Delaware (State or other jurisdiction of incorporation) | 1-9743 (Commission File Number) | 47-0684736 (I.R.S. Employer Identification No.) |
EOG RESOURCES, INC. (Registrant) | ||
Date: November 4, 2014 | By: | /s/ TIMOTHY K. DRIGGERS Timothy K. Driggers Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Officer) |
99.1 | Press Release of EOG Resources, Inc. dated November 4, 2014 (including the accompanying fourth quarter and full year 2014 forecast and benchmark commodity pricing information). |
EOG Resources, Inc. | |
News Release | |
For Further Information Contact: | Investors |
Maire A. Baldwin | |
(713) 651-6364 | |
Kimberly A. Matthews | |
(713) 571-4676 | |
David J. Streit | |
(713) 571-4902 | |
Media | |
K Leonard | |
(713) 571-3870 |
• | Increases 2014 Full-Year Crude Oil and Condensate Production Growth Goal to 31 Percent from 29 Percent |
• | Raises 2014 Total Production Growth Target to 16.5 Percent from 14 Percent |
• | Reports 29 Percent Increase in U.S. Crude Oil and Condensate Production and 17 Percent Growth in Total Company Production Year-Over-Year |
• | Confirms Prolific, Highly Over-Pressured Crude Oil Window on Delaware Basin Wolfcamp Acreage |
• | Realizes Strong Drilling Results from Eagle Ford, Emerging Delaware Basin and Rockies Crude Oil Plays |
• | the timing and extent of changes in prices for, 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 optimize 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, natural gas and related commodity production; |
• | the availability, proximity and capacity of, and costs associated with, appropriate gathering, processing, compression, transportation and refining facilities; |
• | the availability, cost, terms and timing of issuance or execution of, and competition for, mineral licenses and leases and governmental and other permits and rights-of-way, and EOG’s ability to retain mineral licenses and leases; |
• | the impact of, and changes in, government policies, laws and regulations, including tax laws and regulations; environmental, health and safety laws and regulations relating to air emissions, disposal of produced water, drilling fluids and other wastes, hydraulic fracturing and access to and use of water; laws and regulations imposing conditions or restrictions on drilling and completion operations and on the transportation of crude oil and natural gas; laws and regulations with respect to derivatives and hedging activities; and laws and regulations with respect to the import and export of crude oil, natural gas and related commodities; |
• | EOG's ability to effectively integrate acquired crude oil and natural gas properties into its operations, fully identify existing and potential problems with respect to such properties and accurately estimate reserves, production and costs with respect to such properties; |
• | the extent to which EOG's third-party-operated crude oil and natural gas properties are operated successfully and economically; |
• | competition in the oil and gas exploration and production industry for employees and other personnel, facilities, equipment, materials and services; |
• | the availability and cost of employees and other personnel, facilities, equipment, materials (such as water) and services; |
• | the accuracy of reserve estimates, which by their nature involve the exercise of professional judgment and may therefore be imprecise; |
• | weather, including its impact on crude oil and natural gas demand, and weather-related delays in drilling and in the installation and operation (by EOG or third parties) of production, gathering, processing, refining, compression and transportation facilities; |
• | the ability of EOG's customers and other contractual counterparties to satisfy their obligations to EOG and, related thereto, to access the credit and capital markets to obtain financing needed to satisfy their obligations to EOG; |
• | EOG's ability to access the commercial paper market and other credit and capital markets to obtain financing on terms it deems acceptable, if at all, and to otherwise satisfy its capital expenditure requirements; |
• | the extent and effect of any hedging activities engaged in by EOG; |
• | the timing and extent of changes in foreign currency exchange rates, interest rates, inflation rates, global and domestic financial market conditions and global and domestic general economic conditions; |
