Devon Energy
Devon Energy produced 211.9 MMbbl of oil and 1.09 Tcf of natural gas in 2025. 11,233 operated producing wells tracked, trailing 12 months per region.
- Operated 10.4% of the oil produced in New Mexico, 2025.
- Oil production rose 11% in 2025 after acquiring Grayson Mill Energy.
Devon Energy's figures include production filed by its subsidiaries under their own names.
Devon Energy's figures include production filed by its subsidiaries under their own names. Under Current operator an old month can show a later company.
Production
Still arriving: Oct 2026 <1% filed.
All from what the source published. 99.79% held at well grain.
How the volume breaks down
- 85.4% Reported by the official source by well
- 0.21% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 13.3% Reported by the official source as a lease total, split across the lease's wells. The regional total shown is the reported number, to rounding.
- 0.07% Reported by the official source for a longer period, spread across its months. The period total is the reported number.
- 1.0% A series adjusted to match official published figures: a well's cumulative, a later correction netted into the months before it, a field's oil volume from the royalty file for a month missing from the production report, or a state's yearly total from a second official source.
- under 0.01% Filed with the official source, which withheld this period's production figure for one stream. That stream carries a placeholder zero.
Every barrel here starts from what the official source published for the months measured. Measured over January 1951 to June 2026.
The gray “without per-well detail” band is volume the source reports above the well: fields, facilities, or leases the source publishes as one total. It is included so the stack still sums to the whole entity.
Still arriving: Oct 2026 <1% filed.
The gray “without per-well detail” band is volume the source reports above the well: fields, facilities, or leases the source publishes as one total. It is included so the stack still sums to the whole entity.
Still arriving: Oct 2026 <1% filed.
All from what the source published. 99.27% held at well grain.
How the volume breaks down
- 93.8% Reported by the official source by well
- 0.73% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 5.2% Reported by the official source as a lease total, split across the lease's wells. The regional total shown is the reported number, to rounding.
- 0.01% Reported by the official source for a longer period, spread across its months. The period total is the reported number.
- 0.33% A series adjusted to match official published figures: a well's cumulative, a later correction netted into the months before it, a field's oil volume from the royalty file for a month missing from the production report, or a state's yearly total from a second official source.
Every cubic foot here starts from what the official source published for the months measured. Measured over January 1951 to June 2026.
The gray “without per-well detail” band is volume the source reports above the well: fields, facilities, or leases the source publishes as one total. It is included so the stack still sums to the whole entity.
Still arriving: Oct 2026 <1% filed.
The gray “without per-well detail” band is volume the source reports above the well: fields, facilities, or leases the source publishes as one total. It is included so the stack still sums to the whole entity.
The bands group wells by when they first produced.
About this chart
The stack shows what is holding today's rate up and how much of it is new drilling. The bands draw the filings already in.
