EOG Resources Reports Outstanding First Quarter 2019 Results and Raises Dividend by 31 Percent
HOUSTON, May 2, 2019 /PRNewswire/ --
- Increased Crude Oil Production 20 Percent YOY and Exceeded Target
- Delivered First Quarter Capital Expenditures Below Target and Reiterates Unchanged FY 2019 Target
- Reduced Per-Unit Cash Operating Costs 8 Percent YOY and Beat Targets
- Achieved Reductions in Well Costs and On-Track to Reach 5 Percent Reduction Goal
- Established Significant Crude Oil Export Capacity
- Increased Common Stock Dividend 31 Percent
EOG Resources, Inc. (EOG) today reported first quarter 2019 net income of $635 million, or $1.10 per share, compared with first quarter 2018 net income of $639 million, or $1.10 per share. Net cash from operating activities for the first quarter 2019 was $1.6 billion. Discretionary cash flow for the first quarter 2019 of $1.9 billion increased three percent compared to the first quarter 2018, despite a 13 percent drop in the average WTI NYMEX price compared to the same prior year period.
Adjusted non-GAAP net income for the first quarter 2019 was $689 million, or $1.19 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 2019 ReviewEOG delivered stellar operational and financial performance in the first quarter 2019. Crude oil production volumes exceeded the target range, while capital expenditures were below the target range. Total company crude oil volumes grew 20 percent compared to the first quarter 2018, to 435,900 barrels of oil per day (Bopd). Natural gas liquids production increased 19 percent, while natural gas volumes grew 11 percent, contributing to total company production growth of 17 percent.
Cash operating costs declined by eight percent during the first quarter 2019 on a per-unit basis compared to the same prior year period. Lower transportation, lease operating and general and administrative costs contributed to the overall cost reduction. EOG's marketing operations added to the strong first quarter financial performance, as the average price on U.S. crude oil sales was $1.21 per barrel higher than the average WTI NYMEX price. The company also achieved reductions in well costs during the first quarter 2019.
EOG generated $1.9 billion of discretionary cash flow in the first quarter 2019. The company incurred total expenditures of $2.1 billion, including $1.7 billion of cash capital expenditures before acquisitions. After considering dividend payments of $128 million, EOG generated free cash flow during the first quarter of $55 million. Please refer to the attached tables for the reconciliation of non-GAAP measures to GAAP measures.
"EOG's consistent long-term strategy of exploration-led organic growth, focus on operating and capital cost control and disciplined capital allocation is generating robust financial results. We are growing more efficiently than ever before," said William R. "Bill" Thomas, Chairman and Chief Executive Officer. "We are on track to reduce well costs five percent for the year. Combined with strong price realizations, EOG is positioned to further improve margins and returns. The tremendous first quarter results demonstrate that EOG is achieving its goal of performing with the best companies in the S&P 500."
Dividend IncreaseEOG's Board of Directors declared a quarterly dividend of $0.2875 per share on the common stock, an increase of 31 percent. The dividend will be payable July 31, 2019, to holders of record as of July 17, 2019. The indicated annual rate is $1.15 per share.
"EOG's commitment to increasing cash returns to stockholders continues, as we have now increased our dividend by 72 percent during the past 14 months. This is made possible through our relentless efforts to lower costs, increase returns and fundamentally reset the business to be profitable even in a low oil price environment. We are confident our results will continue to improve, guided by our unique culture and sustainable business model," Thomas said.
Crude Oil Export CapacityEOG has reached agreements that provide access to crude oil export capacity on the Gulf Coast. Export capacity available to EOG will increase from 100,000 Bopd in 2020 to 250,000 Bopd in 2022 and subsequent years. The company expects to sell a portion of its crude oil from its Eagle Ford and Delaware Basin plays to export markets. The new agreements complement EOG's existing pipeline and terminal tankage capacity, further increasing the reliability and diversification of its marketing operations.
"These agreements extend control of our crude oil production to the water's edge and open significant new markets to EOG. We enhance our flexibility to capture the highest margins for our crude oil by maintaining firm capacity for our production downstream, providing access to a diverse group of potential customers in multiple end markets," commented D. Lance Terveen, Senior Vice President, Marketing.
Operating HighlightsEOG brought on line 78 wells in the Delaware Basin during the first quarter 2019 using one less rig and completion crew than it did in the first quarter 2018 to bring on line 70 wells. This tremendous operating performance, as well as infrastructure investments such as water handling and reuse, are enabling EOG to achieve further cost reductions.
The South Texas Eagle Ford remains a foundation asset for EOG, capable of sustaining high-return growth for at least 10 years. EOG is improving capital productivity across the entire 120-mile length of its acreage position in the heart of this world class resource play. The further adoption of local sources of sand supply, increased efficiencies in completion operations and the continued development of new completion designs are contributing to lower costs with consistent well productivity. With less than 40 percent of its identified locations in the play developed, there is significant opportunity to convert additional acreage to premium status.
In the Powder River Basin Turner, EOG brought five wells to sales during the first quarter. The company also further progressed plans for infrastructure development, including crude oil and natural gas gathering pipelines and water handling systems. EOG brought on line 25 wells in the Wyoming DJ Basin Codell during the first quarter. With low well costs and a high oil mix, EOG's Codell development program realizes low finding costs and premium rates of return.
EOG brought on line four wells in the Eastern Anadarko Basin Woodford Oil Window during the first quarter. The drilling program in the first quarter was focused on further delineating the play and testing additional targets.
In the Williston Basin, EOG drilled two wells during the first quarter and deferred completions until the summer as part of its seasonal development program.
Financial ReviewAt March 31, 2019, EOG's total debt outstanding was $6.1 billion for a debt-to-total capitalization ratio of 23 percent. Considering cash on the balance sheet at the end of the first quarter, EOG's net debt was $4.9 billion for a net debt-to-total capitalization ratio of 20 percent. For a reconciliation of non-GAAP measures to GAAP measures, please refer to the attached tables.
