
|
|
($/Bbl)
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
May 2020
|
|
|
|
|
|
|
|
10,000
|
|
$ 4.92
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG has also entered into crude oil basis swap contracts in order to fix the differential between pricing in Houston, Texas, and Cushing, Oklahoma (Houston Differential). Presented below is a comprehensive summary of EOG's Houston Differential basis swap contracts through May 5, 2020. The weighted average price differential expressed in $/Bbl represents the amount of addition to Cushing, Oklahoma, prices for the notional volumes expressed in Bbld covered by the basis swap contracts.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Houston Differential Basis Swap Contracts
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Differential
|
|
|
|
|
|
|
|
|
|
(Bbld)
|
|
($/Bbl)
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
May 2020 (closed)
|
|
|
|
|
|
|
10,000
|
|
$ 1.55
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG has also entered into crude oil swaps to fix the differential in pricing between the NYMEX calendar month average and the physical crude oil delivery month (Roll Differential). Presented below is a comprehensive summary of EOG's Roll Differential swap contracts through May 5, 2020. The weighted average price differential expressed in $/Bbl represents the amount of net addition (reduction) to delivery month prices for the notional volumes expressed in Bbld covered by the swap contracts.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Roll Differential Swap Contracts
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Differential
|
|
|
|
|
|
|
|
|
|
(Bbld)
|
|
($/Bbl)
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
February 1, 2020 through May 31, 2020 (closed)
|
|
|
10,000
|
|
$ 0.70
|
|
June 2020
|
|
|
|
|
|
|
|
10,000
|
|
0.70
|
|
July 1, 2020 through September 30, 2020
|
|
|
|
|
110,000
|
|
(1.16)
|
|
October 1, 2020 through December 31, 2020
|
|
|
|
|
93,000
|
|
(1.16)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
In May 2020, EOG entered into crude oil Roll Differential contracts for the period from October 1, 2020 through December 31, 2020, with notional volumes of 17,000 Bbld at a weighted average price differential of $(1.01) per Bbl. These contracts partially offset certain outstanding Roll Differential contracts for the same time period with notional volumes of 17,000 Bbld at a weighted average price differential of $(1.16) per Bbl. EOG expects to pay net cash of $0.2 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Presented below is a comprehensive summary of EOG's crude oil NYMEX WTI price swap contracts through May 5, 2020, with notional volumes expressed in Bbld and prices expressed in $/Bbl.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude Oil NYMEX WTI Price Swap Contracts
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
(Bbld)
|
|
($/Bbl)
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
January 1, 2020 through March 31, 2020 (closed)
|
|
|
|
200,000
|
|
$ 59.33
|
|
April 2020 (closed)
|
|
|
|
|
|
|
265,000
|
|
51.36
|
|
May 1, 2020 through June 30, 2020
|
|
|
265,000
|
|
51.36
|
|
July 2020
|
|
|
|
|
|
|
|
254,000
|
|
42.36
|
|
August 1, 2020 through September 30, 2020
|
|
|
|
|
154,000
|
|
50.42
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
In April and May 2020, EOG entered into crude oil NYMEX WTI price swap contracts for the period from October 1, 2020 through December 31, 2020, with notional volumes of 47,000 Bbld at a weighted average price of $30.04 per Bbl. These contracts offset the remaining NYMEX WTI price swap contracts for the same time period with notional volumes of 47,000 Bbld at a weighted average price of $31.00 per Bbl. EOG expects to receive net cash of $4.1 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Presented below is a comprehensive summary of EOG's crude oil ICE Brent price swap contracts through May 5, 2020, with notional volumes expressed in Bbld and prices expressed in $/Bbl.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude Oil ICE Brent Price Swap Contracts
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
(Bbld)
|
|
($/Bbl)
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
April 2020 (closed)
|
|
|
|
|
|
|
75,000
|
|
$ 25.66
|
|
May 2020
|
|
|
|
|
|
|
|
35,000
|
|
26.53
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Presented below is a comprehensive summary of EOG's Mont Belvieu propane (non-TET) financial price swap contracts (Mont Belvieu Propane Price Swap Contracts) through May 5, 2020, with notional volumes expressed in Bbld and prices expressed in $/Bbl.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Mont Belvieu Propane Price Swap Contracts
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
(Bbld)
|
|
($/Bbl)
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
January 1, 2020 through February 29, 2020 (closed)
|
|
|
4,000
|
|
$ 21.34
|
|
March 1, 2020 through April 30, 2020 (closed)
|
|
|
|
25,000
|
|
17.92
|
|
May 1, 2020 through December 31, 2020
|
|
|
|
|
7,000
|
|
17.92
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
In April and May 2020, EOG entered into Mont Belvieu Propane Price Swap Contracts for the period from May 1, 2020 through December 31, 2020, with notional volumes of 18,000 Bbld at a weighted average price of $15.68 per Bbl. These contracts partially offset certain outstanding Mont Belvieu Propane Price Swap Contracts for the same time period with notional volumes of 18,000 Bbld at a weighted average price of $17.92 per Bbl. EOG expects to receive net cash of $9.9 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Presented below is a comprehensive summary of EOG's natural gas price swap contracts through May 5, 2020, with notional volumes expressed in MMBtud and prices expressed in $/MMBtu.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural Gas Price Swap Contracts
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
(MMBtud)
|
|
($/MMBtu)
|
|
2021
|
|
|
|
|
|
|
|
|
|
|
|
January 1, 2021 through December 31, 2021
|
|
|
|
|
50,000
|
|
$ 2.75