These volumes are the production from the wells and facilities this company operates. Ownership works differently: other parties hold interests in these wells, and this company holds interests in wells that other companies operate. How we attribute production to a company
In Texas, production is reported for an oil lease or unit as well as for individual gas wells. Those lease and unit totals are divided among the wells they cover, and every Texas barrel is labeled reported or allocated. How well-level Texas production is built
Annual table (full history)
best estimate incl. unsplit totals and adjusted
| Year | Oil (MMbbl) | Gas produced (Bcf) |
|---|---|---|
| 2025 | 211.9 | 1,094 |
| 2024 | 191.6 | 916 |
| 2023 | 169.8 | 769 |
| 2022 | 162.6 | 718 |
| 2021 | 157.3 | 645 |
| 2020 | 91.9 | 633 |
| 2019 | 102.7 | 679 |
| 2018 | 112.0 | 719 |
| 2017 | 109.3 | 773 |
| 2016 | 113.8 | 833 |
| 2015 | 132.6 | 980 |
| 2014 | 95.3 | 1,088 |
| 2013 | 55.6 | 1,167 |
| 2012 | 44.4 | 1,235 |
| 2011 | 36.2 | 1,186 |
| 2010 | 32.8 | 1,194 |
| 2009 | 33.0 | 1,227 |
| 2008 | 33.5 | 1,235 |
| 2007 | 31.1 | 1,123 |
| 2006 | 23.9 | 1,027 |
| 2005 | 30.1 | 1,050 |
| 2004 | 37.4 | 1,135 |
| 2003 | 39.2 | 1,125 |
| 2002 | 35.8 | 1,059 |
| 2001 | 37.7 | 920 |
| 2000 | 36.1 | 760 |
| 1999 | 24.9 | 501 |
| 1998 | 20.8 | 407 |
| 1997 | 21.3 | 390 |
| 1996 | 16.7 | 290 |
| 1995 | 16.4 | 261 |
| 1994 | 14.7 | 251 |
| 1993 | 15.1 | 232 |
| 1992 | 13.7 | 160 |
| 1991 | 13.8 | 138 |
| 1990 | 12.7 | 135 |
| 1989 | 11.7 | 141 |
| 1988 | 11.7 | 148 |
| 1987 | 11.7 | 118 |
| 1986 | 11.9 | 92 |
| 1985 | 11.1 | 106 |
| 1984 | 11.0 | 82 |
| 1983 | 11.4 | 77 |
| 1982 | 11.7 | 66 |
| 1981 | 12.5 | 60 |
| 1980 | 14.6 | 46 |
| 1979 | 15.0 | 49 |
| 1978 | 16.9 | 45 |
| 1977 | 18.6 | 42 |
| 1976 | 20.7 | 45 |
| 1975 | 23.5 | 48 |
| 1974 | 23.9 | 43 |
| 1973 | 25.0 | 41 |
| 1972 | 19.5 | 30 |
| 1971 | 15.4 | 28 |
| 1970 | 11.7 | 25 |
| 1969 | 10.3 | 15 |
| 1968 | 9.7 | 9 |
| 1967 | 9.2 | 8 |
| 1966 | 8.1 | 7 |
| 1965 | 6.9 | 6 |
| 1964 | 5.9 | 6 |
| 1963 | 5.5 | 5 |
| 1962 | 5.1 | 5 |
| 1961 | 1.0 | <1 |
| 1960 | 1.0 | <1 |
| 1959 | 0.3 | <1 |
| 1958 | 0.3 | <1 |
| 1957 | 0.3 | <1 |
| 1956 | 0.2 | <1 |
| 1955 | 0.2 | <1 |
| 1954 | 0.2 | <1 |
| 1953 | 0.2 | <1 |
| 1952 | 0.2 | <1 |
| 1951 | 0.1 | <1 |
Source: CommoVision (commovision.com)
Monthly table (last 24 months)
| Month | Oil (Mbbl) | Gas produced (MMcf) |
|---|---|---|
| 2025-12 | 16,583.5 | 87,401 |
| 2025-11 | 17,235.0 | 88,064 |
| 2025-10 | 18,151.2 | 90,583 |
| 2025-09 | 16,263.5 | 86,899 |
| 2025-08 | 17,271.4 | 92,318 |
| 2025-07 | 18,054.2 | 94,235 |
| 2025-06 | 17,199.6 | 92,935 |
| 2025-05 | 18,250.8 | 99,316 |
| 2025-04 | 18,942.7 | 96,205 |
| 2025-03 | 19,277.9 | 95,862 |
| 2025-02 | 16,532.8 | 81,161 |
| 2025-01 | 18,167.7 | 88,649 |
| 2024-12 | 18,195.2 | 90,095 |
| 2024-11 | 18,798.2 | 90,555 |
| 2024-10 | 18,944.1 | 91,732 |
| 2024-09 | 15,092.7 | 75,553 |
| 2024-08 | 15,631.2 | 77,322 |
| 2024-07 | 15,749.6 | 75,588 |
| 2024-06 | 14,677.8 | 70,959 |
| 2024-05 | 15,582.5 | 71,526 |
| 2024-04 | 15,575.4 | 70,745 |
| 2024-03 | 15,760.3 | 71,912 |
| 2024-02 | 14,004.2 | 66,116 |
| 2024-01 | 13,602.6 | 63,637 |
Source: CommoVision (commovision.com)
Source: CommoVision · Devon Energy, data through June 2026.
