Occidental Petroleum
Occidental Petroleum produced 350.6 MMbbl of oil and 1.30 Tcf of natural gas in 2025. 24,550 operated producing wells tracked, trailing 12 months per region.
- Operated 4.8% of the oil produced in Texas, 2025.
- Oil production rose 7% in 2025 from 2024.
Occidental Petroleum's figures include production filed by its subsidiaries under their own names.
Occidental Petroleum'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. 99.72% held at well grain.
How the volume breaks down
- 65.3% Reported by the official source by well
- 0.28% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 33.9% 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.
- 0.03% Reported by the official source for a longer period, spread across its months. The period total is the reported number.
- 0.50% 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.
- 0.03% Published by the official source as its own estimate rather than an operator-attested figure
Every barrel here starts from what the official source published for the months measured. Measured over January 1938 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. 99.61% held at well grain.
How the volume breaks down
- 81.3% Reported by the official source by well
- 0.39% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 17.1% 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.
- 0.10% Reported by the official source for a longer period, spread across its months. The period total is the reported number.
- 0.96% 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.
- 0.07% Published by the official source as its own estimate rather than an operator-attested figure
Every cubic foot here starts from what the official source published for the months measured. Measured over January 1938 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, allocated, adjusted and source-estimated
| Year | Oil (MMbbl) | Gas produced (Bcf) |
|---|---|---|
| 2025 | 350.6 | 1,296 |
| 2024 | 328.2 | 1,135 |
| 2023 | 291.3 | 931 |
| 2022 | 264.5 | 842 |
| 2021 | 260.9 | 842 |
| 2020 | 283.9 | 978 |
| 2019 | 186.2 | 564 |
| 2018 | 112.9 | 259 |
| 2017 | 89.1 | 236 |
| 2016 | 86.8 | 263 |
| 2015 | 90.9 | 285 |
| 2014 | 120.6 | 441 |
| 2013 | 118.0 | 463 |
| 2012 | 114.6 | 476 |
| 2011 | 109.3 | 456 |
| 2010 | 117.9 | 411 |
| 2009 | 120.1 | 398 |
| 2008 | 122.6 | 394 |
| 2007 | 120.8 | 410 |
| 2006 | 117.2 | 430 |
| 2005 | 100.8 | 337 |
| 2004 | 100.7 | 470 |
| 2003 | 100.1 | 452 |
| 2002 | 102.2 | 441 |
| 2001 | 102.1 | 446 |
| 2000 | 79.9 | 420 |
| 1999 | 35.4 | 358 |
| 1998 | 39.0 | 345 |
| 1997 | 43.2 | 365 |
| 1996 | 40.3 | 356 |
| 1995 | 39.7 | 348 |
| 1994 | 41.7 | 367 |
| 1993 | 41.3 | 368 |
| 1992 | 34.4 | 347 |
| 1991 | 37.5 | 353 |
| 1990 | 38.2 | 353 |
| 1989 | 43.1 | 385 |
| 1988 | 47.7 | 364 |
| 1987 | 50.4 | 325 |
| 1986 | 49.0 | 214 |
| 1985 | 56.5 | 189 |
| 1984 | 59.7 | 199 |
| 1983 | 66.3 | 183 |
| 1982 | 71.2 | 194 |
| 1981 | 71.7 | 168 |
| 1980 | 60.7 | 138 |
| 1979 | 63.0 | 132 |
| 1978 | 54.6 | 111 |
| 1977 | 47.9 | 106 |
| 1976 | 2.5 | 61 |
| 1975 | 2.2 | 54 |
| 1974 | 2.3 | 50 |
| 1973 | 2.0 | 44 |
| 1972 | 1.0 | 19 |
| 1971 | 0.8 | 5 |
| 1970 | 0.9 | 4 |
| 1969 | 0.9 | 4 |
| 1968 | 1.0 | 5 |
| 1967 | 1.0 | 4 |
| 1966 | 1.0 | 2 |
| 1965 | 1.0 | 2 |
| 1964 | 1.0 | 2 |
| 1963 | 1.0 | 2 |
| 1962 | 1.0 | 2 |
| 1961 | 1.1 | 2 |
| 1960 | 0.9 | 2 |
| 1959 | 0.3 | 2 |
| 1958 | 0.2 | 2 |
| 1957 | 0.2 | 1 |
| 1956 | 0.1 | 1 |
| 1955 | 0.1 | 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 |