First Quarter 2019 Results WebcastFriday, May 3, 2019, 9:00 a.m. Central time (10:00 a.m. Eastern time) Webcast will be available on EOG website for one year.http://investors.eogresources.com/Investors
About EOGEOG 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 ContactsDavid Streit 713-571-4902Neel Panchal 713-571-4884John Wagner 713-571-4404
Media and Investor ContactKimberly Ehmer 713-571-4676
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. 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 economically develop its acreage in, produce reserves and achieve anticipated production levels from, and maximize reserve recovery from, its existing and future crude oil and natural gas exploration and development projects;
- the extent to which EOG is successful in its efforts to market its crude oil and condensate, natural gas liquids, natural gas and related commodity production;
- the availability, proximity and capacity of, and costs associated with, appropriate gathering, processing, compression, storage, transportation and refining facilities;
- the availability, cost, terms and timing of issuance or execution of, and competition for, mineral licenses and leases and governmental and other permits and rights-of-way, and EOG's ability to retain mineral licenses and leases;
- the impact of, and changes in, government policies, laws and regulations, including tax laws and regulations; climate change and other environmental, health and safety laws and regulations relating to air emissions, disposal of produced water, drilling fluids and other wastes, hydraulic fracturing and access to and use of water; laws and regulations imposing conditions or restrictions on drilling and completion operations and on the transportation of crude oil and natural gas; laws and regulations with respect to derivatives and hedging activities; and laws and regulations with respect to the import and export of crude oil, natural gas and related commodities;
- EOG's ability to effectively integrate acquired crude oil and natural gas properties into its operations, fully identify existing and potential problems with respect to such properties and accurately estimate reserves, production and costs with respect to such properties;
- the extent to which EOG's third-party-operated crude oil and natural gas properties are operated successfully and economically;
- competition in the oil and gas exploration and production industry for the acquisition of licenses, leases and properties, employees and other personnel, facilities, equipment, materials and services;
- the availability and cost of employees and other personnel, facilities, equipment, materials (such as water and tubulars) and services;
- the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise;
- weather, including its impact on crude oil and natural gas demand, and weather-related delays in drilling and in the installation and operation (by EOG or third parties) of production, gathering, processing, refining, compression, storage and transportation facilities;
- the ability of EOG's customers and other contractual counterparties to satisfy their obligations to EOG and, related thereto, to access the credit and capital markets to obtain financing needed to satisfy their obligations to EOG;
- EOG's ability to access the commercial paper market and other credit and capital markets to obtain financing on terms it deems acceptable, if at all, and to otherwise satisfy its capital expenditure requirements;
- the extent to which EOG is successful in its completion of planned asset dispositions;
- the extent and effect of any hedging activities engaged in by EOG;
- the timing and extent of changes in foreign currency exchange rates, interest rates, inflation rates, global and domestic financial market conditions and global and domestic general economic conditions;
- geopolitical factors and political conditions and developments around the world (such as the imposition of tariffs or trade or other economic sanctions, political instability and armed conflict), including in the areas in which EOG operates;
- the use of competing energy sources and the development of alternative energy sources;
- the extent to which EOG incurs uninsured losses and liabilities or losses and liabilities in excess of its insurance coverage;
- acts of war and terrorism and responses to these acts;
- physical, electronic and cybersecurity breaches; and
- the other factors described under ITEM 1A, Risk Factors, on pages 13 through 22 of EOG's Annual Report on Form 10-K for the fiscal year ended December 31, 2018 and any updates to those factors set forth in EOG's subsequent Quarterly Reports on Form 10-Q or Current Reports on Form 8-K.
In light of these risks, uncertainties and assumptions, the events anticipated by EOG's forward-looking statements may not occur, and, if any of such events do, we may not have anticipated the timing of their occurrence or the duration or extent of their impact on our actual results. Accordingly, you should not place any undue reliance on any of EOG's forward-looking statements. EOG's forward-looking statements speak only as of the date made, and EOG undertakes no obligation, other than as required by applicable law, to update or revise its forward-looking statements, whether as a result of new information, subsequent events, anticipated or unanticipated circumstances or otherwise.
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, 2018, 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, | |||||
2019 | 2018 | ||||
Operating Revenues and Other | $ | 4,058.6 | $ | 3,681.2 | |
Net Income | $ | 635.4 | $ | 638.6 | |
Net Income Per Share | |||||
Basic | $ | 1.10 | $ | 1.11 | |
Diluted | $ | 1.10 | $ | 1.10 | |
Average Number of Common Shares | |||||
Basic | 577.2 | 575.8 | |||
Diluted | 580.2 | 579.7 | |||
Summary Income Statements | |||||
(Unaudited; in thousands, except per share data) | |||||
Three Months Ended | |||||
March 31, | |||||
2019 | 2018 | ||||
Operating Revenues and Other | |||||
Crude Oil and Condensate | $ | 2,200,403 | $ | 2,101,308 | |
Natural Gas Liquids | 218,638 | 221,415 | |||
Natural Gas | 334,972 | 299,766 | |||
Losses on Mark-to-Market Commodity Derivative Contracts | (20,580) | (59,771) | |||
Gathering, Processing and Marketing | 1,285,654 | 1,101,822 | |||
Losses on Asset Dispositions, Net | (3,836) | (14,969) | |||
Other, Net | 43,391 | 31,591 | |||
Total | 4,058,642 | 3,681,162 | |||
Operating Expenses | |||||
Lease and Well | 336,291 | 300,064 | |||