• | political conditions and developments around the world (such as political instability and armed conflict), including in the areas in which EOG operates; |
• | the use of competing energy sources and the development of alternative energy sources; |
• | the extent to which EOG incurs uninsured losses and liabilities or losses and liabilities in excess of its insurance coverage; |
• | acts of war and terrorism and responses to these acts; |
• | physical, electronic and cyber security breaches; and |
• | the other factors described under Item 1A, “Risk Factors”, on pages 17 through 26 of EOG’s Annual Report on Form 10-K for the fiscal year ended December 31, 2013 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. |
EOG RESOURCES, INC. FINANCIAL REPORT (Unaudited; in millions, except per share data) | |||||||||||||||
Three Months Ended | Nine Months Ended | ||||||||||||||
September 30, | September 30, | ||||||||||||||
2014 | 2013 | 2014 | 2013 | ||||||||||||
Net Operating Revenues | $ | 5,118.6 | $ | 3,541.4 | $ | 13,389.8 | $ | 10,738.1 | |||||||
Net Income | $ | 1,103.6 | $ | 462.5 | $ | 2,470.9 | $ | 1,616.9 | |||||||
Net Income Per Share | |||||||||||||||
Basic | $ | 2.03 | $ | 0.85 | $ | 4.55 | $ | 3.00 | |||||||
Diluted | $ | 2.01 | $ | 0.85 | $ | 4.51 | $ | 2.96 | |||||||
Average Number of Common Shares | |||||||||||||||
Basic | 544.0 | 540.9 | 543.1 | 539.9 | |||||||||||
Diluted | 549.5 | 547.2 | 548.4 | 545.7 | |||||||||||
SUMMARY INCOME STATEMENTS (Unaudited; in thousands, except per share data) | |||||||||||||||
Three Months Ended | Nine Months Ended | ||||||||||||||
September 30, | September 30, | ||||||||||||||
2014 | 2013 | 2014 | 2013 | ||||||||||||
Net Operating Revenues | |||||||||||||||
Crude Oil and Condensate | $ | 2,671,502 | $ | 2,337,742 | $ | 7,687,579 | $ | 6,132,574 | |||||||
Natural Gas Liquids | 258,927 | 208,190 | 753,135 | 556,176 | |||||||||||
Natural Gas | 443,108 | 396,123 | 1,508,892 | 1,269,604 | |||||||||||
Gains (Losses) on Mark-to-Market Commodity Derivative Contracts | 469,125 | (293,387 | ) | 84,119 | (206,853 | ) | |||||||||
Gathering, Processing and Marketing | 1,196,933 | 872,699 | 3,240,139 | 2,755,069 | |||||||||||
Gains on Asset Dispositions, Net | 60,346 | 8,183 | 75,700 | 185,569 | |||||||||||
Other, Net | 18,675 | 11,846 | 40,279 | 45,956 | |||||||||||
Total | 5,118,616 | 3,541,396 | 13,389,843 | 10,738,095 | |||||||||||
Operating Expenses | |||||||||||||||
Lease and Well | 368,340 | 299,169 | 1,035,632 | 817,057 | |||||||||||
Transportation Costs | 246,067 | 219,790 | 729,883 | 628,538 | |||||||||||
Gathering and Processing Costs | 41,621 | 31,121 | 108,015 | 81,522 | |||||||||||
Exploration Costs | 48,955 | 39,429 | 139,221 | 130,968 | |||||||||||
Dry Hole Costs | 16,359 | 19,548 | 30,265 | 59,260 | |||||||||||
Impairments | 55,542 | 85,917 | 207,938 | 177,432 | |||||||||||
Marketing Costs | 1,213,652 | 876,761 | 3,263,471 | 2,746,900 | |||||||||||
Depreciation, Depletion and Amortization | 1,040,018 | 928,800 | 2,983,111 | 2,685,719 | |||||||||||
General and Administrative | 96,931 | 98,654 | 270,725 | 257,246 | |||||||||||
Taxes Other Than Income | 204,969 | 172,438 | 606,411 | 458,566 | |||||||||||
Total | 3,332,454 | 2,771,627 | 9,374,672 | 8,043,208 | |||||||||||
Operating Income | 1,786,162 | 769,769 | 4,015,171 | 2,694,887 | |||||||||||
Other Income (Expense), Net | (21,338 | ) | 11,168 | (16,726 | ) | 5,867 | |||||||||
Income Before Interest Expense and Income Taxes | 1,764,824 | 780,937 | 3,998,445 | 2,700,754 | |||||||||||
Interest Expense, Net | 49,704 | 59,382 | 151,723 | 182,950 | |||||||||||
Income Before Income Taxes | 1,715,120 | 721,555 | 3,846,722 | 2,517,804 | |||||||||||
Income Tax Provision | 611,502 | 259,057 | 1,375,823 | 900,889 | |||||||||||
Net Income | $ | 1,103,618 | $ | 462,498 | $ | 2,470,899 | $ | 1,616,915 | |||||||
Dividends Declared per Common Share | $ | 0.1675 | $ | 0.0938 | $ | 0.4175 | $ | 0.2813 | |||||||
Note: All share and per-share amounts shown have been restated to reflect the 2-for-1 stock split effective March 31, 2014. |
EOG RESOURCES, INC. OPERATING HIGHLIGHTS (Unaudited) | |||||||||||||||
Three Months Ended | Nine Months Ended | ||||||||||||||
September 30, | September 30, | ||||||||||||||
2014 | 2013 | 2014 | 2013 | ||||||||||||
Wellhead Volumes and Prices | |||||||||||||||
Crude Oil and Condensate Volumes (MBbld) (A) | |||||||||||||||
