EOG Resources
EOG Resources produced 254.3 MMbbl of oil and 1.53 Tcf of natural gas in 2025. 12,317 operated producing wells tracked, trailing 12 months per region.
- Largest operator by operated oil in New Mexico, 2025.
- Operated 15.9% of the oil produced in New Mexico, 2025.
- Oil production rose 4% in 2025 from 2024.
Under Current operator an old month can show a later company.
Production
Still arriving: Oct 2026 <1% filed.
All from what the source published. 99.98% held at well grain.
How the volume breaks down
- 70.4% Reported by the official source by well
- 0.02% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 27.0% 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.
- 0.98% Reported by the official source for a longer period, spread across its months. The period total is the reported number.
- 1.6% 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 barrel here starts from what the official source published for the months measured. Measured over January 1940 to February 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. 99.93% held at well grain.
How the volume breaks down
- 87.1% Reported by the official source by well
- 0.07% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 8.6% 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.
- 2.0% Reported by the official source for a longer period, spread across its months. The period total is the reported number.
- 2.4% 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 1940 to February 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, allocated and adjusted
| Year | Oil (MMbbl) | Gas produced (Bcf) |
|---|---|---|
| 2025 | 254.3 | 1,526 |
| 2024 | 244.2 | 1,185 |
| 2023 | 235.7 | 1,075 |
| 2022 | 224.6 | 905 |
| 2021 | 217.4 | 800 |
| 2020 | 204.3 | 716 |
| 2019 | 230.1 | 751 |
| 2018 | 198.6 | 633 |
| 2017 | 165.5 | 524 |
| 2016 | 144.3 | 584 |
| 2015 | 150.5 | 652 |
| 2014 | 149.7 | 696 |
| 2013 | 111.0 | 676 |
| 2012 | 78.7 | 750 |
| 2011 | 53.9 | 779 |
| 2010 | 35.5 | 748 |
| 2009 | 28.4 | 726 |
| 2008 | 23.5 | 707 |
| 2007 | 14.8 | 594 |
| 2006 | 13.6 | 534 |
| 2005 | 13.6 | 495 |
| 2004 | 13.8 | 451 |
| 2003 | 12.1 | 425 |
| 2002 | 11.6 | 406 |
| 2001 | 13.7 | 427 |
| 2000 | 14.6 | 403 |
| 1999 | 10.5 | 369 |
| 1998 | 10.4 | 397 |
| 1997 | 12.1 | 404 |
| 1996 | 12.6 | 376 |
| 1995 | 11.7 | 324 |
| 1994 | 9.0 | 357 |
| 1993 | 10.4 | 382 |
| 1992 | 6.0 | 181 |
| 1991 | 4.5 | 156 |
| 1990 | 6.7 | 94 |
| 1989 | 6.4 | 64 |
| 1988 | 3.4 | 80 |
| 1987 | 3.1 | 59 |
| 1986 | 2.7 | 40 |
| 1985 | 3.4 | 49 |
| 1984 | 5.6 | 52 |
| 1983 | 3.7 | 36 |
| 1982 | 2.3 | 29 |
| 1981 | 2.4 | 24 |
| 1980 | 2.4 | 21 |
| 1979 | 2.2 | 19 |
| 1978 | 2.3 | 17 |
| 1977 | 1.8 | 14 |
| 1976 | 1.8 | 9 |
| 1975 | 1.4 | 7 |
| 1974 | 1.4 | 4 |
| 1973 | 1.0 | 2 |
| 1972 | 1.0 | 1 |
| 1971 | 1.1 | 1 |
| 1970 | 1.0 | 1 |
| 1969 | 1.0 | 1 |
| 1968 | 1.0 | 1 |
| 1967 | 1.0 | 1 |
| 1966 | 0.9 | <1 |
| 1965 | 0.8 | <1 |
| 1964 | 0.7 | <1 |
| 1963 | 0.7 | <1 |
| 1962 | 0.8 | <1 |
| 1961 | 0.7 | <1 |
| 1960 | 0.7 | <1 |
| 1959 | 0.2 | <1 |
| 1958 | 0.2 | <1 |
| 1957 | 0.2 | <1 |
| 1956 | 0.2 | <1 |
| 1955 | 0.2 | <1 |
| 1954 | 0.2 | <1 |
| 1953 | 0.2 | <1 |
| 1952 | 0.2 | <1 |
| 1951 | 0.2 | <1 |
| 1950 | 0.2 | <1 |
| 1949 | 0.2 | <1 |
| 1948 | 0.2 | <1 |