Transportation Costs | 176,522 | 176,957 | |||
Gathering and Processing Costs | 111,295 | 101,345 | |||
Exploration Costs | 36,324 | 34,836 | |||
Dry Hole Costs | 94 | - | |||
Impairments | 72,356 | 64,609 | |||
Marketing Costs | 1,270,057 | 1,106,390 | |||
Depreciation, Depletion and Amortization | 879,595 | 748,591 | |||
General and Administrative | 106,672 | 94,698 | |||
Taxes Other Than Income | 192,906 | 179,084 | |||
Total | 3,182,112 | 2,806,574 | |||
Operating Income | 876,530 | 874,588 | |||
Other Income, Net | 5,612 | 727 | |||
Income Before Interest Expense and Income Taxes | 882,142 | 875,315 | |||
Interest Expense, Net | 54,906 | 61,956 | |||
Income Before Income Taxes | 827,236 | 813,359 | |||
Income Tax Provision | 191,810 | 174,770 | |||
Net Income | $ | 635,426 | $ | 638,589 | |
Dividends Declared per Common Share | $ | 0.2200 | $ | 0.1850 | |
EOG RESOURCES, INC. | |||||
Operating Highlights | |||||
(Unaudited) | |||||
Three Months Ended | |||||
March 31, | |||||
2019 | 2018 | ||||
Wellhead Volumes and Prices | |||||
Crude Oil and Condensate Volumes (MBbld) (A) | |||||
United States | 435.1 | 359.7 | |||
Trinidad | 0.7 | 0.9 | |||
Other International (B) | 0.1 | 2.7 | |||
Total | 435.9 | 363.3 | |||
Average Crude Oil and Condensate Prices ($/Bbl) (C) | |||||
United States | $ | 56.11 | $ | 64.24 | |
Trinidad | 43.68 | 54.86 | |||
Other International (B) | 60.13 | 71.61 | |||
Composite | 56.09 | 64.27 | |||
Natural Gas Liquids Volumes (MBbld) (A) | |||||
United States | 119.8 | 100.6 | |||
Other International (B) | - | - | |||
Total | 119.8 | 100.6 | |||
Average Natural Gas Liquids Prices ($/Bbl) (C) | |||||
United States | $ | 20.28 | $ | 24.46 | |
Other International (B) | - | - | |||
Composite | 20.28 | 24.46 | |||
Natural Gas Volumes (MMcfd) (A) | |||||
United States | 1,003 | 853 | |||
Trinidad | 267 | 293 | |||
Other International (B) | 38 | 30 | |||
Total | 1,308 | 1,176 | |||
Average Natural Gas Prices ($/Mcf) (C) | |||||
United States | $ | 2.77 | $ | 2.76 | |
Trinidad | 2.91 | 2.88 | |||
Other International (B) | 4.37 | 4.36 | |||
Composite | 2.85 | 2.83 | |||
Crude Oil Equivalent Volumes (MBoed) (D) | |||||
United States | 722.0 | 602.5 | |||
Trinidad | 45.1 | 49.8 | |||
Other International (B) | 6.5 | 7.6 | |||
Total | 773.6 | 659.9 | |||
Total MMBoe (D) | 69.6 | 59.4 | |||
(A) Thousand barrels per day or million cubic feet per day, as applicable. | ||||||
(B) Other International includes EOG's United Kingdom, China and Canada operations. The United Kingdom operations were sold in the fourth quarter of 2018. | ||||||
(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, 2018). | ||||||
(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, | ||||
2019 | 2018 | ||||
ASSETS | |||||
Current Assets | |||||
Cash and Cash Equivalents | $ | 1,135,810 | $ | 1,555,634 | |
Accounts Receivable, Net | 2,203,438 | 1,915,215 | |||
Inventories | 860,764 | 859,359 | |||
Assets from Price Risk Management Activities | 3,909 | 23,806 | |||
Income Taxes Receivable | 440,217 | 427,909 | |||
Other | 263,747 | 275,467 | |||
Total | 4,907,885 | 5,057,390 | |||
Property, Plant and Equipment | |||||
Oil and Gas Properties (Successful Efforts Method) | 58,691,746 | 57,330,016 | |||
Other Property, Plant and Equipment | 4,277,888 | 4,220,665 | |||
Total Property, Plant and Equipment | 62,969,634 | 61,550,681 | |||
Less: Accumulated Depreciation, Depletion and Amortization | (33,840,631) | (33,475,162) | |||
Total Property, Plant and Equipment, Net | 29,129,003 | 28,075,519 | |||
Deferred Income Taxes | 1,224 | 777 | |||
Other Assets | 1,625,423 | 800,788 | |||
Total Assets | $ | 35,663,535 | $ | 33,934,474 | |
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||
Current Liabilities | |||||
Accounts Payable | $ | 2,452,337 | $ | 2,239,850 | |
Accrued Taxes Payable | 239,524 | 214,726 | |||
Dividends Payable | 126,979 | 126,971 | |||
Liabilities from Price Risk Management Activities | 746 | - | |||
Current Portion of Long-Term Debt | 914,861 | 913,093 | |||
Current Portion of Operating Lease Liabilities | 396,294 | - | |||
Other | 170,527 | 233,724 | |||
Total | 4,301,268 | 3,728,364 | |||
Long-Term Debt | 5,166,050 | 5,170,169 | |||
Other Liabilities | 1,772,248 | 1,258,355 | |||
Deferred Income Taxes | 4,520,172 | 4,413,398 | |||
Commitments and Contingencies | |||||
Stockholders' Equity | |||||
Common Stock, $0.01 Par, 1,280,000,000 Shares Authorized and 580,740,395 Shares Issued at March 31, 2019 and 580,408,117 Shares Issued at December 31, 2018 | 205,807 | 205,804 | |||
Additional Paid in Capital | 5,695,197 | 5,658,794 | |||
Accumulated Other Comprehensive Loss | (2,869) | (1,358) | |||
Retained Earnings | 14,050,676 | 13,543,130 | |||
Common Stock Held in Treasury, 425,637 Shares at March 31, 2019 and 385,042 Shares at December 31, 2018 | (45,014) | (42,182) | |||
Total Stockholders' Equity | 19,903,797 | 19,364,188 | |||
Total Liabilities and Stockholders' Equity | $ | 35,663,535 | $ | 33,934,474 | |
EOG RESOURCES, INC. | |||||
Summary Statements of Cash Flows | |||||
(Unaudited; in thousands) | |||||
Three Months Ended | |||||
March 31, | |||||
2019 | 2018 | ||||
Cash Flows from Operating Activities | |||||
Reconciliation of Net Income to Net Cash Provided by Operating Activities: | |||||
Net Income | $ | 635,426 | $ | 638,589 | |
Items Not Requiring (Providing) Cash | |||||
Depreciation, Depletion and Amortization | 879,595 | 748,591 | |||
Impairments | 72,356 | 64,609 | |||
Stock-Based Compensation Expenses | 39,087 | 35,486 | |||
Deferred Income Taxes | 106,324 | 171,362 | |||
Losses on Asset Dispositions, Net | 3,836 | 14,969 | |||
Other, Net | 2,952 | 2,013 | |||
Dry Hole Costs | 94 | - | |||
Mark-to-Market Commodity Derivative Contracts | |||||
Total Losses | 20,580 | 59,771 | |||
Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts | 20,846 | (21,965) | |||
Other, Net | 976 | (478) | |||
Changes in Components of Working Capital and Other Assets and Liabilities | |||||
Accounts Receivable | (308,996) | (109,654) | |||
Inventories | (18,979) | (106,799) | |||
Accounts Payable | 194,082 | 53,652 | |||
Accrued Taxes Payable | 114,998 | 21,950 | |||
Other Assets | (6,935) | (8,863) | |||
Other Liabilities | (54,092) | (29,055) | |||
Changes in Components of Working Capital Associated with Investing and Financing Activities | (94,381) | 17,988 | |||
Net Cash Provided by Operating Activities | 1,607,769 | 1,552,166 | |||
Investing Cash Flows | |||||
Additions to Oil and Gas Properties | (1,939,473) | (1,365,111) | |||