United States | 293.2 | 227.6 | 275.5 | 204.3 | |||||||||||
Canada | 5.3 | 6.1 | 6.0 | 6.7 | |||||||||||
Trinidad | 0.9 | 1.2 | 1.0 | 1.3 | |||||||||||
Other International (B) | 0.1 | 0.1 | 0.1 | 0.1 | |||||||||||
Total | 299.5 | 235.0 | 282.6 | 212.4 | |||||||||||
Average Crude Oil and Condensate Prices ($/Bbl) (C) | |||||||||||||||
United States | $ | 97.33 | $ | 108.56 | $ | 100.10 | $ | 106.36 | |||||||
Canada | 87.64 | 97.90 | 90.74 | 90.53 | |||||||||||
Trinidad | 87.87 | 94.96 | 90.84 | 91.80 | |||||||||||
Other International (B) | 94.31 | 81.30 | 90.68 | 88.90 | |||||||||||
Composite | 97.13 | 108.20 | 99.87 | 105.76 | |||||||||||
Natural Gas Liquids Volumes (MBbld) (A) | |||||||||||||||
United States | 85.8 | 68.2 | 78.4 | 63.5 | |||||||||||
Canada | 0.6 | 0.9 | 0.7 | 0.9 | |||||||||||
Total | 86.4 | 69.1 | 79.1 | 64.4 | |||||||||||
Average Natural Gas Liquids Prices ($/Bbl) (C) | |||||||||||||||
United States | $ | 32.61 | $ | 32.75 | $ | 34.83 | $ | 31.55 | |||||||
Canada | 40.38 | 32.24 | 43.01 | 37.83 | |||||||||||
Composite | 32.67 | 32.74 | 34.90 | 31.64 | |||||||||||
Natural Gas Volumes (MMcfd) (A) | |||||||||||||||
United States | 941 | 899 | 920 | 920 | |||||||||||
Canada | 63 | 76 | 65 | 78 | |||||||||||
Trinidad | 356 | 352 | 374 | 350 | |||||||||||
Other International (B) | 9 | 7 | 9 | 8 | |||||||||||
Total | 1,369 | 1,334 | 1,368 | 1,356 | |||||||||||
Average Natural Gas Prices ($/Mcf) (C) | |||||||||||||||
United States | $ | 3.48 | $ | 3.19 | $ | 4.17 | $ | 3.33 | |||||||
Canada | 4.05 | 2.61 | 4.49 | 3.01 | |||||||||||
Trinidad | 3.50 | 3.41 | 3.61 | 3.71 | |||||||||||
Other International (B) | 5.00 | 6.12 | 5.03 | 6.58 | |||||||||||
Composite | 3.52 | 3.23 | 4.04 | 3.43 | |||||||||||
Crude Oil Equivalent Volumes (MBoed) (D) | |||||||||||||||
United States | 536.1 | 445.7 | 507.3 | 421.2 | |||||||||||
Canada | 16.4 | 19.7 | 17.5 | 20.7 | |||||||||||
Trinidad | 60.1 | 59.8 | 63.4 | 59.5 | |||||||||||
Other International (B) | 1.5 | 1.2 | 1.5 | 1.4 | |||||||||||
Total | 614.1 | 526.4 | 589.7 | 502.8 | |||||||||||
Total MMBoe (D) | 56.5 | 48.4 | 161.0 | 137.3 |
(A) | Thousand barrels per day or million cubic feet per day, as applicable. |
(B) | Other International includes EOG's United Kingdom, China and Argentina operations. |
(C) | Dollars per barrel or per thousand cubic feet, as applicable. Excludes the impact of financial commodity derivative instruments. |
(D) | Thousand barrels of oil equivalent per day or million barrels of oil equivalent, as applicable; includes crude oil and condensate, natural gas liquids and natural gas. Crude oil equivalents are determined using the ratio of 1.0 barrel of crude oil and condensate or natural gas liquids to 6.0 thousand cubic feet of natural gas. MMBoe is calculated by multiplying the MBoed amount by the number of days in the period and then dividing that amount by one thousand. |
EOG RESOURCES, INC. SUMMARY BALANCE SHEETS (Unaudited; in thousands, except share data) | |||||||
September 30, | December 31, | ||||||
2014 | 2013 | ||||||
ASSETS | |||||||
Current Assets | |||||||
Cash and Cash Equivalents | $ | 1,481,145 | $ | 1,318,209 | |||
Accounts Receivable, Net | 2,009,091 | 1,658,853 | |||||
Inventories | 672,899 | 563,268 | |||||
Assets from Price Risk Management Activities | 132,931 | 8,260 | |||||
Income Taxes Receivable | 17,978 | 4,797 | |||||
Deferred Income Taxes | 238,258 | 244,606 | |||||
Other | 332,414 | 274,022 | |||||
Total | 4,884,716 | 4,072,015 | |||||
Property, Plant and Equipment | |||||||
Oil and Gas Properties (Successful Efforts Method) | 47,912,930 | 42,821,803 | |||||
Other Property, Plant and Equipment | 3,571,545 | 2,967,085 | |||||
Total Property, Plant and Equipment | 51,484,475 | 45,788,888 | |||||
Less: Accumulated Depreciation, Depletion and Amortization | (22,267,642 | ) | (19,640,052 | ) | |||
Total Property, Plant and Equipment, Net | 29,216,833 | 26,148,836 | |||||
Other Assets | 399,334 | 353,387 | |||||
Total Assets | $ | 34,500,883 | $ | 30,574,238 | |||
LIABILITIES AND STOCKHOLDERS' EQUITY | |||||||
Current Liabilities | |||||||
Accounts Payable | $ | 2,775,342 | $ | 2,254,418 | |||
Accrued Taxes Payable | 257,948 | 159,365 | |||||
Dividends Payable | 91,094 | 50,795 | |||||
Liabilities from Price Risk Management Activities | — | 127,542 | |||||
Deferred Income Taxes | 2,444 | — | |||||
Current Portion of Long-Term Debt | 6,579 | 6,579 | |||||