| 1947 | 0.2 | <1 |
| 1946 | 0.2 | <1 |
| 1945 | 0.2 | <1 |
| 1944 | 0.1 | <1 |
| 1943 | 0.1 | <1 |
| 1942 | 0.1 | <1 |
| 1941 | 0.1 | <1 |
| 1940 | 0.1 | <1 |
Source: CommoVision (commovision.com)
Monthly table (last 24 months)
| Month | Oil (Mbbl) | Gas produced (MMcf) |
|---|---|---|
| 2025-12 | 22,081.4 | 155,746 |
| 2025-11 | 21,800.1 | 157,330 |
| 2025-10 | 21,919.9 | 152,851 |
| 2025-09 | 21,684.8 | 148,868 |
| 2025-08 | 23,391.8 | 153,098 |
| 2025-07 | 20,605.8 | 118,357 |
| 2025-06 | 20,167.5 | 109,959 |
| 2025-05 | 21,007.4 | 115,746 |
| 2025-04 | 20,353.6 | 106,582 |
| 2025-03 | 21,103.1 | 108,026 |
| 2025-02 | 19,291.4 | 96,296 |
| 2025-01 | 20,854.1 | 102,757 |
| 2024-12 | 20,496.7 | 107,045 |
| 2024-11 | 19,854.0 | 99,335 |
| 2024-10 | 21,021.7 | 103,074 |
| 2024-09 | 19,721.1 | 96,260 |
| 2024-08 | 21,451.4 | 103,631 |
| 2024-07 | 20,401.5 | 102,247 |
| 2024-06 | 20,091.0 | 90,504 |
| 2024-05 | 20,437.8 | 102,929 |
| 2024-04 | 20,021.2 | 93,065 |
| 2024-03 | 20,563.1 | 94,654 |
| 2024-02 | 19,693.7 | 95,776 |
| 2024-01 | 20,424.6 | 96,402 |
Source: CommoVision (commovision.com)
Source: CommoVision · EOG Resources, data through February 2026.
Well map
- Oil 15,796
- Natural gas 10,036
- Undetermined 903
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
5 of the drawn cohorts’ wells are not in these curves yet: each is still producing and joins its curve once it carries a forecast.
5 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. allocated and adjusted
Horizontal wells only. Average production per well, for wells grouped by when they first produced.
How these curves are built
Horizontal wells only: 12,226 of the 12,750 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. 6 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 | 478 | 654 | — | 19.9 | 1,741 | — | 0.1 | 1 | 100% | 60 |
| 2025 | 755 | 1,003 | — | 125 | 4,091 | — | 0.7 | 7 | 100% | 60 |
| 2024 | 763 | 1,007 | 195 | 190 | 3,609 | 1,442 | 1.1 | 19 | 100% | 60 |
| 2023 | 808 | 973 | 185 | 221 | 3,576 | 1,171 | 1.2 | 31 | 100% | 60 |
| 2022 | 703 | 1,051 | 207 | 268 | 4,279 | 1,390 | 1.7 | 42 | 100% | 60 |
| 2021 | 603 | 1,078 | 223 | 303 | 4,128 | 1,254 | 1.7 | 55 | 100% | 60 |
| 2020 | 602 | 844 | 214 | 292 | 3,176 | 1,009 | 1.5 | 67 | 100% | 60 |
| 2019 | 870 | 957 | 198 | 302 | 2,629 | 830 | 1.3 | 79 | 100% | 60 |
| 2018 | 866 | 863 | 180 | 286 | 1,989 | 749 | 1.1 | 89 | 100% | 60 |
| 2017 | 659 | 862 | 189 | 293 | 2,303 | 823 | 1.2 | 98 | 100% | 60 |
| 2016 | 484 | 775 | 174 | 279 | 1,721 | 665 | 1.1 | 111 | 100% | 60 |
| 2015 | 759 | 520 | 140 | 223 | 1,353 | 705 | 1.1 | 121 | 100% | 60 |
| 2010-2014 | 3,871 | 393 | 106 | 168 | 789 | 461 | 0.8 | 136 | 100% | 60 |
Source: CommoVision (commovision.com)
Source: CommoVision · EOG Resources 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 12, 2026 (33 so far), drawn hatched. Of the 880 approved in the 365 days to November 12, 2026, 837 are permits to drill a new well, 32 are other permit types, 8 are permits to deepen, sidetrack or re-enter existing wells, 2 are recompletion permits and 1 is a permit to plug a well. Permits to drill a new well: 837 in the 365 days to November 12, 2026 and 197 in the last 90 days of that window. How permits are counted.