Well map
- Oil 16,412
- Natural gas 18,001
- Undetermined 9,796
About this map
Undetermined means not enough signal to settle it. Producing wells are the ones that reported oil or gas in the trailing 12 months per region.
Type curves
39 of the drawn cohorts’ wells are not in these curves yet: each is still producing and joins its curve once it carries a forecast.
39 of the drawn cohorts’ wells are not in these curves yet: each is still producing and joins its curve once it carries a forecast.
best estimate incl. adjusted
Horizontal wells only. Average production per well, for wells grouped by when they first produced.
How these curves are built
Horizontal wells only: 6,739 of the 6,912 wells in these cohorts. Average daily production per well, for wells grouped by when they first produced. Includes every well of the cohort that is old enough at each month, except wells that are still active but not yet covered by our forecasts; those are left out of both the reported and forecast parts until they are. Wells that are shut in or have stopped producing count as zero, so the average reflects the whole group drawn, not just survivors. Rates are calendar-day (volume ÷ days in month). The cumulative axis accumulates those same monthly averages at the average month length. Months not yet fully reported are excluded. The 2010-2014 curve draws those years as one group. The chart opens on average daily rate against months on production, the rate on a log scale. The view control switches to rate against cumulative production per well, on the same log rate scale, or to cumulative production per well against months on production, on a linear scale. Every view draws the same cohorts from the same production history. Each cohort is solid through the last month all the wells in its curve sit inside fully reported data. Past it the dashed curve carries the same wells forward, on our forecast where a well’s own record ends, for up to five years. A dashed curve runs as far as at least nine in ten of its wells are accounted for. A well that is old enough but shut in still counts, as zero. The measured months are what these wells reported. In the forward months each well counts its own reported figure for each month it has one, our forecast for each month it has only that, and zero for the rest. The forward average counts every well in the curve. The drawn forecast runs up to five years past the measured months. Line thickness tracks how many wells each curve is drawn from. 23 wells are counted here but not shown on the age axis: they started producing in 1995 or earlier, too close to the start of our records for their region to verify their true age.
Cohort summary table
| First produced | Wells in curve | Peak oil (bbl/d per well) | Month-12 oil (bbl/d per well) | Cum oil in series (Mbbl per well) | Peak gas (Mcf/d per well) | Month-12 gas (Mcf/d per well) | Cum gas in series (Bcf per well) | Months in series | Wells old enough at last month in series | Forecast months drawn |
|---|---|---|---|---|---|---|---|---|---|---|
| 2026 | 235 | 597 | — | 18.2 | 1,600 | — | 0.0 | 1 | 100% | 60 |
| 2025 | 364 | 1,047 | — | 158 | 3,234 | — | 0.6 | 9 | 100% | 60 |
| 2024 | 417 | 1,022 | 256 | 236 | 3,219 | 1,592 | 1.1 | 21 | 100% | 60 |
| 2023 | 376 | 1,017 | 260 | 273 | 2,664 | 1,115 | 1.0 | 33 | 100% | 60 |
| 2022 | 337 | 1,086 | 240 | 303 | 2,770 | 1,122 | 1.3 | 45 | 100% | 60 |
| 2021 | 258 | 1,261 | 325 | 441 | 2,921 | 1,173 | 1.6 | 57 | 100% | 60 |
| 2020 | 244 | 1,245 | 339 | 443 | 2,123 | 922 | 1.3 | 69 | 100% | 60 |
| 2019 | 455 | 979 | 263 | 359 | 1,656 | 913 | 1.4 | 81 | 100% | 60 |
| 2018 | 395 | 894 | 245 | 343 | 1,665 | 841 | 1.3 | 93 | 100% | 60 |
| 2017 | 298 | 733 | 230 | 327 | 1,377 | 681 | 1.1 | 105 | 100% | 60 |
| 2016 | 270 | 597 | 246 | 336 | 1,127 | 625 | 1.0 | 117 | 100% | 60 |
| 2015 | 531 | 525 | 189 | 287 | 1,040 | 565 | 0.9 | 129 | 100% | 60 |
| 2010-2014 | 2,520 | 309 | 132 | 207 | 797 | 640 | 0.8 | 141 | 100% | 60 |
Source: CommoVision (commovision.com)
Source: CommoVision · Devon Energy type curves, per-well production by first-production cohort.