Other | 245,339 | 263,017 | |||||
Total | 3,378,746 | 2,861,716 | |||||
Long-Term Debt | 5,903,232 | 5,906,642 | |||||
Other Liabilities | 1,084,461 | 865,067 | |||||
Deferred Income Taxes | 6,414,546 | 5,522,354 | |||||
Commitments and Contingencies | |||||||
Stockholders' Equity | |||||||
Common Stock, $0.01 Par, 640,000,000 Shares Authorized and 548,601,616 Shares Issued at September 30, 2014 and 546,378,440 Shares Issued at December 31, 2013 | 205,488 | 202,732 | |||||
Additional Paid in Capital | 2,785,716 | 2,646,879 | |||||
Accumulated Other Comprehensive Income | 387,725 | 415,834 | |||||
Retained Earnings | 14,410,707 | 12,168,277 | |||||
Common Stock Held in Treasury, 701,786 Shares at September 30, 2014 and 206,830 Shares at December 31, 2013 | (69,738 | ) | (15,263 | ) | |||
Total Stockholders' Equity | 17,719,898 | 15,418,459 | |||||
Total Liabilities and Stockholders’ Equity | $ | 34,500,883 | $ | 30,574,238 | |||
EOG RESOURCES, INC. SUMMARY STATEMENTS OF CASH FLOWS (Unaudited; in thousands) | |||||||
Nine Months Ended | |||||||
September 30, | |||||||
2014 | 2013 | ||||||
Cash Flows from Operating Activities | |||||||
Reconciliation of Net Income to Net Cash Provided by Operating Activities: | |||||||
Net Income | $ | 2,470,899 | $ | 1,616,915 | |||
Items Not Requiring (Providing) Cash | |||||||
Depreciation, Depletion and Amortization | 2,983,111 | 2,685,719 | |||||
Impairments | 207,938 | 177,432 | |||||
Stock-Based Compensation Expenses | 103,636 | 103,171 | |||||
Deferred Income Taxes | 974,522 | 657,686 | |||||
Gains on Asset Dispositions, Net | (75,700 | ) | (185,569 | ) | |||
Other, Net | 17,188 | 460 | |||||
Dry Hole Costs | 30,265 | 59,260 | |||||
Mark-to-Market Commodity Derivative Contracts | |||||||
Total (Gains) Losses | (84,119 | ) | 206,853 | ||||
Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts | (188,937 | ) | 115,323 | ||||
Excess Tax Benefits from Stock-Based Compensation | (87,827 | ) | (50,230 | ) | |||
Other, Net | 8,701 | 16,222 | |||||
Changes in Components of Working Capital and Other Assets and Liabilities | |||||||
Accounts Receivable | (341,043 | ) | (213,746 | ) | |||
Inventories | (119,166 | ) | 61,147 | ||||
Accounts Payable | 566,753 | 145,199 | |||||
Accrued Taxes Payable | 176,412 | 73,197 | |||||
Other Assets | (61,966 | ) | (78,799 | ) | |||
Other Liabilities | 66,618 | 10,889 | |||||
Changes in Components of Working Capital Associated with Investing and Financing Activities | (108,568 | ) | (72,945 | ) | |||
Net Cash Provided by Operating Activities | 6,538,717 | 5,328,184 | |||||
Investing Cash Flows | |||||||
Additions to Oil and Gas Properties | (5,653,035 | ) | (5,084,335 | ) | |||
Additions to Other Property, Plant and Equipment | (587,178 | ) | (271,136 | ) | |||
Proceeds from Sales of Assets | 91,335 | 587,273 | |||||
Changes in Restricted Cash | (91,238 | ) | (68,061 | ) | |||
Changes in Components of Working Capital Associated with Investing Activities | 108,999 | 72,916 | |||||
Net Cash Used in Investing Activities | (6,131,117 | ) | (4,763,343 | ) | |||
Financing Cash Flows | |||||||
Long-Term Debt Borrowings | 496,220 | — | |||||
Long-Term Debt Repayments | (500,000 | ) | — | ||||
Settlement of Foreign Currency Swap | (31,573 | ) | — | ||||
Dividends Paid | (187,670 | ) | (147,731 | ) | |||
Excess Tax Benefits from Stock-Based Compensation | 87,827 | 50,230 | |||||
Treasury Stock Purchased | (114,824 | ) | (55,562 | ) | |||
Proceeds from Stock Options Exercised and Employee Stock Purchase Plan | 11,740 | 30,080 | |||||
Debt Issuance Costs | (895 | ) | — | ||||
Repayment of Capital Lease Obligation | (4,457 | ) | (4,318 | ) | |||
Other, Net | (431 | ) | 29 | ||||
Net Cash Used in Financing Activities | (244,063 | ) | (127,272 | ) | |||
Effect of Exchange Rate Changes on Cash | (601 | ) | 4,813 | ||||
Increase in Cash and Cash Equivalents | 162,936 | 442,382 | |||||
Cash and Cash Equivalents at Beginning of Period | 1,318,209 | 876,435 | |||||
Cash and Cash Equivalents at End of Period | $ | 1,481,145 | $ | 1,318,817 |
EOG RESOURCES, INC. QUANTITATIVE RECONCILIATION OF ADJUSTED NET INCOME (NON-GAAP) TO NET INCOME (GAAP) (Unaudited; in thousands, except per share data) | |||||||||||||||
