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Supplemental Information on Oil and Gas Operations (Unaudited) | 12 Months Ended
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Dec. 31, 2020
Oil And Gas Exploration And Production Industries Disclosures [Abstract] |
Supplemental Information on Oil and Gas Operations (Unaudited) |
2 2. | Supplemental Information on Oil and Gas Operations (Unaudited)
Supplemental unaudited information regarding Devon’s oil and gas activities is presented in this note. All of Devon’s reserves are located within the U.S. The supplemental information in the tables below excludes amounts for all periods presented related to Devon’s discontinued operations, which consist of Devon’s Canadian operations that were sold in 2019 and its Barnett Shale assets, inclusive of properties divested in previous reporting periods located primarily in Johnson and Wise counties, Texas, which were sold in October 2020. Amounts excluded for 2019 and 2018 consisted of 612 MMBoe and 1,104 MMBoe, respectively, of estimated proved reserves and $940 million and $3,042 million, respectively, of discounted future net cash flows, which related to both Devon’s Canadian operations and its Barnett Shale assets. For additional information on these discontinued operations, see Note 19. Costs Incurred The following tables reflect the costs incurred in oil and gas property acquisition, exploration and development activities.
|  | Year Ended December 31, |
|  | 2020 |  | 2019 |  |  | 2018 |
Property acquisition costs: |  |  |  |  |  |  |  |  |  |  |
Proved properties |  | $ | — |  | $ | — |  |  | $ | 2 |
Unproved properties |  |  | 8 |  |  | 35 |  |  |  | 70 |
Exploration costs |  |  | 159 |  |  | 312 |  |  |  | 679 |
Development costs |  |  | 820 |  |  | 1,499 |  |  |  | 1,505 |
Costs incurred |  | $ | 987 |  | $ | 1,846 |  |  | $ | 2,256 |
Development costs in the tables above include additions and revisions to Devon’s asset retirement obligations. Results of Operations The following tables include revenues and expenses associated with Devon’s oil and gas producing activities. They do not include any allocation of Devon’s interest costs or general corporate overhead and, therefore, are not necessarily indicative of the contribution to net earnings of Devon’s oil and gas operations. Income tax expense has been calculated by applying statutory income tax rates to oil, gas and NGL sales after deducting costs, including DD&A and after giving effect to permanent differences.
|  | Year Ended December 31,
|  | 2020 |  |  | 2019 |  |  | 2018 |  |
Oil, gas and NGL sales |  | $ | 2,695 |  |  | $ | 3,809 |  |  | $ | 4,085 |  |
Production expenses |  |  | (1,123 | ) |  |  | (1,197 | ) |  |  | (1,153 | ) |
Exploration expenses |  |  | (167 | ) |  |  | (58 | ) |  |  | (128 | ) |
Depreciation, depletion and amortization |  |  | (1,207 | ) |  |  | (1,398 | ) |  |  | (1,134 | ) |
Asset dispositions |  |  | — |  |  |  | 37 |  |  |  | 276 |  |
Asset impairments |  |  | (2,664 | ) |  |  | — |  |  |  | (109 | ) |
Accretion of asset retirement obligations |  |  | (20 | ) |  |  | (21 | ) |  |  | (26 | ) |
Income tax expense |  |  | — |  |  |  | (270 | ) |  |  | (416 | ) |
Results of operations |  | $ | (2,486 | ) |  | $ | 902 |  |  | $ | 1,395 |  |
Depreciation, depletion and amortization per Boe |  | $ | 9.90 |  |  | $ | 11.72 |  |  | $ | 10.51 |  |
Proved Reserves The following table presents Devon’s estimated proved reserves by product.