Additions to Other Property, Plant and Equipment | (60,963) | (76,100) | |||
Proceeds from Sales of Assets | 15,049 | 2,829 | |||
Changes in Components of Working Capital Associated with Investing Activities | 94,381 | (18,045) | |||
Net Cash Used in Investing Activities | (1,891,006) | (1,456,427) | |||
Financing Cash Flows | |||||
Dividends Paid | (127,546) | (97,026) | |||
Treasury Stock Purchased | (6,248) | (16,776) | |||
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan | 403 | 1,453 | |||
Repayment of Capital Lease Obligation | (3,190) | (1,671) | |||
Changes in Components of Working Capital Associated with Financing Activities | - | 57 | |||
Net Cash Used in Financing Activities | (136,581) | (113,963) | |||
Effect of Exchange Rate Changes on Cash | (6) | 90 | |||
Decrease in Cash and Cash Equivalents | (419,824) | (18,134) | |||
Cash and Cash Equivalents at Beginning of Period | 1,555,634 | 834,228 | |||
Cash and Cash Equivalents at End of Period | $ | 1,135,810 | $ | 816,094 | |
EOG RESOURCES, INC. | ||||||||||||||
First Quarter 2019 Well Results by Play | ||||||||||||||
(Unaudited) | ||||||||||||||
Wells On Line | Initial Gross 30-Day Average Production Rate | |||||||||||||
Gross | Net | LateralLength(ft) | Crude Oil and Condensate(Bbld) (A) | Natural GasLiquids(Bbld) (A) | Natural Gas(MMcfd) (A) | Crude Oil Equivalent(Boed) (B) | ||||||||
Delaware Basin | ||||||||||||||
Wolfcamp | 61 | 53 | 7,800 | 1,950 | 400 | 3.8 | 2,950 | |||||||
Bone Spring | 12 | 10 | 5,500 | 1,500 | 300 | 1.9 | 2,100 | |||||||
Leonard | 5 | 5 | 7,600 | 1,650 | 650 | 4.3 | 3,000 | |||||||
South Texas Eagle Ford | 93 | 89 | 8,300 | 1,350 | 150 | 0.8 | 1,650 | |||||||
Powder River Basin | ||||||||||||||
Turner | 5 | 4 | 9,800 | 650 | 650 | 1.0 | 1,450 | |||||||
DJ Basin Codell | 25 | 13 | 9,600 | 600 | 50 | 0.3 | 700 | |||||||
Anadarko Basin Woodford Oil Window | 4 | 3 | 9,700 | 900 | 100 | 0.6 | 1,100 | |||||||
(A) Barrels per day or million cubic feet per day, as applicable. | ||||||||||||||
(B) Barrels of oil equivalent per day; includes crude oil and condensate, natural gas liquids and natural gas. Crude oil equivalent volumes are determined using a ratio of 1.0 barrel of crude oil and condensate or natural gas liquids to 6.0 thousand cubic feet of natural gas. |
EOG RESOURCES, INC. | |||||||||||||||
Quantitative Reconciliation of Adjusted Net Income (Non-GAAP) | |||||||||||||||
To Net Income (GAAP) | |||||||||||||||
(Unaudited; in thousands, except per share data) | |||||||||||||||
The following chart adjusts the three-month periods ended March 31, 2019 and 2018 reported Net Income (GAAP) to reflect actual net cash received from (payments for) settlements of commodity derivative contracts by eliminating the unrealized mark-to-market losses from these transactions, to eliminate the net losses on asset dispositions in 2019 and 2018, to add back impairment charges related to certain of EOG's assets in 2019 and 2018 and to eliminate certain adjustments in 2018 related to the 2017 U.S. tax reform. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported company earnings to match hedge realizations to production settlement months and make certain other adjustments to exclude non-recurring and certain other items. EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry. | |||||||||||||||
Three Months Ended | Three Months Ended | ||||||||||||||
March 31, 2019 | March 31, 2018 | ||||||||||||||
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) | $827,236 | $(191,810) | $635,426 | $ 1.10 | $813,359 | $(174,770) | $638,589 | $ 1.10 | |||||||
Adjustments: | |||||||||||||||
Losses on Mark-to-Market Commodity Derivative Contracts | 20,580 | (4,533) | 16,047 | 0.02 | 59,771 | (13,166) | 46,605 | 0.08 | |||||||
Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts | 20,846 | (4,592) | 16,254 | 0.03 | (21,965) | 4,838 | (17,127) | (0.03) | |||||||
Add: Losses on Asset Dispositions | 3,836 | (736) | 3,100 | 0.01 | 14,969 | (3,324) | 11,645 | 0.02 | |||||||
Add: Impairments | 23,745 | (5,230) | 18,515 | 0.03 | 20,876 | (4,598) | 16,278 | 0.03 | |||||||
Less: Tax Reform Impact | - | - | - | - | - | (6,524) | (6,524) | (0.01) | |||||||
Adjustments to Net Income | 69,007 | (15,091) | 53,916 | 0.09 | 73,651 | (22,774) | 50,877 | 0.09 | |||||||
Adjusted Net Income (Non-GAAP) | $896,243 | $(206,901) | $689,342 | $ 1.19 | $887,010 | $(197,544) | $689,466 | $ 1.19 | |||||||
Average Number of Common Shares (GAAP) | |||||||||||||||
Basic | 577,207 | 575,775 | |||||||||||||
Diluted | 580,222 | 579,726 | |||||||||||||
EOG RESOURCES, INC. | ||||||
Quantitative Reconciliation of Discretionary Cash Flow (Non-GAAP) | ||||||
To Net Cash Provided By Operating Activities (GAAP) | ||||||
(Unaudited; in thousands) | ||||||
Calculation of Free Cash Flow (Non-GAAP) | ||||||
(Unaudited; in thousands) | ||||||
The following chart reconciles the three-month periods ended March 31, 2019 and 2018 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 and Financing Activities. EOG defines Free Cash Flow (Non-GAAP) for a given period as Discretionary Cash Flow (Non-GAAP) (see below reconciliation) for such period less the total cash capital expenditures excluding acquisitions incurred (Non-GAAP) during such period and dividends paid (GAAP) during such period, as is illustrated below for the three months ended March 31, 2019 and 2018. EOG management uses this information for comparative purposes within the industry. | ||||||
Three Months Ended | ||||||
March 31, | ||||||
2019 | 2018 | |||||
Net Cash Provided by Operating Activities (GAAP) | $ | 1,607,769 | $ | 1,552,166 | ||
Adjustments: | ||||||
Exploration Costs (excluding Stock-Based Compensation Expenses) | 29,787 | 27,936 | ||||
Other Non-Current Income Taxes - Net Receivable | 102,918 | 118,921 | ||||
Changes in Components of Working Capital and Other Assets | ||||||
and Liabilities | ||||||
Accounts Receivable | 308,996 | 109,654 | ||||
Inventories | 18,979 | 106,799 | ||||
Accounts Payable | (194,082) | (53,652) | ||||
Accrued Taxes Payable | (114,998) | (21,950) | ||||
Other Assets | 6,935 | 8,863 | ||||
Other Liabilities | 54,092 | 29,055 | ||||
Changes in Components of Working Capital Associated with | ||||||
Investing and Financing Activities | 94,381 | (17,988) | ||||
Discretionary Cash Flow (Non-GAAP) | $ | 1,914,777 | $ | 1,859,804 | ||
Discretionary Cash Flow (Non-GAAP) - Percentage Increase | 3% | |||||
Discretionary Cash Flow (Non-GAAP) | $ | 1,914,777 | $ | 1,859,804 | ||