Recent permitting
About this chart
Approvals of every permit type per month, the 24 months to Nov 2026. The last bar is Nov 2026 through November 3, 2026 (7 so far), drawn hatched. Of the 951 approved in the 365 days to November 3, 2026, 950 are permits to drill a new well and 1 is another permit type. Permits to drill a new well: 950 in the 365 days to November 3, 2026 and 246 in the last 90 days of that window. How permits are counted.
- Devon Energy was granted 951 well permits in the 365 days to November 3, 2026. Of those, 247 came in the last 90 days of that window. The latest approval on record is dated November 3, 2026.
- Of the 951 approved in the 365 days to November 3, 2026, 950 are permits to drill a new well and 1 is another permit type. Permits to drill a new well: 950 in the 365 days to November 3, 2026 and 246 in the last 90 days of that window.
- Permits counted here come from Montana, North Dakota, New Mexico, Oklahoma, Pennsylvania, Texas and Wyoming.
- Brazil, Gulf of Mexico, Manitoba and Mississippi reach this page through production data alone.
Well permits approved per month: full table
| Month | Permits approved |
|---|---|
| Nov 2026 (through November 3, 2026) | 7 |
| Oct 2026 | 63 |
| Sep 2026 | 86 |
| Aug 2026 | 99 |
| Jul 2026 | 71 |
| Jun 2026 | 44 |
| May 2026 | 59 |
| Apr 2026 | 65 |
| Mar 2026 | 96 |
| Feb 2026 | 94 |
| Jan 2026 | 112 |
| Dec 2025 | 94 |
| Nov 2025 | 63 |
| Oct 2025 | 52 |
| Sep 2025 | 78 |
| Aug 2025 | 123 |
| Jul 2025 | 50 |
| Jun 2025 | 116 |
| May 2025 | 105 |
| Apr 2025 | 62 |
| Mar 2025 | 86 |
| Feb 2025 | 103 |
| Jan 2025 | 101 |
| Dec 2024 | 120 |
Source: CommoVision (commovision.com)
What we cover here
Each row names the grain a region’s production is held at. Where a source publishes at a coarser grain, the page says so.
| Data | Grain | Since | Benchmark |
|---|---|---|---|
| Alberta production | project + well | 1962-01 | ~100% of StatCan (oil) |
| Arkansas production | well | 1920-04 | ~62–101% of EIA |
| Brazil production | well | 1941-12 | — |
| Colorado production | well | 1999-01 | ~100% of EIA |
| Gulf of Mexico production | well | 1947-11 | ~100% of EIA |
| Kansas production | well | 1987-01 | ~99% of EIA |
| Louisiana production | well | 1977-01 | ~97–98% of EIA |
| Manitoba production | well | 1951-02 | ~100% of StatCan (oil) |
| Mississippi production | well | 1946-07 | ~100–102% of EIA |
| Montana production | well | 1986-01 | ~96–100% of EIA |
| North Dakota production | well | 1951-04 | ~99–100% of EIA |
| New Mexico production | well | 1924-01 | ~98–100% of EIA |
| Ohio production | well | 1955-08 | ~99% of EIA |
| Oklahoma production | lease + well | 1990-07 | ~99–100% of EIA |
| Pennsylvania production | well | 1980-01 | ~100% of EIA |
| Texas production | well | 1993-01 | ~100% of EIA |
| Utah production | well | 1984-01 | ~100% of EIA |
| West Virginia production | well | 1985-01 | ~99–100% of EIA |
| Wyoming production | well | 1978-01 | ~100–101% of EIA |
Where a row carries a Benchmark figure, the cell names the published estimate it compares against: the EIA’s for United States rows, Statistics Canada’s for Canadian rows.