|  | Oil (MMBbls) |  |  | Gas (Bcf) (1) |  |  | NGL (MMBbls) |  |  | Combined (MMBoe) |
Proved developed and undeveloped reserves: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
December 31, 2017 |  |  | 254 |  |  |  | 1,810 |  |  |  | 231 |  |  |  | 787 |
Revisions due to prices |  |  | 12 |  |  |  | 7 |  |  |  | 2 |  |  |  | 15 |
Revisions other than price |  |  | (10 | ) |  |  | (102 | ) |  |  | (27 | ) |  |  | (53 | )
Extensions and discoveries |  |  | 93 |  |  |  | 358 |  |  |  | 54 |  |  |  | 206 |
Production |  |  | (47 | ) |  |  | (206 | ) |  |  | (26 | ) |  |  | (108 | )
Sale of reserves |  |  | (6 | ) |  |  | (65 | ) |  |  | (7 | ) |  |  | (24 | )
December 31, 2018 |  |  | 296 |  |  |  | 1,802 |  |  |  | 227 |  |  |  | 823 |
Revisions due to prices |  |  | (7 | ) |  |  | (86 | ) |  |  | (6 | ) |  |  | (28 | )
Revisions other than price |  |  | (13 | ) |  |  | (50 | ) |  |  | (9 | ) |  |  | (31 | )
Extensions and discoveries |  |  | 76 |  |  |  | 269 |  |  |  | 39 |  |  |  | 160 |
Purchase of reserves |  |  | 3 |  |  |  | 7 |  |  |  | 1 |  |  |  | 6 |
Production |  |  | (55 | ) |  |  | (219 | ) |  |  | (28 | ) |  |  | (119 | )
Sale of reserves |  |  | (24 | ) |  |  | (102 | ) |  |  | (13 | ) |  |  | (54 | )
December 31, 2019 |  |  | 276 |  |  |  | 1,621 |  |  |  | 211 |  |  |  | 757 |
Revisions due to prices |  |  | (26 | ) |  |  | (209 | ) |  |  | (17 | ) |  |  | (78 | )
Revisions other than price |  |  | 18 |  |  |  | 119 |  |  |  | 17 |  |  |  | 55 |
Extensions and discoveries |  |  | 71 |  |  |  | 188 |  |  |  | 33 |  |  |  | 135 |
Purchase of reserves |  |  | 1 |  |  |  | 19 |  |  |  | 3 |  |  |  | 7 |
Production |  |  | (57 | ) |  |  | (221 | ) |  |  | (28 | ) |  |  | (122 | )
Sale of reserves |  |  | (1 | ) |  |  | (5 | ) |  |  | (1 | ) |  |  | (2 | )
December 31, 2020 |  |  | 282 |  |  |  | 1,512 |  |  |  | 218 |  |  |  | 752 |
Proved developed reserves: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
December 31, 2017 |  |  | 175 |  |  |  | 1,455 |  |  |  | 168 |  |  |  | 585 |
December 31, 2018 |  |  | 196 |  |  |  | 1,427 |  |  |  | 166 |  |  |  | 600 |
December 31, 2019 |  |  | 198 |  |  |  | 1,344 |  |  |  | 167 |  |  |  | 589 |
December 31, 2020 |  |  | 194 |  |  |  | 1,244 |  |  |  | 173 |  |  |  | 574 |
Proved developed-producing reserves: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
December 31, 2017 |  |  | 163 |  |  |  | 1,384 |  |  |  | 160 |  |  |  | 554 |
December 31, 2018 |  |  | 188 |  |  |  | 1,394 |  |  |  | 162 |  |  |  | 582 |
December 31, 2019 |  |  | 191 |  |  |  | 1,327 |  |  |  | 165 |  |  |  | 578 |
December 31, 2020 |  |  | 190 |  |  |  | 1,223 |  |  |  | 171 |  |  |  | 564 |
Proved undeveloped reserves: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
December 31, 2017 |  |  | 79 |  |  |  | 355 |  |  |  | 63 |  |  |  | 202 |
December 31, 2018 |  |  | 100 |  |  |  | 375 |  |  |  | 61 |  |  |  | 223 |
December 31, 2019 |  |  | 78 |  |  |  | 277 |  |  |  | 44 |  |  |  | 168 |
December 31, 2020 |  |  | 88 |  |  |  | 268 |  |  |  | 45 |  |  |  | 178 |
(1) | Gas reserves are converted to Boe at the rate of six Mcf per Bbl of oil, based upon the approximate relative energy content of gas and oil. NGL reserves are converted to Boe on a one-to-one basis with oil. The conversion rates are not necessarily indicative of the relationship of oil, natural gas and NGL prices.