Less: | ||||||
Total Cash Expenditures Excluding Acquisitions (Non-GAAP)(a) | (1,732,476) | (1,478,097) | ||||
Dividends Paid (GAAP) | (127,546) | (97,026) | ||||
Free Cash Flow (Non-GAAP) | $ | 54,755 | $ | 284,681 | ||
(a) See below reconciliation of Total Expenditures (GAAP) to Total Cash Expenditures Excluding Acquisitions (Non-GAAP) for the three-month periods ended March 31, 2019 and 2018: | ||||||
Total Expenditures (GAAP) | $ | 2,101,919 | $ | 1,546,641 | ||
Less: | ||||||
Asset Retirement Costs | (5,156) | (12,100) | ||||
Non-Cash Expenditures of Other Property, Plant and Equipment | - | (47,635) | ||||
Non-Cash Acquisition Costs of Unproved Properties | (43,481) | (8,809) | ||||
Acquisition Costs of Proved Properties | (320,806) | - | ||||
Total Cash Expenditures Excluding Acquisitions (Non-GAAP) | $ | 1,732,476 | $ | 1,478,097 | ||
EOG RESOURCES, INC. | ||||||
Quantitative Reconciliation of Adjusted Earnings Before Interest Expense, Net, | ||||||
Income Taxes, Depreciation, Depletion and Amortization, Exploration Costs, | ||||||
Dry Hole Costs, Impairments and Additional Items (Adjusted EBITDAX) | ||||||
(Non-GAAP) to Net Income (GAAP) | ||||||
(Unaudited; in thousands) | ||||||
The following chart adjusts the three-month periods ended March 31, 2019 and 2018 reported Net Income (GAAP) to Earnings Before Interest Expense (Net), Income Taxes (Income Tax Provision), Depreciation, Depletion and Amortization, Exploration Costs, Dry Hole Costs and Impairments (EBITDAX) (Non-GAAP) and further adjusts such amount to reflect actual net cash received from (payments for) settlements of commodity derivative contracts by eliminating the unrealized mark-to-market (MTM) losses from these transactions and to eliminate the 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, | ||||||
2019 | 2018 | |||||
Net Income (GAAP) | $ | 635,426 | $ | 638,589 | ||
Adjustments: | ||||||
Interest Expense, Net | 54,906 | 61,956 | ||||
Income Tax Provision | 191,810 | 174,770 | ||||
Depreciation, Depletion and Amortization | 879,595 | 748,591 | ||||
Exploration Costs | 36,324 | 34,836 | ||||
Dry Hole Costs | 94 | - | ||||
Impairments | 72,356 | 64,609 | ||||
EBITDAX (Non-GAAP) | 1,870,511 | 1,723,351 | ||||
Total Losses on MTM Commodity Derivative Contracts | 20,580 | 59,771 | ||||
Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts | 20,846 | (21,965) | ||||
Losses on Asset Dispositions, Net | 3,836 | 14,969 | ||||
Adjusted EBITDAX (Non-GAAP) | $ | 1,915,773 | $ | 1,776,126 | ||
Adjusted EBITDAX (Non-GAAP) - Percentage Increase | 8% | |||||
EOG RESOURCES, INC. | |||||
Quantitative Reconciliation of Net Debt (Non-GAAP) and Total | |||||
Capitalization (Non-GAAP) as Used in the Calculation of | |||||
The Net Debt-to-Total Capitalization Ratio (Non-GAAP) to | |||||
Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) | |||||
(Unaudited; in millions, except ratio data) | |||||
The following chart reconciles Current and Long-Term Debt (GAAP) to Net Debt (Non-GAAP) and Total Capitalization (GAAP) to Total Capitalization (Non-GAAP), as used in the Net Debt-to-Total Capitalization ratio calculation. A portion of the cash is associated with international subsidiaries; tax considerations may impact debt paydown. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize Net Debt and Total Capitalization (Non-GAAP) in their Net Debt-to-Total Capitalization ratio calculation. EOG management uses this information for comparative purposes within the industry. | |||||
At | At | ||||
March 31, | December 31, | ||||
2019 | 2018 | ||||
Total Stockholders' Equity - (a) | $ | 19,904 | $ | 19,364 | |
Current and Long-Term Debt (GAAP) - (b) | 6,081 | 6,083 | |||
Less: Cash | (1,136) | (1,556) | |||
Net Debt (Non-GAAP) - (c) | 4,945 | 4,527 | |||
Total Capitalization (GAAP) - (a) + (b) | $ | 25,985 | $ | 25,447 | |
Total Capitalization (Non-GAAP) - (a) + (c) | $ | 24,849 | $ | 23,891 | |
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)] | 23% | 24% | |||
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)] | 20% | 19% | |||
EOG RESOURCES, INC. | |||||||||||
Crude Oil and Natural Gas Financial Commodity | |||||||||||
Derivative Contracts | |||||||||||
EOG accounts for financial commodity derivative contracts using the mark-to-market accounting method. Prices received by EOG for its crude oil production generally vary from NYMEX West Texas Intermediate prices due to adjustments for delivery location (basis) and other factors. EOG has entered into crude oil basis swap contracts in order to fix the differential between pricing in Midland, Texas, and Cushing, Oklahoma (Midland Differential). Presented below is a comprehensive summary of EOG's Midland Differential basis swap contracts through April 26, 2019. The weighted average price differential expressed in $/Bbl represents the amount of reduction to Cushing, Oklahoma, prices for the notional volumes expressed in Bbld covered by the basis swap contracts. | |||||||||||
Midland Differential Basis Swap Contracts | |||||||||||
Weighted | |||||||||||
Average Price | |||||||||||
Volume | Differential | ||||||||||
(Bbld) | ($/Bbl) | ||||||||||
2019 | |||||||||||
January 1, 2019 through May 31, 2019 (closed) | 20,000 | $ 1.075 | |||||||||
June 1, 2019 through December 31, 2019 | 20,000 | 1.075 | |||||||||
EOG has also entered into crude oil basis swap contracts in order to fix the differential between pricing in the U.S. Gulf Coast and Cushing, Oklahoma (Gulf Coast Differential). Presented below is a comprehensive summary of EOG's Gulf Coast Differential basis swap contracts through April 26, 2019. The weighted average price differential expressed in $/Bbl represents the amount of addition to Cushing, Oklahoma, prices for the notional volumes expressed in Bbld covered by the basis swap contracts. | |||||||||||
Gulf Coast Differential Basis Swap Contracts | |||||||||||
Weighted | |||||||||||
Average Price | |||||||||||
Volume | Differential | ||||||||||
(Bbld) | ($/Bbl) | ||||||||||
2019 | |||||||||||
January 1, 2019 through May 31, 2019 (closed) | 13,000 | $ 5.572 | |||||||||
June 1, 2019 through December 31, 2019 | 13,000 | 5.572 | |||||||||
Presented below is a comprehensive summary of EOG's crude oil price swap contracts through April 26, 2019, with notional volumes expressed in Bbld and prices expressed in $/Bbl. | |||||||||||
Crude Oil Price Swap Contracts | |||||||||||
Weighted | |||||||||||
Volume | Average Price | ||||||||||
(Bbld) | ($/Bbl) | ||||||||||
2019 | |||||||||||
April 2019 | 25,000 | $ 60.00 | |||||||||