About the benchmark comparisons
Where a row carries a Benchmark figure, it names the agency it compares against: the EIA for United States rows, Statistics Canada for Canadian rows. The compared series are produced differently from ours, so recent months can differ in either direction.
Coverage rows for Devon Energy are regenerated at every build from the same catalog of sources the data is built from.
Top regions by 2025 operated production best estimate incl. unsplit totals
| Region | Oil (MMbbl) | Gas produced (Bcf) | Share of 2025 output |
|---|---|---|---|
| New Mexico | 86.8 | 420.8 | 40.3% |
| Texas | 58.9 | 273.9 | 27.1% |
| North Dakota | 47.3 | 175 | 20.7% |
| Oklahoma | 9.3 | 208.7 | 8.2% |
| Wyoming | 8.7 | 14.3 | 3.4% |
| Montana | 0.9 | 0.9 | 0.3% |
| Kansas | 0 | 0 | 0.0% |
Share of output counts oil and gas together, gas at its market-value weight.
What the data shows
- Devon Energy produced 211.9 MMbbl of oil and 1.09 Tcf of natural gas in 2025.
- Devon Energy oil production reached its highest level on record in 2025 at 211.9 MMbbl.
- Devon Energy operated production across 19 reporting regions in 3 countries (Brazil, Canada, United States) in our coverage.
- 11,233 operated producing wells tracked, trailing 12 months per region.
Corporate history
- May 2026 Coterra Energy became part of Devon Energy.
- April 2025 Assets moved from Devon Energy to BP.
- January 2025 Franklin Mountain Energy 2, LLC became part of Cimarex Energy.
- January 2025 Franklin Mountain Energy 3, LLC became part of Cimarex Energy.
- January 2025 Franklin Mountain Energy, LLC became part of Cimarex Energy.
- January 2025 Assets moved from Avant Operating, LLC to Coterra Energy.
- 2024 Devon Energy acquired Grayson Mill Energy.
- October 2021 Cabot Oil & Gas continued as Coterra Energy.
- 2021 Coterra Energy acquired Cabot Petroleum Corporation.
- October 2021 Cimarex Energy became part of Coterra Energy.
- January 2021 WPX Energy became part of Devon Energy.
- 2020 WPX Energy acquired Felix Energy Holdings II.
- March 2019 Resolute Energy Corporation became part of Cimarex Energy.
- August 2015 WPX Energy acquired RKI Exploration & Production.
- February 2014 Assets moved from GeoSouthern Energy to Devon Energy.
- 2011 WPX Energy acquired Williams Production RMT Company.
- 2005 Cimarex Energy acquired Magnum Hunter Production, Inc..
- April 2003 Devon Energy acquired Ocean Energy.
- November 2002 Devon SFS Operating merged into Devon Energy.
- September 2002 Cimarex Energy acquired Key Production Company.
- 2002 Devon Energy acquired Mitchell Energy.
- August 2000 Devon SFS Operating became part of Devon Energy.
- August 2000 Santa Fe Snyder Corporation continued as Devon SFS Operating.
- 2000 Devon Energy acquired Devon ARL Corporation.
- 1999 Devon Energy acquired PennzEnergy Exploration and Production.
- May 1999 Santa Fe Energy Resources continued as Santa Fe Snyder Corporation.
- 1999 Snyder Oil Corporation merged into Santa Fe Snyder Corporation.
- March 1999 Seagull Energy E&P became part of Ocean Energy.
- June 1998 BRG Petroleum, Inc. became part of Seagull Energy E&P.
- 1996 Seagull Energy E&P acquired Global Natural Resources Corporation.
- 1992 Adobe Resources Corporation merged into Santa Fe Energy Resources.
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