The following chart adjusts the three-month and nine-month periods ended September 30, 2014 and 2013 reported Net Income (GAAP) to reflect actual net cash received from (payments for) settlements of commodity derivative contracts by eliminating the unrealized mark-to-market (gains) losses from these transactions, to eliminate the net gains on asset dispositions in North America in 2014 and 2013 and to add back impairment charges related to certain of EOG's non-core North American assets in 2014 and 2013. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported company earnings to match realizations to production settlement months and make certain other adjustments to exclude non-recurring items. EOG management uses this information for comparative purposes within the industry. | |||||||||||||||
Three Months Ended | Nine Months Ended | ||||||||||||||
September 30, | September 30, | ||||||||||||||
2014 | 2013 | 2014 | 2013 | ||||||||||||
Reported Net Income (GAAP) | $ | 1,103,618 | $ | 462,498 | $ | 2,470,899 | $ | 1,616,915 | |||||||
Commodity Derivative Contracts Impact | |||||||||||||||
(Gains) Losses on Mark-to-Market Commodity Derivative Contracts | (469,125 | ) | 293,387 | (84,119 | ) | 206,853 | |||||||||
Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts | (68,037 | ) | (20,636 | ) | (188,937 | ) | 115,323 | ||||||||
Subtotal | (537,162 | ) | 272,751 | (273,056 | ) | 322,176 | |||||||||
After-Tax Impact | (344,616 | ) | 174,628 | (175,179 | ) | 206,273 | |||||||||
Less: Net Gains on Asset Dispositions, Net of Tax | (38,386 | ) | (5,241 | ) | (47,426 | ) | (129,616 | ) | |||||||
Add: Impairments of Certain North American Assets, Net of Tax | — | 2,422 | 36,058 | 4,425 | |||||||||||
Adjusted Net Income (Non-GAAP) | $ | 720,616 | $ | 634,307 | $ | 2,284,352 | $ | 1,697,997 | |||||||
Net Income Per Share (GAAP) | |||||||||||||||
Basic | $ | 2.03 | $ | 0.85 | $ | 4.55 | $ | 3.00 | |||||||
Diluted | $ | 2.01 | $ | 0.85 | $ | 4.51 | $ | 2.96 | |||||||
Adjusted Net Income Per Share (Non-GAAP) | |||||||||||||||
Basic | $ | 1.32 | $ | 1.17 | $ | 4.21 | $ | 3.15 | |||||||
Diluted | $ | 1.31 | $ | 1.16 | $ | 4.17 | $ | 3.11 | |||||||
Adjusted Net Income Per Diluted Share (Non-GAAP) - Percentage Increase | 13 | % | 34 | % | |||||||||||
Average Number of Common Shares (GAAP) | |||||||||||||||
Basic | 543,984 | 540,941 | 543,086 | 539,869 | |||||||||||
Diluted | 549,518 | 547,152 | 548,401 | 545,712 |
EOG RESOURCES, INC. QUANTITATIVE RECONCILIATION OF DISCRETIONARY CASH FLOW (NON-GAAP) TO NET CASH PROVIDED BY OPERATING ACTIVITIES (GAAP) (Unaudited; in thousands) | |||||||||||||||
The following chart reconciles the three-month and nine-month periods ended September 30, 2014 and 2013 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 management uses this information for comparative purposes within the industry. | |||||||||||||||
Three Months Ended | Nine Months Ended | ||||||||||||||
September 30, | September 30, | ||||||||||||||
2014 | 2013 | 2014 | 2013 | ||||||||||||
Net Cash Provided by Operating Activities (GAAP) | $ | 2,336,469 | $ | 2,012,472 | $ | 6,538,717 | $ | 5,328,184 | |||||||
Adjustments: | |||||||||||||||
Exploration Costs (excluding Stock-Based Compensation Expenses) | 42,220 | 32,755 | 119,003 | 110,330 | |||||||||||
Excess Tax Benefits from Stock-Based Compensation | 24,068 | 28,361 | 87,827 | 50,230 | |||||||||||
Changes in Components of Working Capital and Other Assets and Liabilities | |||||||||||||||
Accounts Receivable | 91,707 | 48,937 | 341,043 | 213,746 | |||||||||||
Inventories | 9,410 | (39,062 | ) | 119,166 | (61,147 | ) | |||||||||
Accounts Payable | (219,214 | ) | (3,830 | ) | (566,753 | ) | (145,199 | ) | |||||||
Accrued Taxes Payable | (60,744 | ) | (48,381 | ) | (176,412 | ) | (73,197 | ) | |||||||
Other Assets | (79,487 | ) | (13,506 | ) | 61,966 | 78,799 | |||||||||
Other Liabilities | (9,517 | ) | (62,289 | ) | (66,618 | ) | (10,889 | ) | |||||||
Changes in Components of Working Capital Associated with Investing and Financing Activities | 76,924 | 53,306 | 108,568 | 72,945 | |||||||||||
Discretionary Cash Flow (Non-GAAP) | $ | 2,211,836 | $ | 2,008,763 | $ | 6,566,507 | $ | 5,563,802 | |||||||
Discretionary Cash Flow (Non-GAAP) - Percentage Increase | 10 | % | 18 | % |
EOG RESOURCES, INC. QUANTITATIVE RECONCILIATION OF ADJUSTED EARNINGS BEFORE INTEREST EXPENSE, INCOME TAXES, DEPRECIATION, DEPLETION AND AMORTIZATION, EXPLORATION COSTS, DRY HOLE COSTS, IMPAIRMENTS AND ADDITIONAL ITEMS (ADJUSTED EBITDAX) (NON-GAAP) TO INCOME BEFORE INTEREST EXPENSE AND INCOME TAXES (GAAP) (Unaudited; in thousands) | |||||||||||||||