May 1, 2019 through December 31, 2019 | 150,000 | 62.50 | |||||||||
Presented below is a comprehensive summary of EOG's natural gas price swap contracts through April 26, 2019, with notional volumes expressed in MMBtud and prices expressed in $/MMBtu. | |||||||||||
Natural Gas Price Swap Contracts | |||||||||||
Weighted | |||||||||||
Volume | Average Price | ||||||||||
(MMBtud) | ($/MMBtu) | ||||||||||
2019 | |||||||||||
April 1, 2019 through May 31, 2019 (closed) | 250,000 | $ 2.90 | |||||||||
June 1, 2019 through October 31, 2019 | 250,000 | 2.90 | |||||||||
Definitions | |||||||||||
Bbld | Barrels per day | ||||||||||
$/Bbl | Dollars per barrel | ||||||||||
MMBtud | Million British thermal units per day | ||||||||||
$/MMBtu | Dollars per million British thermal units | ||||||||||
NYMEX | U.S. New York Mercantile Exchange | ||||||||||
EOG RESOURCES, INC. |
Direct After-Tax Rate of Return (ATROR) |
The calculation of our direct after-tax rate of return (ATROR) with respect to our capital expenditure program for a particular play or well is based on the estimated recoverable reserves ("net" to EOG's interest) for all wells in such play or such well (as the case may be), the estimated net present value (NPV) of the future net cash flows from such reserves (for which we utilize certain assumptions regarding future commodity prices and operating costs) and our direct net costs incurred in drilling or acquiring (as the case may be) such wells or well (as the case may be). As such, our direct ATROR with respect to our capital expenditures for a particular play or well cannot be calculated from our consolidated financial statements. |
Direct ATROR |
Based on Cash Flow and Time Value of Money |
- Estimated future commodity prices and operating costs |
- Costs incurred to drill, complete and equip a well, including facilities |
Excludes Indirect Capital |
- Gathering and Processing and other Midstream |
- Land, Seismic, Geological and Geophysical |
Payback ~12 Months on 100% Direct ATROR Wells |
First Five Years ~1/2 Estimated Ultimate Recovery Produced but ~3/4 of NPV Captured |
Return on Equity / Return on Capital Employed |
Based on GAAP Accrual Accounting |
Includes All Indirect Capital and Growth Capital for Infrastructure |
- Eagle Ford, Bakken, Permian Facilities |
- Gathering and Processing |
Includes Legacy Gas Capital and Capital from Mature Wells |
EOG RESOURCES, INC. | ||||||||
Quantitative Reconciliation of After-Tax Net Interest Expense (Non-GAAP), Adjusted Net Income (Non-GAAP), | ||||||||
Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP) as Used in the Calculations of Return on Capital | ||||||||
Employed (Non-GAAP) and Return on Equity (Non-GAAP) to Net Interest Expense (GAAP), Net Income | ||||||||
(GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP), Respectively | ||||||||
(Unaudited; in millions, except ratio data) | ||||||||
The following chart reconciles Net Interest Expense (GAAP), Net Income (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. | ||||||||
2018 | 2017 | |||||||
Return on Capital Employed (ROCE) (Non-GAAP) | ||||||||
Net Interest Expense (GAAP) | $ | 245 | ||||||
Tax Benefit Imputed (based on 21%) | (51) | |||||||
After-Tax Net Interest Expense (Non-GAAP) - (a) | $ | 194 | ||||||
Net Income (GAAP) - (b) | $ | 3,419 | ||||||
Adjustments to Net Income, Net of Tax (See Accompanying Schedule) | (201) | (1) | ||||||
Adjusted Net Income (Non-GAAP) - (c) | $ | 3,218 | ||||||
Total Stockholders' Equity - (d) | $ | 19,364 | $ | 16,283 | ||||
Average Total Stockholders' Equity * - (e) | $ | 17,824 | ||||||
Current and Long-Term Debt (GAAP) - (f) | $ | 6,083 | $ | 6,387 | ||||
Less: Cash | (1,556) | (834) | ||||||
Net Debt (Non-GAAP) - (g) | $ | 4,527 | $ | 5,553 | ||||
Total Capitalization (GAAP) - (d) + (f) | $ | 25,447 | $ | 22,670 | ||||
Total Capitalization (Non-GAAP) - (d) + (g) | $ | 23,891 | $ | 21,836 | ||||
Average Total Capitalization (Non-GAAP) * - (h) | $ | 22,864 | ||||||
ROCE (GAAP Net Income) - [(a) + (b)] / (h) | 15.8% | |||||||
ROCE (Non-GAAP Adjusted Net Income) - [(a) + (c)] / (h) | 14.9% | |||||||
Return on Equity (ROE) | ||||||||
ROE (GAAP Net Income) - (b) / (e) | 19.2% | |||||||
ROE (Non-GAAP Adjusted Net Income) - (c) / (e) | 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 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. | ||||||||||
Quantitative Reconciliation of After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total | ||||||||||
Capitalization (Non-GAAP) as Used in the Calculation of Return on Capital Employed (Non-GAAP) to Net Interest | ||||||||||
Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP), Respectively | ||||||||||
(Unaudited; in millions, except ratio data) | ||||||||||
The following chart reconciles Net Interest Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) (Non-GAAP) calculation. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Net Debt and Total Capitalization (Non-GAAP) in their ROCE calculation. EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry. | ||||||||||
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. | ||||||||||
Quantitative Reconciliation of After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total | ||||||||||
Capitalization (Non-GAAP) as Used in the Calculation of Return on Capital Employed (Non-GAAP) to Net Interest | ||||||||||
Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP), Respectively | ||||||||||
(Unaudited; in millions, except ratio data) | ||||||||||
The following chart reconciles Net Interest Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) (Non-GAAP) calculation. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Net Debt and Total Capitalization (Non-GAAP) in their ROCE calculation. EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry. | ||||||||||
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. | ||||||||||
Quantitative Reconciliation of After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total | ||||||||||
Capitalization (Non-GAAP) as Used in the Calculation of Return on Capital Employed (Non-GAAP) to Net Interest | ||||||||||
Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP), Respectively | ||||||||||
(Unaudited; in millions, except ratio data) | ||||||||||
The following chart reconciles Net Interest Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) (Non-GAAP) calculation. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Net Debt and Total Capitalization (Non-GAAP) in their ROCE calculation. EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry. | ||||||||||