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG has entered into natural gas collar contracts, which establish ceiling and floor prices for the sale of notional volumes of natural gas as specified in the collar contracts. The collars require that EOG pay the difference between the ceiling price and the 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 ceiling price. The collars grant EOG the right to receive the difference between the floor price and the Henry Hub Index Price in the event the Henry Hub Index Price is below the floor price. On March 24, 2020, EOG executed the early termination provision granting EOG the right to terminate certain 2020 natural gas collar contracts with notional volumes of 250,000 MMBtud at a weighted average ceiling price of $2.50 per MMBtu and a weighted average floor price of $2.00 per MMBtu for the period April 1, 2020 through July 31, 2020. The net cash EOG received for settling these contracts was $7.8 million. Presented below is a comprehensive summary of EOG's natural gas collar contracts through May 5, 2020, with notional volumes expressed in MMBtud and prices expressed in $/MMBtu.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural Gas Collar Contracts
|
|
|
|
|
|
|
|
|
|
Weighted Average Price ($/MMBtu)
|
|
|
|
|
|
|
|
Volume (MMBtud)
|
|
Ceiling Price
|
|
Floor Price
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
April 1, 2020 through July 31, 2020 (closed)
|
|
|
250,000
|
|
$ 2.50
|
|
$ 2.00
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
On April 14, 2020, EOG entered into natural gas collar contracts for the period August 1, 2020 through October 31, 2020, with notional volumes of 250,000 MMBtud at a ceiling price of $2.50 per MMBtu and a floor price of $2.00 per MMBtu. These contracts offset the remaining natural gas collar contracts for the same time period with notional volumes of 250,000 MMBtud at a ceiling price of $2.50 per MMBtu and a floor price of $2.00 per MMBtu. EOG expects to receive net cash of $1.1 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Prices received by EOG for its natural gas production generally vary from NYMEX Henry Hub prices due to adjustments for delivery location (basis) and other factors. EOG has entered into natural gas basis swap contracts in order to fix the differential between pricing in the Rocky Mountain area and NYMEX Henry Hub prices (Rockies Differential). Presented below is a comprehensive summary of EOG's Rockies Differential basis swap contracts through May 5, 2020. The weighted average price differential expressed in $/MMBtu represents the amount of reduction to NYMEX Henry Hub prices for the notional volumes expressed in MMBtud covered by the basis swap contracts.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Rockies Differential Basis Swap Contracts
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Differential
|
|
|
|
|
|
|
|
|
|
(MMBtud)
|
|
($/MMBtu)
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
January 1, 2020 through May 31, 2020 (closed)
|
|
|
|
30,000
|
|
$ 0.55
|
|
June 1, 2020 through December 31, 2020
|
|
|
|
|
30,000
|
|
0.55
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG has also entered into natural gas basis swap contracts in order to fix the differential between pricing at the Houston Ship Channel (HSC) and NYMEX Henry Hub prices (HSC Differential). On March 27, 2020, EOG executed the early termination provision granting EOG the right to terminate certain 2020 HSC Differential basis swaps with notional volumes of 60,000 MMBtud at a weighted average price differential of $0.05 per MMBtu for the period April 1, 2020 through December 31, 2020. The net cash EOG paid for settling these contracts was $0.4 million. Presented below is a comprehensive summary of EOG's HSC Differential basis swap contracts through May 5, 2020. The weighted average price differential expressed in $/MMBtu represents the amount of reduction to NYMEX Henry Hub prices for the notional volumes expressed in MMBtud covered by the basis swap contracts.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
HSC Differential Basis Swap Contracts
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Differential
|
|
|
|
|
|
|
|
|
|
(MMBtud)
|
|
($/MMBtu)
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
January 1, 2020 through December 31, 2020 (closed)
|
|
|
60,000
|
|
$ 0.05
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG has also entered into natural gas basis swap contracts in order to fix the differential between pricing at the Waha Hub in West Texas and NYMEX Henry Hub prices (Waha Differential). Presented below is a comprehensive summary of EOG's Waha Differential basis swap contracts through May 5, 2020. The weighted average price differential expressed in $/MMBtu represents the amount of reduction to NYMEX Henry Hub prices for the notional volumes expressed in MMBtud covered by the basis swap contracts.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Waha Differential Basis Swap Contracts
|
|
|
|
|
|
|
|
|
|
|
|
Weighted
|
|
|
|
|
|
|
|
|
|
|
|
Average Price
|
|
|
|
|
|
|
|
|
|
Volume
|
|
Differential
|
|
|
|
|
|
|
|
|
|
(MMBtud)
|
|
($/MMBtu)
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
January 1, 2020 through April 30, 2020 (closed)
|
|
|
|
50,000
|
|
$ 1.40
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
In April 2020, EOG entered into Waha Differential basis swap contracts for the period from May 1, 2020 through December 31, 2020, with notional volumes of 50,000 MMBtud at a weighted average price differential of $0.43 per MMBtu. These contracts offset the remaining Waha Differential basis swap contracts for the same time period with notional volumes of 50,000 MMBtud at a weighted average price differential of $1.40 MMBtu. EOG expects to pay net cash of $11.9 million for the settlement of these contracts. The offsetting contracts were excluded from the above table.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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
|
|
|
|
|
|
WTI
|
West Texas Intermediate
|
|
|
|
|
|
|
|
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.
|
|
Reconciliation of After-Tax Net Interest Expense, Adjusted Net Income,
|
|
Net Debt and Total Capitalization
|
|
Calculations of Return on Capital Employed and Return on Equity
|
|
(Unaudited; in millions, except ratio data)
|
|
|
|
|
|
|
|
|
|
|
The following chart reconciles Net Interest Expense (GAAP), Net Income (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Adjusted Net Income (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, 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.
