ExxonMobil
ExxonMobil produced 912.0 MMbbl of oil and 2.18 Tcf of natural gas in 2025. 20,741 operated producing wells tracked, trailing 12 months per region.
- Operated 10.3% of the oil produced in Texas, 2025.
- Oil production rose 19% in 2025 from 2024.
ExxonMobil's figures include production filed by its subsidiaries under their own names.
ExxonMobil's figures include production filed by its subsidiaries under their own names. Under Current operator an old month can show a later company.
Production
- filling in (est. · unconfirmed) . Hatching marks our estimate of the volume still to be filed. That estimate draws on our own production forecast. This estimate is published unconfirmed. It updates as filings arrive
Still arriving: Jun 2026 91% filed, Jul 2026 90% filed, Aug 2026 82% filed, Sep 2026 <1% filed.
All from what the source published. 70.4% held at well grain.
How the volume breaks down
- 62.3% Reported by the official source by well
- 29.6% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 8.0% 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.
- 0.08% Reported by the official source for a longer period, spread across its months. The period total is the reported number.
- under 0.01% Published by the official source as its own estimate rather than an operator-attested figure
Every barrel through April 2026 starts from what the official source published for those months. Measured over January 1946 to April 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.
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.
- filling in (est. · unconfirmed) . Hatching marks our estimate of the volume still to be filed. That estimate draws on our own production forecast. This estimate is published unconfirmed. It updates as filings arrive
Still arriving: Jun 2026 91% filed, Jul 2026 90% filed, Aug 2026 82% filed, Sep 2026 <1% filed.
All from what the source published. 95.9% held at well grain.
How the volume breaks down
- 87.5% Reported by the official source by well
- 4.1% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 7.1% 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.
- 1.3% Reported by the official source for a longer period, spread across its months. The period total is the reported number.
- under 0.01% A series adjusted to match figures the official source published: a well's cumulative, a later correction netted into the months before it, or a field's oil volume from the royalty file for a month missing from the production report.
- under 0.01% Published by the official source as its own estimate rather than an operator-attested figure
Every cubic foot through April 2026 starts from what the official source published for those months. Measured over January 1946 to April 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.
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. In the reported months the bands draw the filings already in. The months still filling in are marked.
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, source-estimated and allocated
| Year | Oil (MMbbl) | Gas produced (Bcf) |
|---|---|---|
| 2025 | 912.0 | 2,184 |
| 2024 | 767.9 | 1,812 |
| 2023 | 544.4 | 1,481 |
| 2022 | 494.2 | 1,586 |
| 2021 | 440.1 | 1,778 |
| 2020 | 410.8 | 1,719 |
| 2019 | 350.2 | 1,683 |
| 2018 | 297.4 | 1,512 |
| 2017 | 265.8 | 1,705 |
| 2016 | 260.0 | 1,677 |
| 2015 | 227.3 | 1,702 |
| 2014 | 194.6 | 1,760 |
| 2013 | 178.9 | 1,792 |
| 2012 | 158.9 | 1,862 |
| 2011 | 165.4 | 1,957 |
| 2010 | 153.8 | 1,369 |
| 2009 | 130.8 | 773 |
| 2008 | 141.0 | 778 |
| 2007 | 147.0 | 884 |
| 2006 | 169.4 | 1,038 |
| 2005 | 183.8 | 1,136 |
| 2004 | 199.0 | 1,238 |
| 2003 | 214.9 | 1,341 |
| 2002 | 217.7 | 1,418 |
| 2001 | 159.5 | 1,441 |
| 2000 | 152.3 | 1,605 |
| 1999 | 108.3 | 925 |
| 1998 | 112.3 | 858 |
| 1997 | 113.6 | 930 |
| 1996 | 107.0 | 919 |
| 1995 | 76.9 | 867 |
| 1994 | 74.2 | 900 |
| 1993 | 72.9 | 794 |
| 1992 | 76.2 | 771 |
| 1991 | 80.1 | 779 |
| 1990 | 83.3 | 769 |
| 1989 | 93.2 | 779 |
| 1988 | 105.6 | 743 |