2007 | 2006 | 2005 | 2004 | 2003 | ||||||
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. | ||||||||||
Quantitative Reconciliation of After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total | ||||||||||
Capitalization (Non-GAAP) as Used in the Calculation of Return on Capital Employed (Non-GAAP) to Net Interest | ||||||||||
Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP), Respectively | ||||||||||
(Unaudited; in millions, except ratio data) | ||||||||||
The following chart reconciles Net Interest Expense (GAAP), Current and Long-Term Debt (GAAP) and Total Capitalization (GAAP) to After-Tax Net Interest Expense (Non-GAAP), Net Debt (Non-GAAP) and Total Capitalization (Non-GAAP), respectively, as used in the Return on Capital Employed (ROCE) (Non-GAAP) calculation. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize After-Tax Net Interest Expense, Net Debt and Total Capitalization (Non-GAAP) in their ROCE calculation. EOG management uses this information for purposes of comparing its financial performance with the financial performance of other companies in the industry. | ||||||||||
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 | |||||||||||
2019 | 2018 | ||||||||||
Cash Operating Expenses (GAAP)* | |||||||||||
Lease and Well | $ 336,291 | $ 300,064 | |||||||||
Transportation Costs | 176,522 | 176,957 | |||||||||
General and Administrative | 106,672 | 94,698 | |||||||||
Cash Operating Expenses | 619,485 | 571,719 | |||||||||
Less: Non-GAAP Adjustments | - | - | |||||||||
Adjusted Cash Operating Expenses (Non-GAAP) - (a) | $ 619,485 | $ 571,719 | |||||||||
Volume - Thousand Barrels of Oil Equivalent - (b) | 69,623 | 59,394 | |||||||||
Adjusted Cash Operating Expenses Per Boe (Non-GAAP) - (a) / (b) | $ 8.90 | (c) | $ 9.63 | (d) | |||||||
Adjusted Cash Operating Expenses Per Boe (Non-GAAP) - Percentage Decrease | |||||||||||
1Q19 compared to 1Q18 - [(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, | |||||||||||
2018 | 2017 | 2016 | 2015 | 2014 | |||||||
Cash Operating Expenses (GAAP)* | |||||||||||
Lease and Well | $ 1,282,678 | $ 1,044,847 | $ 927,452 | $ 1,182,282 | $ 1,416,413 | ||||||
Transportation Costs | 746,876 | 740,352 | 764,106 | 849,319 | 972,176 | ||||||
General and Administrative | 426,969 | 434,467 | 394,815 | 366,594 | 402,010 | ||||||
Cash Operating Expenses | 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) | $ 2,456,523 | $ 2,201,880 | $ 2,039,219 | $ 2,378,840 | $ 2,790,599 | ||||||
Volume - Thousand Barrels of Oil Equivalent - (b) | 262,516 | 222,251 | 204,929 | 208,862 | 217,073 | ||||||
Adjusted Cash Operating Expenses Per Boe (Non-GAAP) - (a) / (b) | $ 9.36 | (c) | $ 9.91 | (d) | $ 9.95 | (e) | $ 11.39 | (f) | $ 12.86 | (g) | |
Adjusted Cash Operating Expenses Per Boe (Non-GAAP) - Percentage Decrease | |||||||||||
2018 compared to 2017 - [(c) - (d)] / (d) | -6% | ||||||||||
2018 compared to 2016 - [(c) - (e)] / (e) | -6% | ||||||||||
2018 compared to 2015 - [(c) - (f)] / (f) | -18% | ||||||||||
2018 compared to 2014 - [(c) - (g)] / (g) | -27% | ||||||||||
* 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, | ||||||||||
2019 | ||||||||||
Volume - Thousand Barrels of Oil Equivalent - (a) | 69,623 | |||||||||
Crude Oil and Condensate | $ 2,200,403 | |||||||||
Natural Gas Liquids | 218,638 | |||||||||
Natural Gas | 334,972 | |||||||||
Total Wellhead Revenues - (b) | $ 2,754,013 | |||||||||
Operating Costs | ||||||||||
Lease and Well | $ 336,291 | |||||||||
Transportation Costs | 176,522 | |||||||||
Gathering and Processing Costs | 111,295 | |||||||||
General and Administrative | 106,672 | |||||||||
Taxes Other Than Income | 192,906 | |||||||||
Interest Expense, Net | 54,906 | |||||||||
Total Cash Operating Cost (excluding DD&A and Total Exploration Costs) - (c) | $ 978,592 | |||||||||
Depreciation, Depletion and Amortization (DD&A) | 879,595 | |||||||||
Total Operating Cost (excluding Total Exploration Costs) - (d) | $ 1,858,187 | |||||||||
Exploration Costs | $ 36,324 | |||||||||
Dry Hole Costs | 94 | |||||||||
Impairments | 72,356 | |||||||||
Total Exploration Costs | 108,774 | |||||||||
Less: Impairments (Non-GAAP) | (23,745) | |||||||||
Total Exploration Costs (Non-GAAP) | $ 85,029 | |||||||||
Total Operating Cost (Non-GAAP) (including Total Exploration Costs) - (e) | $ 1,943,216 | |||||||||
Composite Average Wellhead Revenue per Boe - (b) / (a) | $ 39.56 | |||||||||
Total Cash Operating Cost per Boe (excluding DD&A and Total Exploration Costs) - (c) / (a) | $ 14.06 | |||||||||
Composite Average Margin per Boe (excluding DD&A and Total Exploration Costs) - [(b) / (a) - (c) / (a)] | $ 25.50 | |||||||||
Total Operating Cost per Boe (excluding Total Exploration Costs) - (d) / (a) | $ 26.69 | |||||||||
Composite Average Margin per Boe (excluding Total Exploration Costs) - [(b) / (a) - (d) / (a)] | $ 12.87 | |||||||||
Total Operating Cost per Boe (Non-GAAP) (including Total Exploration Costs) - (e) / (a) | $ 27.91 | |||||||||
Composite Average Margin per Boe (Non-GAAP) (including Total Exploration Costs) - [(b) / (a) - (e) / (a)] | $ 11.65 | |||||||||
EOG RESOURCES, INC. | ||||||||||
Cost per Barrel of Oil Equivalent (Boe) | ||||||||||
(Unaudited; in thousands, except per Boe amounts) | ||||||||||
Year Ended | ||||||||||
December 31, | ||||||||||
2018 | 2017 | 2016 | 2015 | 2014 | ||||||
Volume - Thousand Barrels of Oil Equivalent - (a) | 262,516 | 222,251 | 204,929 | 208,862 | 217,073 | |||||
Crude Oil and Condensate | $ 9,517,440 | $ 6,256,396 | $ 4,317,341 | $ 4,934,562 | $ 9,742,480 | |||||
Natural Gas Liquids | 1,127,510 | 729,561 | 437,250 | 407,658 | 934,051 | |||||
Natural Gas | 1,301,537 | 921,934 | 742,152 | 1,061,038 | 1,916,386 | |||||
Total Wellhead Revenues - (b) | $ 11,946,487 | $ 7,907,891 | $ 5,496,743 | $ 6,403,258 | $ 12,592,917 | |||||
Operating Costs | ||||||||||
Lease and Well | $ 1,282,678 | $ 1,044,847 | $ 927,452 | $ 1,182,282 | $ 1,416,413 | |||||
Transportation Costs | 746,876 | 740,352 | 764,106 | 849,319 | 972,176 | |||||
Gathering and Processing Costs | 436,973 | 148,775 | 122,901 | 146,156 | 145,800 | |||||
General and Administrative | 426,969 | 434,467 | 394,815 | 366,594 | 402,010 | |||||
Less: Voluntary Retirement Expense | - | - | (42,054) | - | - | |||||
Less: Acquisition Costs | - | - | (5,100) | - | - | |||||
Less: Legal Settlement - Early Leasehold Termination | - | (10,202) | - | (19,355) | - | |||||
Less: Joint Venture Transaction Costs | - | (3,056) | - | - | - | |||||