|
|
|
|
|
|
|
|
|
|
|
|
2019
|
|
|
2018
|
|
|
2017
|
|
Return on Capital Employed (ROCE) (Non-GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Interest Expense (GAAP)
|
$
|
185
|
|
$
|
245
|
|
|
|
|
Tax Benefit Imputed (based on 21%)
|
|
(39)
|
|
|
(51)
|
|
|
|
|
After-Tax Net Interest Expense (Non-GAAP) - (a)
|
$
|
146
|
|
$
|
194
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income (GAAP) - (b)
|
$
|
2,735
|
|
$
|
3,419
|
|
|
|
|
Adjustments to Net Income, Net of Tax (See Accompanying Schedule)
|
|
158
|
(1)
|
|
(201)
|
(2)
|
|
|
|
Adjusted Net Income (Non-GAAP) - (c)
|
$
|
2,893
|
|
$
|
3,218
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders' Equity - (d)
|
$
|
21,641
|
|
$
|
19,364
|
|
$
|
16,283
|
|
|
|
|
|
|
|
|
|
|
Average Total Stockholders' Equity * - (e)
|
$
|
20,503
|
|
$
|
17,824
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current and Long-Term Debt (GAAP) - (f)
|
$
|
5,175
|
|
$
|
6,083
|
|
$
|
6,387
|
|
Less: Cash
|
|
(2,028)
|
|
|
(1,556)
|
|
|
(834)
|
|
Net Debt (Non-GAAP) - (g)
|
$
|
3,147
|
|
$
|
4,527
|
|
$
|
5,553
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (GAAP) - (d) + (f)
|
$
|
26,816
|
|
$
|
25,447
|
|
$
|
22,670
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (Non-GAAP) - (d) + (g)
|
$
|
24,788
|
|
$
|
23,891
|
|
$
|
21,836
|
|
|
|
|
|
|
|
|
|
|
Average Total Capitalization (Non-GAAP) * - (h)
|
$
|
24,340
|
|
$
|
22,864
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROCE (GAAP Net Income) - [(a) + (b)] / (h)
|
|
11.8%
|
|
|
15.8%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROCE (Non-GAAP Adjusted Net Income) - [(a) + (c)] / (h)
|
|
12.5%
|
|
|
14.9%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Return on Equity (ROE)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROE (GAAP Net Income) - (b) / (e)
|
|
13.3%
|
|
|
19.2%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROE (Non-GAAP Adjusted Net Income) - (c) / (e)
|
|
14.1%
|
|
|
18.1%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* Average for the current and immediately preceding year
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjustments to Net Income (GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1) See below schedule for detail of adjustments to Net Income (GAAP) in 2019:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2019
|
|
|
Before
|
|
|
Income Tax
|
|
|
After
|
|
|
Tax
|
|
|
Impact
|
|
|
Tax
|
|
Adjustments:
|
|
|
|
|
|
|
|
|
|
Add: Mark-to-Market Commodity Derivative Contracts Impact
|
$
|
51
|
|
$
|
(11)
|
|
$
|
40
|
|
Add: Impairments of Certain Assets
|
|
275
|
|
|
(60)
|
|
|
215
|
|
Less: Net Gains on Asset Dispositions
|
|
(124)
|
|
|
27
|
|
|
(97)
|
|
Total
|
$
|
202
|
|
$
|
(44)
|
|
$
|
158
|
|
|
|
|
|
|
|
|
|
|
(2) See below schedule for detail of adjustments to Net Income (GAAP) in 2018:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended December 31, 2018
|
|
|
Before
|
|
|
Income Tax
|
|
|
After
|
|
|
Tax
|
|
|
Impact
|
|
|
Tax
|
|
Adjustments:
|
|
|
|
|
|
|
|
|
|
Add: Mark-to-Market Commodity Derivative Contracts Impact
|
$
|
(93)
|
|
$
|
20
|
|
$
|
(73)
|
|
Add: Impairments of Certain Assets
|
|
153
|
|
|
(34)
|
|
|
119
|
|
Less: Net Gains on Asset Dispositions
|
|
(175)
|
|
|
38
|
|
|
(137)
|
|
Less: Tax Reform Impact
|
|
-
|
|
|
(110)
|
|
|
(110)
|
|
Total
|
$
|
(115)
|
|
$
|
(86)
|
|
$
|
(201)
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of After-Tax Net Interest Expense,
|
|
Net Debt and Total Capitalization
|
|
Calculation of Return on Capital Employed
|
|
(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.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2017
|
|
2016
|
|
2015
|
|
2014
|
|
2013
|
|
Return on Capital Employed (ROCE) (Non-GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
(Calculated Using GAAP Net Income)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Interest Expense (GAAP)
|
$
|
274
|
$
|
282
|
$
|
237
|
$
|
201
|
$
|
235
|
|
Tax Benefit Imputed (based on 35%)
|
|
(96)
|
|
(99)
|
|
(83)
|
|
(70)
|
|
(82)
|
|
After-Tax Net Interest Expense (Non-GAAP) - (a)
|
$
|
178
|
$
|
183
|
$
|
154
|
$
|
131
|
$
|
153
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income (Loss) (GAAP) - (b)
|
$
|
2,583
|
$
|
(1,097)
|
$
|
(4,525)
|
$
|
2,915
|
$
|
2,197
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders' Equity - (d)
|
$
|
16,283
|
$
|
13,982
|
$
|
12,943
|
$
|
17,713
|
$
|
15,418
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Total Stockholders' Equity * - (e)
|
$
|
15,133
|
$
|
13,463
|
$
|
15,328
|
$
|
16,566
|
$
|
14,352
|
|
|
|
|
|
|
|
|
|
|
|
|
Current and Long-Term Debt (GAAP) - (f)
|
$
|
6,387
|
$
|
6,986
|
$
|
6,655
|
$
|
5,906
|
$
|
5,909
|
|
Less: Cash
|
|
(834)
|
|
(1,600)
|
|
(719)
|
|
(2,087)
|
|
(1,318)
|
|
Net Debt (Non-GAAP) - (g)
|
$
|
5,553
|
$
|
5,386
|
$
|
5,936
|
$
|
3,819
|
$
|
4,591
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (GAAP) - (d) + (f)
|
$
|
22,670
|
$
|
20,968
|
$
|
19,598
|
$
|
23,619
|
$
|
21,327
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (Non-GAAP) - (d) + (g)
|
$
|
21,836
|
$
|
19,368
|
$
|
18,879
|
$
|
21,532
|
$
|
20,009
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Total Capitalization (Non-GAAP) * - (h)
|
$
|
20,602
|
$
|
19,124
|
$
|
20,206
|
$
|
20,771
|
$
|
19,365
|
|
|
|
|
|
|
|
|
|
|
|
|
ROCE (GAAP Net Income) - [(a) + (b)] / (h)
|
|
13.4%
|
|
-4.8%
|
|
-21.6%
|
|
14.7%
|
|
12.1%
|
|
|
|
|
|
|
|
|
|
|
|
|
Return on Equity (ROE) (GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROE (GAAP Net Income) - (b) / (e)