The following chart adjusts the three-month and nine-month periods ended September 30, 2014 and 2013 reported Income Before Interest Expense and Income Taxes (GAAP) to Earnings Before Interest Expense, Income Taxes, Depreciation, Depletion and Amortization, Exploration Costs, Dry Hole Costs and Impairments (EBITDAX) (Non-GAAP) and further adjusts such amount to reflect actual net cash received from (payments for) settlements of commodity derivative contracts by eliminating the unrealized mark-to-market (MTM) (gains) losses from these transactions and to eliminate the net gains on asset dispositions in North America in 2014 and 2013. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who adjust reported Income Before Interest Expense and Income Taxes (GAAP) to add back 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 items. EOG management uses this information for comparative purposes within the industry. | |||||||||||||||
Three Months Ended | Nine Months Ended | ||||||||||||||
September 30, | September 30, | ||||||||||||||
2014 | 2013 | 2014 | 2013 | ||||||||||||
Income Before Interest Expense and Income Taxes (GAAP) | $ | 1,764,824 | $ | 780,937 | $ | 3,998,445 | $ | 2,700,754 | |||||||
Adjustments: | |||||||||||||||
Depreciation, Depletion and Amortization | 1,040,018 | 928,800 | 2,983,111 | 2,685,719 | |||||||||||
Exploration Costs | 48,955 | 39,429 | 139,221 | 130,968 | |||||||||||
Dry Hole Costs | 16,359 | 19,548 | 30,265 | 59,260 | |||||||||||
Impairments | 55,542 | 85,917 | 207,938 | 177,432 | |||||||||||
EBITDAX (Non-GAAP) | 2,925,698 | 1,854,631 | 7,358,980 | 5,754,133 | |||||||||||
Total (Gains) Losses on MTM Commodity Derivative Contracts | (469,125 | ) | 293,387 | (84,119 | ) | 206,853 | |||||||||
Net Cash Received from (Payments for) Settlements of Commodity Derivative Contracts | (68,037 | ) | (20,636 | ) | (188,937 | ) | 115,323 | ||||||||
Gains on Asset Dispositions, Net | (60,346 | ) | (8,183 | ) | (75,700 | ) | (185,569 | ) | |||||||
Adjusted EBITDAX (Non-GAAP) | $ | 2,328,190 | $ | 2,119,199 | $ | 7,010,224 | $ | 5,890,740 | |||||||
Adjusted EBITDAX (Non-GAAP) - Percentage Increase | 10 | % | 19 | % |
EOG RESOURCES, INC. QUANTITATIVE RECONCILIATION OF NET DEBT (NON-GAAP) AND TOTAL CAPITALIZATION (NON-GAAP) AS USED IN THE CALCULATION OF THE NET DEBT-TO-TOTAL CAPITALIZATION RATIO (NON-GAAP) TO CURRENT AND LONG-TERM DEBT (GAAP) AND TOTAL CAPITALIZATION (GAAP) (Unaudited; in millions, except ratio data) | |||||||
The following chart reconciles Current and Long-Term Debt (GAAP) to Net Debt (Non-GAAP) and Total Capitalization (GAAP) to Total Capitalization (Non-GAAP), as used in the Net Debt-to-Total Capitalization ratio calculation. A portion of the cash is associated with international subsidiaries; tax considerations may impact debt paydown. EOG believes this presentation may be useful to investors who follow the practice of some industry analysts who utilize Net Debt and Total Capitalization (Non-GAAP) in their Net Debt-to-Total Capitalization ratio calculation. EOG management uses this information for comparative purposes within the industry. | |||||||
At | At | ||||||
September 30, | December 31, | ||||||
2014 | 2013 | ||||||
Total Stockholders' Equity - (a) | $ | 17,720 | $ | 15,418 | |||
Current and Long-Term Debt (GAAP) - (b) | 5,910 | 5,913 | |||||
Less: Cash | (1,481 | ) | (1,318 | ) | |||
Net Debt (Non-GAAP) - (c) | 4,429 | 4,595 | |||||
Total Capitalization (GAAP) - (a) + (b) | $ | 23,630 | $ | 21,331 | |||
Total Capitalization (Non-GAAP) - (a) + (c) | $ | 22,149 | $ | 20,013 | |||
Debt-to-Total Capitalization (GAAP) - (b) / [(a) + (b)] | 25 | % | 28% | ||||
Net Debt-to-Total Capitalization (Non-GAAP) - (c) / [(a) + (c)] | 20 | % | 23% |
EOG RESOURCES, INC. CRUDE OIL AND NATURAL GAS FINANCIAL COMMODITY DERIVATIVE CONTRACTS | |||||||||
Presented below is a comprehensive summary of EOG's crude oil and natural gas derivative contracts at November 4, 2014, with notional volumes expressed in Bbld and MMBtud and prices expressed in $/Bbl and $/MMBtu. EOG accounts for financial commodity derivative contracts using the mark-to-market accounting method. | |||||||||
CRUDE OIL DERIVATIVE CONTRACTS | |||||||||
Weighted | |||||||||
Volume | Average Price | ||||||||
(Bbld) | ($/Bbl) | ||||||||
2014 | |||||||||
January 2014 (closed) | 156,000 | $ | 96.30 | ||||||