Price Revisions Reserves decreased 78 MMBoe in 2020 primarily due to price decreases in the trailing 12 month averages for oil, gas and NGLs. Reserves decreased 28 MMBoe in 2019 primarily due to price decreases in the trailing 12 month averages for oil, gas and NGLs. Reserves increased 15 MMBoe in 2018 primarily due to price increases in the trailing 12 month averages for oil, gas and NGLs. Revisions Other Than Price 2020 – Total revisions other than price (55 MMBoe) were primarily due to well performance exceeding previous estimates (75 MMBoe) and the removal of proved undeveloped locations as noted below (-20 MMBoe). The most significant well performance revisions were attributable to the Delaware Basin (40 MMBoe) and the STACK region of the Anadarko Basin (22 MMBoe). 2019 – Total revisions other than price in 2019 were primarily due to changes in previously adopted development plans in the STACK region of the Anadarko Basin (-9 MMBoe) and in the Delaware Basin (-6 MMBoe). An additional downward revision of 5 MMBoe was the result of reduced recovery estimates attributable to continued evaluation of analogous offset well performance primarily in the STACK region of the Anadarko Basin. 2018 – Total revisions other than price primarily related to Devon’s development programs evaluation of certain oil and dry gas regions, with the largest revisions being made in the STACK region of the Anadarko Basin. Extensions and Discoveries Each year, Devon’s proved reserves extensions and discoveries consist of adding proved undeveloped reserves to locations classified as undeveloped at year-end and adding proved developed reserves from successful development wells drilled on locations outside the areas classified as proved at the previous year-end. Therefore, it is not uncommon for Devon’s total proved extensions and discoveries to differ from the extensions and discoveries for Devon’s proved undeveloped reserves. Furthermore, because annual additions are classified according to reserve determinations made at the previous year-end and because Devon operates a multi-basin portfolio with assets at varying stages of maturity, extensions and discoveries for proved developed and proved undeveloped reserves can differ significantly in any particular year. 2020 – Of the 135 MMBoe of additions from extensions and discoveries, 117 MMBoe were in the Delaware Basin, 8 MMBoe were in the STACK region of the Anadarko Basin, 5 MMBoe in the Powder River Basin and 5 MMBoe in Eagle Ford. 2019 – Of the 160 MMBoe of additions from extensions and discoveries, 77 MMBoe were in the Delaware Basin, 37 MMBoe were in the STACK region of the Anadarko Basin, 28 MMBoe in the Powder River Basin and 18 MMBoe in Eagle Ford. In 2019, there were no additions related to infill drilling activities. 2018 – Approximately 85% of the additions were through focused efforts in the STACK region of the Anadarko Basin (87 MMBoe) and the Delaware Basin (88 MMBoe). The remaining extensions were added throughout the remainder of Devon’s portfolio. The 2018 extensions and discoveries included 21 MMBoe related to additions from Devon’s infill drilling activities, primarily relating to the STACK region of the Anadarko Basin. Sale of Reserves During 2020, 2019 and 2018, Devon had U.S. non-core asset divestitures. For additional information on these divestitures, see Note 2. Proved Undeveloped Reserves The following table presents the changes in Devon’s total proved undeveloped reserves during 2020 (MMBoe).