|
|
17.1%
|
|
-8.1%
|
|
-29.5%
|
|
17.6%
|
|
15.3%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* Average for the current and immediately preceding year
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of After-Tax Net Interest Expense,
|
|
Net Debt and Total Capitalization
|
|
Calculation of Return on Capital Employed
|
|
(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.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2012
|
|
2011
|
|
2010
|
|
2009
|
|
2008
|
|
Return on Capital Employed (ROCE) (Non-GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
(Calculated Using GAAP Net Income)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Interest Expense (GAAP)
|
$
|
214
|
$
|
210
|
$
|
130
|
$
|
101
|
$
|
52
|
|
Tax Benefit Imputed (based on 35%)
|
|
(75)
|
|
(74)
|
|
(46)
|
|
(35)
|
|
(18)
|
|
After-Tax Net Interest Expense (Non-GAAP) - (a)
|
$
|
139
|
$
|
136
|
$
|
84
|
$
|
66
|
$
|
34
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income (Loss) (GAAP) - (b)
|
$
|
570
|
$
|
1,091
|
$
|
161
|
$
|
547
|
$
|
2,437
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders' Equity - (d)
|
$
|
13,285
|
$
|
12,641
|
$
|
10,232
|
$
|
9,998
|
$
|
9,015
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Total Stockholders' Equity * - (e)
|
$
|
12,963
|
$
|
11,437
|
$
|
10,115
|
$
|
9,507
|
$
|
8,003
|
|
|
|
|
|
|
|
|
|
|
|
|
Current and Long-Term Debt (GAAP) - (f)
|
$
|
6,312
|
$
|
5,009
|
$
|
5,223
|
$
|
2,797
|
$
|
1,897
|
|
Less: Cash
|
|
(876)
|
|
(616)
|
|
(789)
|
|
(686)
|
|
(331)
|
|
Net Debt (Non-GAAP) - (g)
|
$
|
5,436
|
$
|
4,393
|
$
|
4,434
|
$
|
2,111
|
$
|
1,566
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (GAAP) - (d) + (f)
|
$
|
19,597
|
$
|
17,650
|
$
|
15,455
|
$
|
12,795
|
$
|
10,912
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (Non-GAAP) - (d) + (g)
|
$
|
18,721
|
$
|
17,034
|
$
|
14,666
|
$
|
12,109
|
$
|
10,581
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Total Capitalization (Non-GAAP) * - (h)
|
$
|
17,878
|
$
|
15,850
|
$
|
13,388
|
$
|
11,345
|
$
|
9,351
|
|
|
|
|
|
|
|
|
|
|
|
|
ROCE (GAAP Net Income) - [(a) + (b)] / (h)
|
|
4.0%
|
|
7.7%
|
|
1.8%
|
|
5.4%
|
|
26.4%
|
|
|
|
|
|
|
|
|
|
|
|
|
Return on Equity (ROE) (GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROE (GAAP Net Income) - (b) / (e)
|
|
4.4%
|
|
9.5%
|
|
1.6%
|
|
5.8%
|
|
30.5%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* Average for the current and immediately preceding year
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of After-Tax Net Interest Expense,
|
|
Net Debt and Total Capitalization
|
|
Calculation of Return on Capital Employed
|
|
(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
|
|
Return on Capital Employed (ROCE) (Non-GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
(Calculated Using GAAP Net Income)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Interest Expense (GAAP)
|
$
|
47
|
$
|
43
|
$
|
63
|
$
|
63
|
$
|
59
|
|
Tax Benefit Imputed (based on 35%)
|
|
(16)
|
|
(15)
|
|
(22)
|
|
(22)
|
|
(21)
|
|
After-Tax Net Interest Expense (Non-GAAP) - (a)
|
$
|
31
|
$
|
28
|
$
|
41
|
$
|
41
|
$
|
38
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income (Loss) (GAAP) - (b)
|
$
|
1,090
|
$
|
1,300
|
$
|
1,260
|
$
|
625
|
$
|
430
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders' Equity - (d)
|
$
|
6,990
|
$
|
5,600
|
$
|
4,316
|
$
|
2,945
|
$
|
2,223
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Total Stockholders' Equity * - (e)
|
$
|
6,295
|
$
|
4,958
|
$
|
3,631
|
$
|
2,584
|
$
|
1,948
|
|
|
|
|
|
|
|
|
|
|
|
|
Current and Long-Term Debt (GAAP) - (f)
|
$
|
1,185
|
$
|
733
|
$
|
985
|
$
|
1,078
|
$
|
1,109
|
|
Less: Cash
|
|
(54)
|
|
(218)
|
|
(644)
|
|
(21)
|
|
(4)
|
|
Net Debt (Non-GAAP) - (g)
|
$
|
1,131
|
$
|
515
|
$
|
341
|
$
|
1,057
|
$
|
1,105
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (GAAP) - (d) + (f)
|
$
|
8,175
|
$
|
6,333
|
$
|
5,301
|
$
|
4,023
|
$
|
3,332
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (Non-GAAP) - (d) + (g)
|
$
|
8,121
|
$
|
6,115
|
$
|
4,657
|
$
|
4,002
|
$
|
3,328
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Total Capitalization (Non-GAAP) * - (h)
|
$
|
7,118
|
$
|
5,386
|
$
|
4,330
|
$
|
3,665
|
$
|
3,068
|
|
|
|
|
|
|
|
|
|
|
|
|
ROCE (GAAP Net Income) - [(a) + (b)] / (h)
|
|
15.7%
|
|
24.7%
|
|
30.0%
|
|
18.2%
|
|
15.3%
|
|
|
|
|
|
|
|
|
|
|
|
|
Return on Equity (ROE) (GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROE (GAAP Net Income) - (b) / (e)
|
|
17.3%
|
|
26.2%
|
|
34.7%
|
|
24.2%
|
|
22.1%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* Average for the current and immediately preceding year
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
Reconciliation of After-Tax Net Interest Expense,
|
|
Net Debt and Total Capitalization
|
|
Calculation of Return on Capital Employed
|
|
(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.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2002
|
|
2001
|
|
2000
|
|
1999
|
|
1998
|
|
Return on Capital Employed (ROCE) (Non-GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
(Calculated Using GAAP Net Income)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Interest Expense (GAAP)
|
$
|
60
|
$
|
45
|
$
|
61
|
$
|
62
|
|
|
|
Tax Benefit Imputed (based on 35%)
|
|
(21)
|
|
(16)
|
|
(21)
|
|
(22)
|
|
|
|
After-Tax Net Interest Expense (Non-GAAP) - (a)
|
$
|
39
|
$
|
29
|
$
|
40
|
$
|
40
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net Income (Loss) (GAAP) - (b)
|
$
|
87