| 1945 | <0.1 | 1 |
| 1944 | <0.1 | 1 |
| 1943 | <0.1 | 1 |
| 1942 | <0.1 | 1 |
| 1941 | <0.1 | 1 |
| 1940 | <0.1 | 1 |
| 1939 | <0.1 | 1 |
| 1938 | <0.1 | 1 |
Source: CommoVision (commovision.com)
Monthly table (last 24 months)
| Month | Oil (Mbbl) | Gas produced (MMcf) |
|---|---|---|
| 2025-12 | 30,231.1 | 114,009 |
| 2025-11 | 29,866.3 | 109,260 |
| 2025-10 | 30,716.8 | 111,103 |
| 2025-09 | 28,732.0 | 106,950 |
| 2025-08 | 30,559.8 | 111,597 |
| 2025-07 | 30,329.8 | 110,862 |
| 2025-06 | 28,943.6 | 105,853 |
| 2025-05 | 29,692.1 | 109,563 |
| 2025-04 | 28,252.8 | 106,613 |
| 2025-03 | 28,849.2 | 107,957 |
| 2025-02 | 25,827.9 | 97,046 |
| 2025-01 | 28,618.2 | 105,231 |
| 2024-12 | 30,541.9 | 112,201 |
| 2024-11 | 29,086.8 | 106,163 |
| 2024-10 | 30,678.5 | 112,085 |
| 2024-09 | 29,071.2 | 105,320 |
| 2024-08 | 31,573.5 | 109,665 |
| 2024-07 | 27,433.8 | 91,274 |
| 2024-06 | 27,327.7 | 88,675 |
| 2024-05 | 26,890.5 | 88,960 |
| 2024-04 | 24,392.8 | 82,164 |
| 2024-03 | 24,308.1 | 83,405 |
| 2024-02 | 22,822.8 | 75,722 |
| 2024-01 | 24,098.9 | 79,688 |
Source: CommoVision (commovision.com)
Source: CommoVision · Occidental Petroleum, data through June 2026.
Well map
- Oil 38,474
- Natural gas 14,398
- Undetermined 8,481
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. allocated, adjusted and source-estimated
Horizontal wells only. Average production per well, for wells grouped by when they first produced.
How these curves are built
Horizontal wells only: 2,835 of the 6,136 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. 87 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 | 190 | 432 | — | 13.2 | 747 | — | 0.0 | 1 | 100% | 60 |
| 2025 | 334 | 935 | — | 140 | 1,783 | — | 0.4 | 9 | 100% | 60 |
| 2024 | 337 | 990 | 236 | 222 | 1,775 | 820 | 0.6 | 21 | 100% | 60 |
| 2023 | 314 | 972 | 223 | 256 | 1,878 | 900 | 0.9 | 33 | 100% | 60 |
| 2022 | 332 | 1,057 | 212 | 273 | 1,826 | 837 | 1.0 | 45 | 100% | 60 |
| 2021 | 275 | 956 | 194 | 265 | 1,283 | 713 | 1.0 | 57 | 100% | 60 |
| 2020 | 136 | 1,046 | 224 | 332 | 1,729 | 871 | 1.3 | 69 | 100% | 60 |
| 2019 | 241 | 1,186 | 273 | 400 | 2,056 | 970 | 1.5 | 81 | 100% | 60 |
| 2018 | 212 | 947 | 287 | 410 | 1,317 | 860 | 1.3 | 93 | 100% | 60 |
| 2017 | 129 | 742 | 241 | 327 | 907 | 602 | 1.2 | 105 | 100% | 60 |
| 2016 | 61 | 681 | 221 | 341 | 830 | 556 | 1.1 | 117 | 100% | 60 |
| 2015 | 111 | 320 | 176 | 246 | 304 | 238 | 0.6 | 129 | 100% | 60 |
| 2010-2014 | 163 | 156 | 78.2 | 138 | 187 | 135 | 0.4 | 141 | 100% | 60 |
Source: CommoVision (commovision.com)
Source: CommoVision · Occidental Petroleum 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 30, 2026 (47 so far), drawn hatched. Of the 861 approved in the 365 days to October 30, 2026, 664 are permits to drill a new well, 194 are recompletion permits and 3 are other permit types. Permits to drill a new well: 664 in the 365 days to October 30, 2026 and 97 in the last 90 days of that window. How permits are counted.
- Occidental Petroleum was granted 861 well permits in the 365 days to October 30, 2026. Of those, 157 came in the last 90 days of that window. The latest approval on record is dated October 30, 2026.
- Of the 861 approved in the 365 days to October 30, 2026, 664 are permits to drill a new well, 194 are recompletion permits and 3 are other permit types. Permits to drill a new well: 664 in the 365 days to October 30, 2026 and 97 in the last 90 days of that window.