|  | Total |
Proved undeveloped reserves as of December 31, 2019 |  |  | 168 |
Extensions and discoveries |  |  | 105 |
Revisions due to prices |  |  | (8 | )
Revisions other than price |  |  | (20 | )
Purchase of reserves |  |  | 2 |
Sale of reserves |  |  | (1 | )
Conversion to proved developed reserves |  |  | (68 | )
Proved undeveloped reserves as of December 31, 2020 |  |  | 178 |
Total proved undeveloped reserves increased 6% from 2019 to 2020 with the year-end 2020 balance representing 24% of total proved reserves. Over 87% of the 105 MMBoe in extensions and discoveries were the result of Devon’s focus on drilling and development activities in the Delaware Basin. This continued development in the Delaware Basin also led to the conversion of 68 MMBoe, or 40% of the 2019 proved undeveloped reserves. Costs incurred to develop and convert Devon’s proved undeveloped reserves were approximately $448 million for 2020. Proved undeveloped reserves revisions other than price were primarily due to changes in previously adopted development plans in the STACK region of the Anadarko Basin (-12 MMBoe) and the Delaware Basin (-8 MMBoe). Standardized Measure The following tables reflect Devon’s standardized measure of discounted future net cash flows from its proved reserves.
|  | Year Ended December 31, |
|  | 2020 |  | 2019 |  |  | 2018 |
Future cash inflows |  | $ | 14,957 |  | $ | 20,750 |  |  | $ | 27,759 |
Future costs: |  |  |  |  |  |  |  |  |  |  |
Development |  |  | (1,747 | ) |  | (2,093 | ) |  |  | (2,957 | )
Production |  |  | (7,964 | ) |  | (9,174 | ) |  |  | (10,991 | )
Future income tax expense |  |  | — |  |  | (1,037 | ) |  |  | (2,036 | )
Future net cash flow |  |  | 5,246 |  |  | 8,446 |  |  |  | 11,775 |
10% discount to reflect timing of cash flows |  |  | (1,774 | ) |  | (3,048 | ) |  |  | (4,625 | )
Standardized measure of discounted future net cash flows |  | $ | 3,472 |  | $ | 5,398 |  |  | $ | 7,150 |
Future cash inflows, development costs and production costs were computed using the same assumptions for prices and costs that were used to estimate Devon’s proved oil and gas reserves at the end of each year. For 2020 estimates, Devon’s future realized prices were assumed to be $37.35 per Bbl of oil, $1.37 per Mcf of gas and $10.76 per Bbl of NGLs. Of the $1.7 billion of future development costs as of the end of 2020, $0.6 billion, $0.4 billion and $0.2 billion are estimated to be spent in 2021, 2022 and 2023, respectively. Future development costs include not only development costs but also future asset retirement costs. Included as part of the $1.7 billion of future development costs are $0.3 billion of future asset retirement costs. The future income tax expenses have been computed using statutory tax rates, giving effect to allowable tax deductions and tax credits under current laws. The principal changes in Devon’s standardized measure of discounted future net cash flows are as follows:
|  | Year Ended December 31, |
|  | 2020 |  |  | 2019 |  |  | 2018 |
Beginning balance |  | $ | 5,398 |  |  | $ | 7,150 |  |  | $ | 5,954 |
Net changes in prices and production costs |  |  | (3,277 | ) |  |  | (2,323 | ) |  |  | 1,533 |
Oil, gas and NGL sales, net of production costs |  |  | (1,572 | ) |  |  | (2,612 | ) |  |  | (2,932 | )
Changes in estimated future development costs |  |  | 402 |  |  |  | 303 |  |  |  | (273 | )
Extensions and discoveries, net of future development costs |  |  | 988 |  |  |  | 1,690 |  |  |  | 2,944 |
Purchase of reserves |  |  | 23 |  |  |  | 43 |  |  |  | — |
Sales of reserves in place |  |  | (7 | ) |  |  | (481 | ) |  |  | (120 | )
Revisions of quantity estimates |  |  | 147 |  |  |  | (359 | ) |  |  | (152 | )
Previously estimated development costs incurred during the period |  |  | 537 |  |  |  | 857 |  |  |  | 787 |
Accretion of discount |  |  | 285 |  |  |  | 506 |  |  |  | 648 |
Net change in income taxes and other |  |  | 548 |  |  |  | 624 |  |  |  | (1,239 | )
Ending balance |  | $ | 3,472 |  |  | $ | 5,398 |  |  | $ | 7,150 |

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