February 2014 (closed) | 171,000 | 96.35 | |||||||
March 1, 2014 through June 30, 2014 (closed) | 181,000 | 96.55 | |||||||
July 1, 2014 through August 31, 2014 (closed) | 202,000 | 96.34 | |||||||
September 1, 2014 through October 31, 2014 (closed) | 192,000 | 96.15 | |||||||
November 1, 2014 through December 31, 2014 | 192,000 | 96.15 | |||||||
2015 (1) | |||||||||
January 1, 2015 through June 30, 2015 | 47,000 | $ | 91.22 | ||||||
July 1, 2015 through December 31, 2015 | 10,000 | 89.98 | |||||||
(1) | EOG has entered into crude oil derivative contracts which give counterparties the option to extend certain current derivative contracts for additional six-month periods. Options covering a notional volume of 69,000 Bbld are exercisable on or about December 31, 2014. If the counterparties exercise all such options, the notional volume of EOG's existing crude oil derivative contracts will increase by 69,000 Bbld at an average price of $95.20 per barrel for each month during the period January 1, 2015 through June 30, 2015. Options covering a notional volume of 37,000 Bbld are exercisable on June 30, 2015. If the counterparties exercise all such options, the notional volume of EOG's existing crude oil derivative contracts will increase by 37,000 Bbld at an average price of $91.56 per barrel for each month during the period July 1, 2015 through December 31, 2015. |
NATURAL GAS DERIVATIVE CONTRACTS | |||||||||
Weighted | |||||||||
Volume | Average Price | ||||||||
(MMBtud) | ($/MMBtu) | ||||||||
2014 (2) | |||||||||
January 2014 (closed) | 230,000 | $ | 4.51 | ||||||
February 2014 (closed) | 710,000 | 4.57 | |||||||
March 2014 (closed) | 810,000 | 4.60 | |||||||
April 2014 (closed) | 465,000 | 4.52 | |||||||
May 2014 (closed) | 685,000 | 4.55 | |||||||
June 2014 (closed) | 515,000 | 4.52 | |||||||
July 2014 (closed) | 340,000 | 4.55 | |||||||
August 1, 2014 through November 30, 2014 (closed) | 330,000 | 4.55 | |||||||
December 2014 | 330,000 | 4.55 | |||||||
2015 (3) | |||||||||
January 1, 2015 through December 31, 2015 | 175,000 | $ | 4.51 | ||||||
(2) | EOG has entered into natural gas derivative contracts which give counterparties the option of entering into derivative contracts at future dates. All such options are exercisable monthly up until the settlement date of each monthly contract. For December 2014, if the counterparties exercise all such options, the notional volume of EOG's existing natural gas derivative contracts will increase by 480,000 MMBtud at an average price of $4.63 per MMBtu. | ||||||||
(3) | EOG has entered into natural gas derivative contracts which give counterparties the option of entering into derivative contracts at future dates. All such options are exercisable monthly up until the settlement date of each monthly contract. If the counterparties exercise all such options, the notional volume of EOG's existing natural gas derivative contracts will increase by 175,000 MMBtud at an average price of $4.51 per MMBtu for each month during the period January 1, 2015 through December 31, 2015. |
$/Bbl | Dollars per barrel | |
$/MMBtu | Dollars per million British thermal units | |
Bbld | Barrels per day | |
MMBtu | Million British thermal units | |
MMBtud | Million British thermal units per day |
EOG RESOURCES, INC. FOURTH QUARTER AND FULL YEAR 2014 FORECAST AND BENCHMARK COMMODITY PRICING | |||||||||||||||||||
(a) Fourth Quarter and Full Year 2014 Forecast | |||||||||||||||||||
The forecast items for the fourth quarter and full year 2014 set forth below for EOG Resources, Inc. (EOG) are based on current available information and expectations as of the date of the accompanying press release. EOG undertakes no obligation, other than as required by applicable law, to update or revise this forecast, whether as a result of new information, subsequent events, anticipated or unanticipated circumstances or otherwise. This forecast, which should be read in conjunction with the accompanying press release and EOG’s related Current Report on Form 8-K filing, replaces and supersedes any previously issued guidance or forecast. | |||||||||||||||||||
(b) Benchmark Commodity Pricing | |||||||||||||||||||
EOG bases United States, Canada 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 and Canada natural gas price differentials upon the natural gas price at Henry Hub, Louisiana, using the simple average of the NYMEX settlement prices for the last three trading days of the applicable month. | |||||||||||||||||||