- Permits counted here come from Colorado, New Mexico, Texas and Wyoming.
- Alabama, Argentina, Gulf of Mexico and Mississippi reach this page through production data alone.
Well permits approved per month: full table
| Month | Permits approved |
|---|---|
| Oct 2026 (through October 30, 2026) | 47 |
| Sep 2026 | 60 |
| Aug 2026 | 50 |
| Jul 2026 | 93 |
| Jun 2026 | 81 |
| May 2026 | 81 |
| Apr 2026 | 99 |
| Mar 2026 | 77 |
| Feb 2026 | 69 |
| Jan 2026 | 128 |
| Dec 2025 | 46 |
| Nov 2025 | 26 |
| Oct 2025 | 71 |
| Sep 2025 | 138 |
| Aug 2025 | 88 |
| Jul 2025 | 77 |
| Jun 2025 | 99 |
| May 2025 | 93 |
| Apr 2025 | 102 |
| Mar 2025 | 79 |
| Feb 2025 | 130 |
| Jan 2025 | 113 |
| Dec 2024 | 109 |
| Nov 2024 | 58 |
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 |
|---|---|---|---|
| Alabama production | lease + well | 1944-04 | ~99–101% of EIA |
| Argentina production | well | 2006-01 | — |
| 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 |
| Mississippi production | well | 1946-07 | ~100–102% of EIA |
| North Dakota production | well | 1951-04 | ~99–100% of EIA |
| New Mexico production | well | 1924-01 | ~98–100% of EIA |
| Oklahoma production | lease + well | 1990-07 | ~99–100% 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 |
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 official records as they arrive. Recent months can differ without either being wrong; the methodology page explains both methods.
Coverage rows for Occidental Petroleum are regenerated at every build from the same catalog of sources the data is built from.
Top regions by 2025 operated production
| Region | Oil (MMbbl) | Gas produced (Bcf) | Share of 2025 output |
|---|---|---|---|
| Texas | 192.6 | 686.1 | 54.5% |
| Gulf of Mexico | 66.5 | 58.5 | 16.1% |
| New Mexico | 52.3 | 219.4 | 15.3% |
| Colorado | 33.8 | 317.6 | 12.6% |
| Wyoming | 5.4 | 14.3 | 1.5% |
| Kansas | 0 | 0.1 | 0.0% |
| Oklahoma | — | 0 | 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
- Occidental Petroleum produced 350.6 MMbbl of oil and 1.30 Tcf of natural gas in 2025.
- Occidental Petroleum oil production reached its highest level on record in 2025 at 350.6 MMbbl.
- Occidental Petroleum operated production across 15 reporting regions in 2 countries (Argentina, United States) in our coverage.
- 24,550 operated producing wells tracked, trailing 12 months per region.
Corporate history
- November 2024 Assets moved from Occidental Petroleum to Permian Resources.
- August 2019 Anadarko Petroleum became part of Occidental Petroleum.
- November 2014 Assets moved from Occidental Petroleum to California Resources Corporation.
- November 2014 Assets moved from Occidental Petroleum to California Resources Long Beach, Inc..
- March 2011 Occidental Argentina Exploration and Production continued as Sinopec Argentina Exploration and Production.
- February 2011 Sinopec Argentina Exploration and Production acquired Occidental Argentina Exploration and Production.
- November 2007 Anadarko Austin Chalk Company merged into Anadarko Petroleum.
- August 2006 Anadarko Petroleum acquired Western Gas Resources Inc.
- August 2006 Kerr-McGee Corporation became part of Anadarko Petroleum.
- January 2006 Tidelands Oil Production Company became part of Occidental Petroleum.
- 2006 Occidental Petroleum acquired Vintage Petroleum.
- 2004 Kerr-McGee Corporation acquired Westport Oil and Gas Company.
- 2004 Kerr-McGee Corporation acquired Westport Resources Corporation.
- 2001 Kerr-McGee Corporation acquired HS Resources, Inc..
- July 2000 Anadarko Canada Corporation became part of Anadarko Petroleum.
- 2000 Anadarko Petroleum acquired RME Petroleum Company.
- July 2000 Anadarko Petroleum acquired Union Pacific Resources.
- April 2000 California Resources Long Beach, Inc. became part of Occidental Petroleum.
- April 2000 THUMS Long Beach Company became part of Occidental Petroleum.
- 2000 Occidental Petroleum acquired Altura Energy.
- 1999 Kerr-McGee Corporation acquired Oryx Energy Company.
- 1994 Occidental Petroleum acquired Placid Oil Company.
- 1982 Occidental Petroleum acquired Cities Service Oil and Gas Corporation.
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