| 1987 | 109.5 | 715 |
| 1986 | 105.0 | 524 |
| 1985 | 102.9 | 506 |
| 1984 | 104.4 | 543 |
| 1983 | 100.1 | 472 |
| 1982 | 94.9 | 557 |
| 1981 | 100.8 | 616 |
| 1980 | 111.7 | 627 |
| 1979 | 127.2 | 648 |
| 1978 | 105.7 | 598 |
| 1977 | 109.3 | 530 |
| 1976 | 111.6 | 492 |
| 1975 | 127.0 | 460 |
| 1974 | 163.1 | 448 |
| 1973 | 169.0 | 436 |
| 1972 | 145.7 | 378 |
| 1971 | 130.8 | 343 |
| 1970 | 123.7 | 273 |
| 1969 | 114.5 | 242 |
| 1968 | 99.7 | 212 |
| 1967 | 89.6 | 190 |
| 1966 | 79.7 | 172 |
| 1965 | 69.1 | 166 |
| 1964 | 61.1 | 146 |
| 1963 | 59.0 | 113 |
| 1962 | 56.7 | 78 |
| 1961 | 8.9 | 11 |
| 1960 | 6.5 | 9 |
| 1959 | 4.3 | 7 |
| 1958 | 3.4 | 5 |
| 1957 | 1.9 | 3 |
| 1956 | 0.8 | 2 |
| 1955 | 0.2 | 1 |
| 1954 | 0.1 | 1 |
| 1953 | 0.1 | 1 |
| 1952 | 0.1 | 1 |
| 1951 | <0.1 | 1 |
| 1950 | <0.1 | 1 |
| 1949 | 0.1 | 1 |
| 1948 | <0.1 | 1 |
| 1947 | <0.1 | 1 |
| 1946 | <0.1 | 1 |
Source: CommoVision (commovision.com)
Monthly table (last 24 months)
| Month | Oil (Mbbl) | Gas produced (MMcf) |
|---|---|---|
| 2025-12 | 86,320.9 | 195,227 |
| 2025-11 | 82,200.7 | 184,557 |
| 2025-10 | 82,688.9 | 192,795 |
| 2025-09 | 79,492.1 | 184,965 |
| 2025-08 | 78,110.8 | 185,448 |
| 2025-07 | 77,027.7 | 187,380 |
| 2025-06 | 73,755.1 | 176,922 |
| 2025-05 | 73,093.3 | 182,352 |
| 2025-04 | 71,890.7 | 174,977 |
| 2025-03 | 72,822.6 | 178,215 |
| 2025-02 | 62,591.1 | 162,710 |
| 2025-01 | 71,976.9 | 178,190 |
| 2024-12 | 74,228.9 | 182,601 |
| 2024-11 | 72,579.3 | 175,343 |
| 2024-10 | 74,213.1 | 169,032 |
| 2024-09 | 71,756.4 | 172,547 |
| 2024-08 | 71,763.7 | 178,693 |
| 2024-07 | 65,817.2 | 180,286 |
| 2024-06 | 70,877.1 | 174,478 |
| 2024-05 | 52,880.8 | 118,790 |
| 2024-04 | 53,986.5 | 114,723 |
| 2024-03 | 55,084.4 | 118,617 |
| 2024-02 | 52,361.6 | 114,006 |
| 2024-01 | 52,387.6 | 113,180 |
Source: CommoVision (commovision.com)
Source: CommoVision · ExxonMobil, data through May 2026.
Well map
- Oil 50,214
- Natural gas 20,710
- Undetermined 11,765
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
best estimate incl. source-estimated and allocated
Horizontal wells only. Average production per well, for wells grouped by when they first produced.
How these curves are built
Horizontal wells only: 5,724 of the 8,988 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. Wells that are shut in or have stopped producing count as zero, so the average reflects the full cohort, 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 the size of each cohort. 69 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 | 275 | 394 | — | 12.0 | 438 | — | 0.0 | 1 | 100% | 60 |
| 2025 | 567 | 819 | — | 154 | 1,090 | — | 0.2 | 8 | 100% | 60 |
| 2024 | 518 | 845 | 293 | 242 | 1,030 | 746 | 0.5 | 20 | 100% | 60 |
| 2023 | 488 | 857 | 272 | 287 | 993 | 779 | 0.7 | 32 | 100% | 60 |
| 2022 | 472 | 752 | 260 | 290 | 859 | 769 | 0.9 | 44 | 100% | 60 |
| 2021 | 581 | 779 | 264 | 318 | 830 | 730 | 1.0 | 56 | 100% | 60 |
| 2020 | 416 | 747 | 280 | 329 | 796 | 701 | 1.0 | 68 | 100% | 60 |
| 2019 | 493 | 867 | 279 | 368 | 933 | 754 | 1.3 | 80 | 100% | 60 |
| 2018 | 396 | 851 | 268 | 386 | 907 | 670 | 1.3 | 92 | 100% | 60 |
| 2017 | 317 | 694 | 275 | 381 | 811 | 665 | 1.4 | 104 | 100% | 60 |
| 2016 | 311 | 590 | 289 | 375 | 701 | 633 | 1.4 | 116 | 100% | 60 |
| 2015 | 285 | 488 | 177 | 285 | 676 | 403 | 1.0 | 128 | 100% | 60 |
| 2010-2014 | 605 | 288 | 107 | 177 | 627 | 321 | 0.6 | 140 | 100% | 60 |
Source: CommoVision (commovision.com)
Source: CommoVision · ExxonMobil 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 Oct 2026. The last bar is Oct 2026 through October 16, 2026 (47 so far), drawn hatched. Of the 1,147 approved in the 365 days to October 16, 2026, 1,131 are permits to drill a new well, 10 are permits to deepen, sidetrack or re-enter existing wells, 5 are recompletion permits and 1 is another permit type. Permits to drill a new well: 1,131 in the 365 days to October 16, 2026 and 322 in the last 90 days of that window. How permits are counted.