|
$
|
399
|
$
|
397
|
$
|
569
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Stockholders' Equity - (d)
|
$
|
1,672
|
$
|
1,643
|
$
|
1,381
|
$
|
1,130
|
$
|
1,280
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Total Stockholders' Equity * - (e)
|
$
|
1,658
|
$
|
1,512
|
$
|
1,256
|
$
|
1,205
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Current and Long-Term Debt (GAAP) - (f)
|
$
|
1,145
|
$
|
856
|
$
|
859
|
$
|
990
|
$
|
1,143
|
|
Less: Cash
|
|
(10)
|
|
(3)
|
|
(20)
|
|
(25)
|
|
(6)
|
|
Net Debt (Non-GAAP) - (g)
|
$
|
1,135
|
$
|
853
|
$
|
839
|
$
|
965
|
$
|
1,137
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (GAAP) - (d) + (f)
|
$
|
2,817
|
$
|
2,499
|
$
|
2,240
|
$
|
2,120
|
$
|
2,423
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Capitalization (Non-GAAP) - (d) + (g)
|
$
|
2,807
|
$
|
2,496
|
$
|
2,220
|
$
|
2,095
|
$
|
2,417
|
|
|
|
|
|
|
|
|
|
|
|
|
Average Total Capitalization (Non-GAAP) * - (h)
|
$
|
2,652
|
$
|
2,358
|
$
|
2,158
|
$
|
2,256
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROCE (GAAP Net Income) - [(a) + (b)] / (h)
|
|
4.8%
|
|
18.2%
|
|
20.2%
|
|
27.0%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Return on Equity (ROE) (GAAP)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
ROE (GAAP Net Income) - (b) / (e)
|
|
5.2%
|
|
26.4%
|
|
31.6%
|
|
47.2%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 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)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1st Quarter
|
|
|
|
|
2020
|
|
2019
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash Operating Expenses (GAAP)*
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease and Well
|
|
$ 329,659
|
|
$ 336,291
|
|
|
|
|
|
|
|
|
|
|
Transportation Costs
|
|
208,296
|
|
176,522
|
|
|
|
|
|
|
|
|
|
|
General and Administrative
|
|
114,273
|
|
106,672
|
|
|
|
|
|
|
|
|
|
|
Cash Operating Expenses
|
|
652,228
|
|
619,485
|
|
|
|
|
|
|
|
|
|
|
Less: Non-GAAP Adjustments
|
|
-
|
|
-
|
|
|
|
|
|
|
|
|
|
|
Adjusted Cash Operating Expenses (Non-GAAP) - (a)
|
|
$ 652,228
|
|
$ 619,485
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Volume - Thousand Barrels of Oil Equivalent - (b)
|
|
79,548
|
|
69,623
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted Cash Operating Expenses Per Boe (Non-GAAP) - (a) / (b)
|
|
$ 8.20
|
(c)
|
$ 8.90
|
(d)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted Cash Operating Expenses Per Boe (Non-GAAP) -
Percentage Decrease
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1Q20 compared to 1Q19 - [(c) - (d)] / (d)
|
|
-8%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* Includes stock compensation expense and other non-cash items.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
Cash Operating Expenses per Barrel of Oil Equivalent (Boe)
|
|
(Unaudited; in thousands, except per Boe amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended
|
|
|
|
December 31,
|
|
|
|
2019
|
|
2018
|
|
2017
|
|
2016
|
|
2015
|
|
2014
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash Operating Expenses (GAAP)*
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease and Well
|
|
$1,366,993
|
|
$1,282,678
|
|
$1,044,847
|
|
$ 927,452
|
|
$1,182,282
|
|
$1,416,413
|
|
|
Transportation Costs
|
|
758,300
|
|
746,876
|
|
740,352
|
|
764,106
|
|
849,319
|
|
972,176
|
|
|
General and Administrative
|
|
489,397
|
|
426,969
|
|
434,467
|
|
394,815
|
|
366,594
|
|
402,010
|
|
|
Cash Operating Expenses
|
|
2,614,690
|
|
2,456,523
|
|
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)
|
|
$2,614,690
|
|
$2,456,523
|
|
$2,201,880
|
|
$2,039,219
|
|
$2,378,840
|
|
$2,790,599
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Volume - Thousand Barrels of Oil Equivalent - (b)
|
|
298,565
|
|
262,516
|
|
222,251
|
|
204,929
|
|
208,862
|
|
217,073
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted Cash Operating Expenses Per Boe (Non-GAAP) - (a) / (b)
|
|
$ 8.76
|
(c)
|
$ 9.36
|
(d)
|
$ 9.91
|
(e)
|
$ 9.95
|
(f)
|
$ 11.39
|
(g)
|
$ 12.86
|
(h)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Adjusted Cash Operating Expenses Per Boe (Non-GAAP) -
Percentage Decrease
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
2019 compared to 2018 - [(c) - (d)] / (d)
|
|
-6%
|
|
|
|
|
|
|
|
|
|
|
|
|
2019 compared to 2017 - [(c) - (e)] / (e)
|
|
-12%
|
|
|
|
|
|
|
|
|
|
|
|
|
2019 compared to 2016 - [(c) - (f)] / (f)
|
|
-12%
|
|
|
|
|
|
|
|
|
|
|
|
|
2019 compared to 2015 - [(c) - (g)] / (g)
|
|
-23%
|
|
|
|
|
|
|
|
|
|
|
|
|
2019 compared to 2014 - [(c) - (h)] / (h)
|
|
-32%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
* 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)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended
|
|
|
|
|
|
|
|
|
March 31,
|
|
|
|
|
|
|
|
|
2020
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Volume - Thousand Barrels of Oil Equivalent - (a)
|
|
79,548
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude Oil and Condensate
|
|
$ 2,065,498
|
|
|
|
|
|
|
|
Natural Gas Liquids
|
|
160,535
|
|
|
|
|
|
|
|
Natural Gas
|
|
209,764
|
|
|
|
|
|
|
|
Total Wellhead Revenues - (b)
|
|
$ 2,435,797
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Costs
|
|
|
|
|
|
|
|
|
|
Lease and Well
|
|
$ 329,659
|
|
|
|
|
|
|
|
Transportation Costs
|
|
208,296
|
|
|
|
|
|
|
|
Gathering and Processing Costs
|
|
128,482
|
|
|
|
|
|
|
|
General and Administrative
|
|
114,273
|
|
|
|
|
|
|
|
Taxes Other Than Income
|
|
157,360
|
|
|
|
|
|
|
|
Interest Expense, Net
|
|
44,690
|
|
|
|
|
|
|