ESTIMATED RANGES (Unaudited) | |||||||||||||||||||
4Q 2014 | Full Year 2014 | ||||||||||||||||||
Daily Production | |||||||||||||||||||
Crude Oil and Condensate Volumes (MBbld) | |||||||||||||||||||
United States | 293.0 | - | 300.0 | 279.9 | - | 281.6 | |||||||||||||
Canada | 6.5 | - | 7.5 | 6.2 | - | 6.4 | |||||||||||||
Trinidad | 0.5 | - | 0.7 | 0.8 | - | 1.0 | |||||||||||||
Other International | 0.0 | - | 0.0 | 0.0 | - | 0.1 | |||||||||||||
Total | 300.0 | - | 308.2 | 286.9 | - | 289.1 | |||||||||||||
Natural Gas Liquids Volumes (MBbld) | |||||||||||||||||||
United States | 81.0 | - | 87.0 | 79.1 | - | 80.6 | |||||||||||||
Canada | 0.4 | - | 0.6 | 0.6 | - | 0.7 | |||||||||||||
Total | 81.4 | - | 87.6 | 79.7 | - | 81.3 | |||||||||||||
Natural Gas Volumes (MMcfd) | |||||||||||||||||||
United States | 905 | - | 925 | 916 | - | 921 | |||||||||||||
Canada | 60 | - | 66 | 63 | - | 65 | |||||||||||||
Trinidad | 324 | - | 372 | 362 | - | 374 | |||||||||||||
Other International | 8 | - | 10 | 8 | - | 9 | |||||||||||||
Total | 1,297 | - | 1,373 | 1,349 | - | 1,369 | |||||||||||||
Crude Oil Equivalent Volumes (MBoed) | |||||||||||||||||||
United States | 524.8 | - | 541.2 | 511.7 | - | 515.8 | |||||||||||||
Canada | 16.9 | - | 19.1 | 17.4 | - | 17.9 | |||||||||||||
Trinidad | 54.5 | - | 62.7 | 61.1 | - | 63.3 | |||||||||||||
Other International | 1.3 | - | 1.7 | 1.4 | - | 1.6 | |||||||||||||
Total | 597.5 | - | 624.7 | 591.6 | - | 598.6 | |||||||||||||
ESTIMATED RANGES (Unaudited) | |||||||||||||||||||
4Q 2014 | Full Year 2014 | ||||||||||||||||||
Operating Costs | |||||||||||||||||||
Unit Costs ($/Boe) | |||||||||||||||||||
Lease and Well | $ | 6.50 | - | $ | 6.80 | $ | 6.45 | - | $ | 6.53 | |||||||||
Transportation Costs | $ | 4.55 | - | $ | 4.75 | $ | 4.54 | - | $ | 4.59 | |||||||||
Depreciation, Depletion and Amortization | $ | 18.10 | - | $ | 18.70 | $ | 18.43 | - | $ | 18.58 | |||||||||
Expenses ($MM) | |||||||||||||||||||
Exploration, Dry Hole and Impairment | $ | 155 | - | $ | 175 | $ | 476 | - | $ | 496 | |||||||||
General and Administrative | $ | 102 | - | $ | 112 | $ | 373 | - | $ | 383 | |||||||||
Gathering and Processing | $ | 34 | - | $ | 40 | $ | 142 | - | $ | 148 | |||||||||
Capitalized Interest | $ | 14 | - | $ | 16 | $ | 57 | - | $ | 59 | |||||||||
Net Interest | $ | 48 | - | $ | 52 | $ | 200 | - | $ | 204 | |||||||||
Taxes Other Than Income (% of Wellhead Revenue) | 6.1 | % | - | 6.5 | % | 6.0 | % | - | 6.4 | % | |||||||||
Income Taxes | |||||||||||||||||||
Effective Rate | 32 | % | - | 37 | % | 34 | % | - | 37 | % | |||||||||
Current Taxes ($MM) | $ | 115 | - | $ | 130 | $ | 515 | - | $ | 535 | |||||||||
Capital Expenditures ($MM) - FY 2014 (Excluding Acquisitions) | |||||||||||||||||||
Exploration and Development, Excluding Facilities | $ | 6,450 | - | $ | 6,550 | ||||||||||||||
Exploration and Development Facilities | $ | 880 | - | $ | 920 | ||||||||||||||
Gathering, Processing and Other | $ | 770 | - | $ | 810 | ||||||||||||||
Pricing - (Refer to Benchmark Commodity Pricing in text) | |||||||||||||||||||
Crude Oil and Condensate ($/Bbl) | |||||||||||||||||||
Differentials | |||||||||||||||||||
United States - (above) below WTI | $ | 0.50 | - | $ | 1.50 | $ | (0.09 | ) | - | $ | 0.25 | ||||||||
Canada - (above) below WTI | $ | 9.50 | - | $ | 10.50 | $ | 9.21 | - | $ | 9.90 | |||||||||
Trinidad - (above) below WTI | $ | 9.75 | - | $ | 10.75 | $ | 7.97 | - | $ | 8.75 | |||||||||
Natural Gas Liquids | |||||||||||||||||||
Realizations as % of WTI | |||||||||||||||||||
United States | 30 | % | - | 35 | % | 33 | % | - | 35 | % | |||||||||
Canada | 32 | % | - | 38 | % | 40 | % | - | 43 | % | |||||||||
Natural Gas ($/Mcf) | |||||||||||||||||||
Differentials | |||||||||||||||||||
United States - (above) below NYMEX Henry Hub | $ | 0.30 | - | $ | 0.70 | $ | 0.32 | - | $ | 0.43 | |||||||||
Canada - (above) below NYMEX Henry Hub | $ | 0.00 | - | $ | 0.30 | $ | 0.00 | - | $ | 0.09 | |||||||||
Realizations | |||||||||||||||||||
Trinidad | $ | 3.10 | - | $ | 3.50 | $ | 3.50 | - | $ | 3.58 | |||||||||
Other International | $ | 4.45 | - | $ | 5.45 | $ | 4.87 | - | $ | 5.12 | |||||||||
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 | New York Mercantile Exchange | ||||||||||||||||||
WTI | West Texas Intermediate |
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