Less: Joint Interest Billings Deemed Uncollectible | - | (4,528) | - | - | - | |||||
General and Administrative (Non-GAAP) | 426,969 | 416,681 | 347,661 | 347,239 | 402,010 | |||||
Taxes Other Than Income | 772,481 | 544,662 | 349,710 | 421,744 | 757,564 | |||||
Interest Expense, Net | 245,052 | 274,372 | 281,681 | 237,393 | 201,458 | |||||
Total Cash Operating Cost (Non-GAAP) (excluding DD&A and Total Exploration Costs) - (c) | $ 3,911,029 | $ 3,169,689 | $ 2,793,511 | $ 3,184,133 | $ 3,895,421 | |||||
Depreciation, Depletion and Amortization (DD&A) | 3,435,408 | 3,409,387 | 3,553,417 | 3,313,644 | 3,997,041 | |||||
Total Operating Cost (Non-GAAP) (excluding Total Exploration Costs) - (d) | $ 7,346,437 | $ 6,579,076 | $ 6,346,928 | $ 6,497,777 | $ 7,892,462 | |||||
Exploration Costs | $ 148,999 | $ 145,342 | $ 124,953 | $ 149,494 | $ 184,388 | |||||
Dry Hole Costs | 5,405 | 4,609 | 10,657 | 14,746 | 48,490 | |||||
Impairments | 347,021 | 479,240 | 620,267 | 6,613,546 | 743,575 | |||||
Total Exploration Costs | 501,425 | 629,191 | 755,877 | 6,777,786 | 976,453 | |||||
Less: Impairments (Non-GAAP) | (152,671) | (261,452) | (320,617) | (6,307,593) | (824,312) | |||||
Total Exploration Costs (Non-GAAP) | $ 348,754 | $ 367,739 | $ 435,260 | $ 470,193 | $ 152,141 | |||||
Total Operating Cost (Non-GAAP) (including Total Exploration Costs) - (e) | $ 7,695,191 | $ 6,946,815 | $ 6,782,188 | $ 6,967,970 | $ 8,044,603 | |||||
Composite Average Wellhead Revenue per Boe - (b) / (a) | $ 45.51 | $ 35.58 | $ 26.82 | $ 30.66 | $ 58.01 | |||||
Total Cash Operating Cost per Boe (Non-GAAP) (excluding DD&A and Total Exploration Costs) - (c) / (a) | $ 14.90 | $ 14.25 | $ 13.64 | $ 15.25 | $ 17.95 | |||||
Composite Average Margin per Boe (Non-GAAP) (excluding DD&A and Total Exploration Costs) - [(b) / (a) - (c) / (a)] | $ 30.61 | $ 21.33 | $ 13.18 | $ 15.41 | $ 40.06 | |||||
Total Operating Cost per Boe (Non-GAAP) (excluding Total Exploration Costs) - (d) / (a) | $ 27.99 | $ 29.59 | $ 30.98 | $ 31.11 | $ 36.38 | |||||
Composite Average Margin per Boe (Non-GAAP) (excluding Total Exploration Costs) - [(b) / (a) - (d) / (a)] | $ 17.52 | $ 5.99 | $ (4.16) | $ (0.45) | $ 21.63 | |||||
Total Operating Cost per Boe (Non-GAAP) (including Total Exploration Costs) - (e) / (a) | $ 29.32 | $ 31.24 | $ 33.10 | $ 33.36 | $ 37.08 | |||||
Composite Average Margin per Boe (Non-GAAP) (including Total Exploration Costs) - [(b) / (a) - (e) / (a)] | $ 16.19 | $ 4.34 | $ (6.28) | $ (2.70) | $ 20.93 | |||||
EOG RESOURCES, INC. | |||||||||||
Second Quarter and Full Year 2019 Forecast and Benchmark Commodity Pricing | |||||||||||
(a) Second Quarter and Full Year 2019 Forecast | |||||||||||
The forecast items for the second quarter and full year 2019 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 Exchanges. | |||||||||||
(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 2019 | Full Year 2019 | ||||||||||
Daily Sales Volumes | |||||||||||
Crude Oil and Condensate Volumes (MBbld) | |||||||||||
United States | 446.5 | - | 454.1 | 442.6 | - | 458.2 | |||||
Trinidad | 0.5 | - | 0.7 | 0.4 | - | 0.6 | |||||
Other International | 0.0 | - | 0.2 | 0.0 | - | 0.2 | |||||
Total | 447.0 | - | 455.0 | 443.0 | - | 459.0 | |||||
Natural Gas Liquids Volumes (MBbld) | |||||||||||
Total | 122.0 | - | 132.0 | 120.0 | - | 140.0 | |||||
Natural Gas Volumes (MMcfd) | |||||||||||
United States | 1,025 | - | 1,075 | 1,030 | - | 1,130 | |||||
Trinidad | 245 | - | 275 | 250 | - | 290 | |||||
Other International | 30 | - | 40 | 30 | - | 40 | |||||
Total | 1,300 | - | 1,390 | 1,310 | - | 1,460 | |||||
Crude Oil Equivalent Volumes (MBoed) | |||||||||||
United States | 739.3 | - | 765.3 | 734.3 | - | 786.5 | |||||
Trinidad | 41.3 | - | 46.5 | 42.1 | - | 48.9 | |||||
Other International | 5.0 | - | 6.9 | 5.0 | - | 6.9 | |||||
Total | 785.6 | - | 818.7 | 781.4 | - | 842.3 | |||||
Capital Expenditures ($MM) | $ | 1,600 | - | $ | 1,800 | $ | 6,100 | - | $ | 6,500 | |
Estimated Ranges | |||||||||||
(Unaudited) | |||||||||||
2Q 2019 | Full Year 2019 | ||||||||||
Operating Costs | |||||||||||
Unit Costs ($/Boe) | |||||||||||
Lease and Well | $ | 4.65 | - | $ | 5.05 | $ | 4.50 | - | $ | 5.30 | |
Transportation Costs | $ | 2.30 | - | $ | 2.80 | $ | 2.50 | - | $ | 3.00 | |
Depreciation, Depletion and Amortization | $ | 12.75 | - | $ | 13.25 | $ | 12.25 | - | $ | 13.25 | |
Expenses ($MM) | |||||||||||
Exploration and Dry Hole | $ | 30 | - | $ | 40 | $ | 155 | - | $ | 195 | |
Impairment | $ | 55 | - | $ | 65 | $ | 190 | - | $ | 230 | |
General and Administrative | $ | 110 | - | $ | 120 | $ | 450 | - | $ | 490 | |
Gathering and Processing | $ | 110 | - | $ | 120 | $ | 440 | - | $ | 480 | |
Capitalized Interest | $ | 7 | - | $ | 9 | $ | 30 | - | $ | 35 | |
Net Interest | $ | 50 | - | $ | 52 | $ | 185 | - | $ | 195 | |
Taxes Other Than Income (% of Wellhead Revenue) | 7.0% | - | 7.4% | 7.0% | - | 7.4% | |||||
Income Taxes | |||||||||||
Effective Rate | 21% | - | 26% | 21% | - | 26% | |||||
Current Tax (Benefit) / Expense ($MM) | $ | - | - | $ | 40 | $ | (10) | - | $ | 30 | |
Pricing - (Refer to Benchmark Commodity Pricing in text) | |||||||||||
Crude Oil and Condensate ($/Bbl) | |||||||||||
Differentials | |||||||||||
United States - above (below) WTI | $ | 0.50 | - | $ | 1.50 | $ | (0.50) | - | $ | 1.50 | |
Trinidad - above (below) WTI | $ | (11.00) | - | $ | (9.00) | $ | (11.00) | - | $ | (9.00) | |
Other International - above (below) WTI | $ | (9.00) | - | $ | (5.00) | $ | (1.00) | - | $ | 1.00 | |
Natural Gas Liquids | |||||||||||
Realizations as % of WTI | 32% | - | 40% | 32% | - | 40% | |||||
Natural Gas ($/Mcf) | |||||||||||
Differentials | |||||||||||
United States - above (below) NYMEX Henry Hub | $ | (0.60) | - | $ | (0.20) | $ | (0.80) | - | $ | (0.20) | |
Realizations | |||||||||||
Trinidad | $ | 2.60 | - | $ | 3.00 | $ | 2.50 | - | $ | 3.20 | |
Other International | $ | 4.20 | - | $ | 4.70 | $ | 4.00 | - | $ | 5.00 | |
Definitions | |||||||||||
$/Bbl U.S. Dollars per barrel | |||||||||||
$/Boe U.S. Dollars per barrel of oil equivalent | |||||||||||
$/Mcf U.S. Dollars per thousand cubic feet | |||||||||||
$MM U.S. Dollars in millions | |||||||||||
MBbld Thousand barrels per day | |||||||||||
MBoed Thousand barrels of oil equivalent per day | |||||||||||
MMcfd Million cubic feet per day | |||||||||||
NYMEX U.S. New York Mercantile Exchange | |||||||||||
WTI West Texas Intermediate | |||||||||||
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SOURCE EOG Resources, Inc.