|
Total Cash Operating Cost (excluding DD&A and Total
Exploration Costs) - (c)
|
|
$ 982,760
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation, Depletion and Amortization (DD&A)
|
|
1,000,060
|
|
|
|
|
|
|
|
Total Operating Cost (excluding Total Exploration Costs) - (d)
|
|
$ 1,982,820
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Exploration Costs
|
|
$ 39,677
|
|
|
|
|
|
|
|
Dry Hole Costs
|
|
372
|
|
|
|
|
|
|
|
Impairments
|
|
1,572,935
|
|
|
|
|
|
|
|
Total Exploration Costs
|
|
1,612,984
|
|
|
|
|
|
|
|
Less: Impairments (Non-GAAP)
|
|
(1,516,316)
|
|
|
|
|
|
|
|
Total Exploration Costs (Non-GAAP)
|
|
$ 96,668
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Cost (Non-GAAP) (including Total
Exploration Costs) - (e)
|
|
$ 2,079,488
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Wellhead Revenue per Boe - (b) / (a)
|
|
$ 30.62
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Cash Operating Cost per Boe (excluding DD&A
and Total Exploration Costs) - (c) / (a)
|
|
$ 12.36
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Margin per Boe (excluding DD&A
and Total Exploration Costs) - [(b) / (a) - (c) / (a)]
|
|
$ 18.26
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Cost per Boe (excluding Total
Exploration Costs) - (d) / (a)
|
|
$ 24.93
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Margin per Boe (excluding Total
Exploration Costs) - [(b) / (a) - (d) / (a)]
|
|
$ 5.69
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Cost per Boe (Non-GAAP) (including
Total Exploration Costs) - (e) / (a)
|
|
$ 26.15
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Margin per Boe (Non-GAAP)
(including Total Exploration Costs) - [(b) / (a) - (e) / (a)]
|
|
$ 4.47
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
|
|
Cost per Barrel of Oil Equivalent (Boe)
|
|
|
|
(Unaudited; in thousands, except per Boe amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended
|
|
|
|
|
December 31,
|
|
|
|
|
2019
|
|
2018
|
|
2017
|
|
|
|
|
|
|
|
|
|
|
|
|
Volume - Thousand Barrels of Oil Equivalent - (a)
|
|
298,565
|
|
262,516
|
|
222,251
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude Oil and Condensate
|
|
$ 9,612,532
|
|
$ 9,517,440
|
|
$ 6,256,396
|
|
|
|
Natural Gas Liquids
|
|
784,818
|
|
1,127,510
|
|
729,561
|
|
|
|
Natural Gas
|
|
1,184,095
|
|
1,301,537
|
|
921,934
|
|
|
|
Total Wellhead Revenues - (b)
|
|
$ 11,581,445
|
|
$ 11,946,487
|
|
$ 7,907,891
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Costs
|
|
|
|
|
|
|
|
|
|
Lease and Well
|
|
$ 1,366,993
|
|
$ 1,282,678
|
|
$ 1,044,847
|
|
|
|
Transportation Costs
|
|
758,300
|
|
746,876
|
|
740,352
|
|
|
|
Gathering and Processing Costs
|
|
479,102
|
|
436,973
|
|
148,775
|
|
|
|
|
|
|
|
|
|
|
|
|
General and Administrative
|
|
489,397
|
|
426,969
|
|
434,467
|
|
|
|
Less: Legal Settlement - Early Leasehold Termination
|
|
-
|
|
-
|
|
(10,202)
|
|
|
|
Less: Joint Venture Transaction Costs
|
|
-
|
|
-
|
|
(3,056)
|
|
|
|
Less: Joint Interest Billings Deemed Uncollectible
|
|
-
|
|
-
|
|
(4,528)
|
|
|
|
General and Administrative (Non-GAAP)
|
|
489,397
|
|
426,969
|
|
416,681
|
|
|
|
|
|
|
|
|
|
|
|
|
Taxes Other Than Income
|
|
800,164
|
|
772,481
|
|
544,662
|
|
|
|
Interest Expense, Net
|
|
185,129
|
|
245,052
|
|
274,372
|
|
|
|
Total Cash Operating Cost (Non-GAAP) (excluding DD&A
and Total Exploration Costs) - (c)
|
|
$ 4,079,085
|
|
$ 3,911,029
|
|
$ 3,169,689
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation, Depletion and Amortization (DD&A)
|
|
3,749,704
|
|
3,435,408
|
|
3,409,387
|
|
|
|
Total Operating Cost (Non-GAAP) (excluding Total
Exploration Costs) - (d)
|
|
$ 7,828,789
|
|
$ 7,346,437
|
|
$ 6,579,076
|
|
|
|
|
|
|
|
|
|
|
|
|
Exploration Costs
|
|
$ 139,881
|
|
$ 148,999
|
|
$ 145,342
|
|
|
|
Dry Hole Costs
|
|
28,001
|
|
5,405
|
|
4,609
|
|
|
|
Impairments
|
|
517,896
|
|
347,021
|
|
479,240
|
|
|
|
Total Exploration Costs
|
|
685,778
|
|
501,425
|
|
629,191
|
|
|
|
Less: Impairments (Non-GAAP)
|
|
(274,974)
|
|
(152,671)
|
|
(261,452)
|
|
|
|
Total Exploration Costs (Non-GAAP)
|
|
$ 410,804
|
|
$ 348,754
|
|
$ 367,739
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Cost (Non-GAAP) (including Total
Exploration Costs) - (e)
|
|
$ 8,239,593
|
|
$ 7,695,191
|
|
$ 6,946,815
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Wellhead Revenue per Boe - (b) / (a)
|
|
$ 38.79
|
|
$ 45.51
|
|
$ 35.58
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Cash Operating Cost per Boe (Non-GAAP)
(excluding DD&A and Total Exploration Costs) - (c) / (a)
|
|
$ 13.66
|
|
$ 14.90
|
|
$ 14.25
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Margin per Boe (Non-GAAP) (excluding
DD&A and Total Exploration Costs) - [(b) / (a) - (c) / (a)]
|
|
$ 25.13
|
|
$ 30.61
|
|
$ 21.33
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Cost per Boe (Non-GAAP) (excluding
Total Exploration Costs) - (d) / (a)
|
|
$ 26.22
|
|
$ 27.99
|
|
$ 29.59
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Margin per Boe (Non-GAAP)
(excluding Total Exploration Costs) - [(b) / (a) - (d) / (a)]
|
|
$ 12.57
|
|
$ 17.52
|
|
$ 5.99
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Cost per Boe (Non-GAAP) (including
Total Exploration Costs) - (e) / (a)
|
|
$ 27.60
|
|
$ 29.32
|
|
$ 31.24
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Margin per Boe (Non-GAAP)
(including Total Exploration Costs) - [(b) / (a) - (e) / (a)]
|
|
$ 11.19
|
|
$ 16.19
|
|
$ 4.34
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
EOG RESOURCES, INC.