- ExxonMobil was granted 1,147 well permits in the 365 days to October 16, 2026. Of those, 324 came in the last 90 days of that window. The latest approval on record is dated October 16, 2026.
- Of the 1,147 approved in the 365 days to October 16, 2026, 1,131 are permits to drill a new well, 10 are permits to deepen, sidetrack or re-enter existing wells, 5 are recompletion permits and 1 is another permit type. Permits to drill a new well: 1,131 in the 365 days to October 16, 2026 and 322 in the last 90 days of that window.
- Permits counted here come from Alberta, Kansas, Louisiana, North Dakota, New Mexico, Oklahoma, Texas, West Virginia and Wyoming.
- Alabama, Gulf of Mexico, Manitoba, Michigan, Mississippi and Pacific OCS reach this page through production data alone.
Well permits approved per month: full table
| Month | Permits approved |
|---|---|
| Oct 2026 (through October 16, 2026) | 47 |
| Sep 2026 | 85 |
| Aug 2026 | 141 |
| Jul 2026 | 110 |
| Jun 2026 | 141 |
| May 2026 | 57 |
| Apr 2026 | 118 |
| Mar 2026 | 114 |
| Feb 2026 | 85 |
| Jan 2026 | 91 |
| Dec 2025 | 73 |
| Nov 2025 | 45 |
| Oct 2025 | 120 |
| Sep 2025 | 68 |
| Aug 2025 | 35 |
| Jul 2025 | 38 |
| Jun 2025 | 109 |
| May 2025 | 70 |
| Apr 2025 | 164 |
| Mar 2025 | 120 |
| Feb 2025 | 114 |
| Jan 2025 | 80 |
| Dec 2024 | 88 |
| Nov 2024 | 44 |
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 | — |
| Alaska production | well | 1919-12 | ~100–101% of EIA |
| Alabama production | well | 1944-04 | ~100–104% of EIA |
| 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 | ~99–100% of EIA |
| Louisiana production | well | 1977-01 | ~97–98% of EIA |
| Manitoba production | well | 1951-02 | — |
| Michigan production | well | 1980-08 | ~100% of EIA |
| 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 | ~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 |
| Pacific OCS production | well | 1996-01 | ~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 |
| Guyana production | country + facility | 2019-12 | — |
| Newfoundland & Labrador Offshore production | field | 2002-01 | — |
Benchmark cells compare our series with the EIA’s published estimates.
About the EIA comparison
The two are produced differently: the EIA estimates from a survey of the largest operators and a model built to anticipate late filings, while the series compared here are rebuilt from the source’s own records as they arrive. Recent months can differ without either being wrong; the methodology page explains both methods.
Coverage rows for ExxonMobil 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 |
|---|---|---|---|
| Texas | 284.6 | 1145 | 34.1% |
| Guyana | 261.1 | — | 24.7% |
| Alberta | 165.8 | 13.8 | 15.8% |
| New Mexico | 82.5 | 394.1 | 10.3% |
| Newfoundland & Labrador Offshore | 76.1 | 135 | 8.0% |
| North Dakota | 20.2 | 67.9 | 2.3% |
| Wyoming | 2.1 | 257.3 | 1.8% |
| Gulf of Mexico | 8.6 | 1 | 0.8% |
| Oklahoma | 3.7 | 68 | 0.8% |
| Pennsylvania | 0 | 64 | 0.4% |
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
- ExxonMobil produced 912.0 MMbbl of oil and 2.18 Tcf of natural gas in 2025.
- ExxonMobil oil production reached its highest level on record in 2025 at 912.0 MMbbl.
- ExxonMobil operated production across 26 reporting regions in 3 countries (Canada, Guyana, United States) in our coverage.
- 20,741 operated producing wells tracked, trailing 12 months per region.
Corporate history
- July 2024 Assets moved from XTO Energy to MMGL East Texas II, LLC.
- May 2024 ExxonMobil acquired Pioneer Natural Resources.
- November 2023 ExxonMobil acquired Denbury Inc..
- June 2011 XTO Energy acquired Phillips Exploration Inc.
- 2010 Ellora Operating became part of ExxonMobil.
- June 2010 XTO Energy became part of ExxonMobil.
- 2001 XTO Energy acquired Cross Timbers Operating Company.
- November 1999 Exxon Corporation merged into ExxonMobil.
- November 1999 ExxonMobil acquired Mobil.
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