- EOG Resources was granted 880 well permits in the 365 days to November 12, 2026. Of those, 216 came in the last 90 days of that window. The latest approval on record is dated November 12, 2026.
- Of the 880 approved in the 365 days to November 12, 2026, 837 are permits to drill a new well, 32 are other permit types, 8 are permits to deepen, sidetrack or re-enter existing wells, 2 are recompletion permits and 1 is a permit to plug a well. Permits to drill a new well: 837 in the 365 days to November 12, 2026 and 197 in the last 90 days of that window.
- Permits counted here come from North Dakota, New Mexico, Ohio, Texas and Wyoming.
- 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 12, 2026) | 33 |
| Oct 2026 | 72 |
| Sep 2026 | 57 |
| Aug 2026 | 151 |
| Jul 2026 | 80 |
| Jun 2026 | 157 |
| May 2026 | 82 |
| Apr 2026 | 55 |
| Mar 2026 | 40 |
| Feb 2026 | 61 |
| Jan 2026 | 16 |
| Dec 2025 | 53 |
| Nov 2025 | 61 |
| Oct 2025 | 86 |
| Sep 2025 | 106 |
| Aug 2025 | 44 |
| Jul 2025 | 114 |
| Jun 2025 | 44 |
| May 2025 | 85 |
| Apr 2025 | 59 |
| Mar 2025 | 64 |
| Feb 2025 | 63 |
| Jan 2025 | 74 |
| Dec 2024 | 121 |
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 |
| British Columbia production | well | 1954-06 | — |
| California production | well | 1944-03 | ~98–101% of EIA |
| 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 EOG Resources 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 and allocated
| Region | Oil (MMbbl) | Gas produced (Bcf) | Share of 2025 output |
|---|---|---|---|
| New Mexico | 127.8 | 619.6 | 47.5% |
| Texas | 87.1 | 592.3 | 35.6% |
| Ohio | 16.3 | 204.2 | 8.4% |
| Wyoming | 13 | 81.3 | 5.2% |
| North Dakota | 9 | 19.9 | 2.9% |
| Oklahoma | 1.2 | 8.3 | 0.5% |
| Kansas | 0 | 0 | 0.0% |
| Alberta | — | — | 0.0% |
Share of output counts oil and gas together, gas at its market-value weight.
— means no figure is published for that period.
What the data shows
- EOG Resources produced 254.3 MMbbl of oil and 1.53 Tcf of natural gas in 2025.
- EOG Resources oil production reached its highest level on record in 2025 at 254.3 MMbbl.
- EOG Resources operated production across 20 reporting regions in 2 countries (Canada, United States) in our coverage.
- 12,317 operated producing wells tracked, trailing 12 months per region.
Corporate history
- August 2025 EOG Resources acquired Encino Acquisition Partners.
- 2016 EOG Resources acquired Yates Petroleum Corporation.
- August 1999 Enron Oil & Gas Company continued as EOG Resources.
- 1987 HNG Oil Company merged into Enron Oil & Gas Company.
Start a free trial
Watch supply move as soon as its sources publish, with forecasts on 1.1+ million producing wells. A real API and MCP access for AI tools are live, and the Portal is open.
Data use is subject to our Terms of Service.