|
|
|
|
Cost per Barrel of Oil Equivalent (Boe)
|
|
|
|
(Unaudited; in thousands, except per Boe amounts)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Year Ended
|
|
|
|
|
December 31,
|
|
|
|
|
2016
|
|
2015
|
|
2014
|
|
|
|
|
|
|
|
|
|
|
|
|
Volume - Thousand Barrels of Oil Equivalent - (a)
|
|
204,929
|
|
208,862
|
|
217,073
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude Oil and Condensate
|
|
$ 4,317,341
|
|
$ 4,934,562
|
|
$ 9,742,480
|
|
|
|
Natural Gas Liquids
|
|
437,250
|
|
407,658
|
|
934,051
|
|
|
|
Natural Gas
|
|
742,152
|
|
1,061,038
|
|
1,916,386
|
|
|
|
Total Wellhead Revenues - (b)
|
|
$ 5,496,743
|
|
$ 6,403,258
|
|
$ 12,592,917
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Costs
|
|
|
|
|
|
|
|
|
|
Lease and Well
|
|
$ 927,452
|
|
$ 1,182,282
|
|
$ 1,416,413
|
|
|
|
Transportation Costs
|
|
764,106
|
|
849,319
|
|
972,176
|
|
|
|
Gathering and Processing Costs
|
|
122,901
|
|
146,156
|
|
145,800
|
|
|
|
|
|
|
|
|
|
|
|
|
General and Administrative
|
|
394,815
|
|
366,594
|
|
402,010
|
|
|
|
Less: Voluntary Retirement Expense
|
|
(42,054)
|
|
-
|
|
-
|
|
|
|
Less: Acquisition Costs
|
|
(5,100)
|
|
-
|
|
-
|
|
|
|
Less: Legal Settlement - Early Leasehold Termination
|
|
-
|
|
(19,355)
|
|
-
|
|
|
|
General and Administrative (Non-GAAP)
|
|
347,661
|
|
347,239
|
|
402,010
|
|
|
|
|
|
|
|
|
|
|
|
|
Taxes Other Than Income
|
|
349,710
|
|
421,744
|
|
757,564
|
|
|
|
Interest Expense, Net
|
|
281,681
|
|
237,393
|
|
201,458
|
|
|
|
Total Cash Operating Cost (Non-GAAP) (excluding DD&A
and Total Exploration Costs) - (c)
|
|
$ 2,793,511
|
|
$ 3,184,133
|
|
$ 3,895,421
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation, Depletion and Amortization (DD&A)
|
|
3,553,417
|
|
3,313,644
|
|
3,997,041
|
|
|
|
Total Operating Cost (Non-GAAP) (excluding Total
Exploration Costs) - (d)
|
|
$ 6,346,928
|
|
$ 6,497,777
|
|
$ 7,892,462
|
|
|
|
|
|
|
|
|
|
|
|
|
Exploration Costs
|
|
$ 124,953
|
|
$ 149,494
|
|
$ 184,388
|
|
|
|
Dry Hole Costs
|
|
10,657
|
|
14,746
|
|
48,490
|
|
|
|
Impairments
|
|
620,267
|
|
6,613,546
|
|
743,575
|
|
|
|
Total Exploration Costs
|
|
755,877
|
|
6,777,786
|
|
976,453
|
|
|
|
Less: Impairments (Non-GAAP)
|
|
(320,617)
|
|
(6,307,593)
|
|
(824,312)
|
|
|
|
Total Exploration Costs (Non-GAAP)
|
|
$ 435,260
|
|
$ 470,193
|
|
$ 152,141
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Cost (Non-GAAP) (including Total
Exploration Costs) - (e)
|
|
$ 6,782,188
|
|
$ 6,967,970
|
|
$ 8,044,603
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Wellhead Revenue per Boe - (b) / (a)
|
|
$ 26.82
|
|
$ 30.66
|
|
$ 58.01
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Cash Operating Cost per Boe (Non-GAAP)
(excluding DD&A and Total Exploration Costs) - (c) / (a)
|
|
$ 13.64
|
|
$ 15.25
|
|
$ 17.95
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Margin per Boe (Non-GAAP) (excluding
DD&A and Total Exploration Costs) - [(b) / (a) - (c) / (a)]
|
|
$ 13.18
|
|
$ 15.41
|
|
$ 40.06
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Cost per Boe (Non-GAAP) (excluding
Total Exploration Costs) - (d) / (a)
|
|
$ 30.98
|
|
$ 31.11
|
|
$ 36.38
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Margin per Boe (Non-GAAP)
(excluding Total Exploration Costs) - [(b) / (a) - (d) / (a)]
|
|
$ (4.16)
|
|
$ (0.45)
|
|
$ 21.63
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Operating Cost per Boe (Non-GAAP) (including
Total Exploration Costs) - (e) / (a)
|
|
$ 33.10
|
|
$ 33.36
|
|
$ 37.08
|
|
|
|
|
|
|
|
|
|
|
|
|
Composite Average Margin per Boe (Non-GAAP)
(including Total Exploration Costs) - [(b) / (a) - (e) / (a)]
|
|
$ (6.28)
|
|
$ (2.70)
|
|
$ 20.93
|
|
|
|
EOG RESOURCES, INC.
|
|
Second Quarter and Full Year 2020 Forecast and Benchmark Commodity Pricing
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(a) Second Quarter and Full Year 2020 Forecast
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The forecast items for the second quarter and full year 2020 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) Capital Expenditures
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The forecast includes expenditures for Exploration and Development Drilling, Facilities, Leasehold Acquisitions, Capitalized Interest, Exploration Costs, Dry Hole Costs and Other Property, Plant and Equipment. The forecast excludes Property Acquisitions, Asset Retirement Costs and any Non-Cash Transactions.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(c) 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)
|
|
|
|
|
|
2Q 2020
|
|
|
Full Year 2020
|
|
Daily Sales Volumes
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude Oil and Condensate Volumes (MBbld)
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
300.0
|
-
|
|
320.0
|
|
|
376.0
|
-
|
|
402.0
|
|
Trinidad
|
|
0.2
|
-
|
|
0.6
|
|
|
0.5
|
-
|
|
0.7
|
|
Other International
|
|
0.0
|
-
|
|
0.2
|
|
|
0.0
|
-
|
|
0.2
|
|
Total
|
|
300.2
|
-
|
|
320.8
|
|
|
376.5
|
-
|
|
402.9
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural Gas Liquids Volumes (MBbld)
|
|
|
|
|
|
|
|
|
|
|
|
|
Total
|
|
85.0
|
-
|
|
95.0
|
|
|
105.0
|
-
|
|
125.0
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural Gas Volumes (MMcfd)
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
870
|
-
|
|
930
|
|
|
950
|
-
|
|
1,050
|
|
Trinidad
|
|
160
|
-
|
|
180
|
|
|
170
|
-
|
|
190
|
|
Other International
|
|
20
|
-
|
|
30
|
|
|
20
|
-
|
|
30
|
|
Total
|
|
1,050
|
-
|
|
1,140
|
|
|
1,140
|
-
|
|
1,270
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude Oil Equivalent Volumes (MBoed)
|
|
|
|
|
|
|
|
|
|
|
|
|
United States
|
|
530.0
|
-
|
|
570.0
|
|
|
639.3
|
-
|
|
702.0
|
|
Trinidad
|
|
26.9
|
-
|
|
30.6
|
|
|
28.8
|
-
|
|
32.4
|
|
Other International
|
|
3.3
|
-
|
|
5.2
|
|
|
3.3
|
-
|
|
5.2
|
|
Total
|
|
560.2
|
-
|
|
605.8
|
|
|
671.4
|
-
|
|
739.6
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Capital Expenditures ($MM)
|
$
|
600
|
-
|
$
|
700
|
|
$
|
3,300
|
-
|
$
|
3,700
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Estimated Ranges
|
|
|
|
|
|
|
|
(Unaudited)
|
|
|
|
|
2Q 2020
|
|
|
Full Year 2020
|
|
Operating Costs
|
|
|
|
|
|
|
|
|
|
|
|
|
Unit Costs ($/Boe)
|
|
|
|
|
|
|
|
|
|
|
|
|
Lease and Well
|
$
|
4.65
|
-
|
$
|
5.15
|
|
$
|
4.20
|
-
|
$
|
4.80
|
|
Transportation Costs
|
$
|
3.00
|
-
|
$
|
3.40
|
|
$
|
2.60
|
-
|
$
|
3.20
|
|
Gathering and Processing
|
$
|
2.15
|
-
|
$
|
2.35
|
|
$
|
1.80
|
-
|
$
|
2.10
|
|
Depreciation, Depletion and Amortization
|
$
|
12.10
|
-
|
$
|
12.60
|
|
$
|
11.85
|
-
|
$
|
12.85
|
|
General and Administrative
|
$
|
2.40
|
-
|
$
|
2.50
|
|
$
|
1.90
|
-
|
$
|
2.10
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Expenses ($MM)
|
|
|
|
|
|
|
|
|
|
|
|
|
Exploration and Dry Hole
|
$
|
32
|
-
|
$
|
42
|
|
$
|
130
|
-
|
$
|
170
|
|
Impairment
|
$
|
75
|
-
|
$
|
85
|
|
$
|
300
|
-
|
$
|
340
|
|
Capitalized Interest
|
$
|
5
|
-
|
$
|
9
|
|
$
|
27
|
-
|
$
|
33
|
|
Net Interest
|
$
|
51
|
-
|
$
|
55
|
|
$
|
200
|
-
|
$
|
205
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Taxes Other Than Income (% of Wellhead Revenue)
|
|
9.0%
|
-
|
|
11.0%
|
|
|
7.0%
|
-
|
|
8.0%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income Taxes
|
|
|
|
|
|
|
|
|
|
|
|
|
Effective Rate
|
|
19%
|
-
|
|
24%
|
|
|
17%
|
-
|
|
22%
|
|
Current Tax (Benefit) / Expense ($MM)
|
$
|
(5)
|
-
|
$
|
35
|
|
$
|
(110)
|
-
|
$
|
(70)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Pricing - (Refer to Benchmark Commodity Pricing in text)
|
|
|
|
|
|
|
|
|
|
|
|
|
Crude Oil and Condensate ($/Bbl)
|
|
|
|
|
|
|
|
|
|
|
|
|
Differentials
|
|
|
|
|
|
|
|
|
|
|
|
|
United States - above (below) WTI
|
$
|
(7.75)
|
-
|
$
|
(2.75)
|
|
$
|
(0.40)
|
-
|
$
|
1.60
|
|
Trinidad - above (below) WTI
|
$
|
(12.00)
|
-
|
$
|
(10.00)
|
|
$
|
(12.00)
|
-
|
$
|
(10.00)
|
|
Other International - above (below) WTI
|
$
|
26.50
|
-
|
$
|
32.50
|
|
$
|
7.00
|
-
|
$
|
12.00
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural Gas Liquids
|
|
|
|
|
|
|
|
|
|
|
|
|
Realizations as % of WTI
|
|
38%
|
-
|
|
48%
|
|
|
30%
|
-
|
|
36%
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Natural Gas ($/Mcf)
|
|
|
|
|
|
|
|
|
|
|
|
|
Differentials
|
|
|
|
|
|
|
|
|
|
|
|
|
United States - above (below) NYMEX Henry Hub
|
$
|
(0.85)
|
-
|
$
|
(0.45)
|
|
$
|
(0.85)
|
-
|
$
|
(0.25)
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Realizations
|
|
|
|
|
|
|
|
|
|
|
|
|
Trinidad
|
$
|
2.90
|
-
|
$
|
3.50
|
|
$
|
2.60
|
-
|
$
|
3.30
|
|
Other International
|
$
|
5.00
|
-
|
$
|
5.50
|
|
$
|
4.45
|
-
|
$
|
5.45
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Definitions
|
|
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|
|
|
|
$/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
|
|
|
|
|
|
|
 View original content:http://www.prnewswire.com/news-releases/eog-resources-reports-first-quarter-2020-results-and-updates-2020-plan-in-response-to-oil-market-downturn-company-well-positioned-to-emerge-stronger-in-a-recovery-301055288.html
SOURCE EOG Resources, Inc.
Source: PR Newswire
(May 7, 2020 - 4:15 PM EDT)
News by QuoteMedia
www.quotemedia.com
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