Noble Energy Part of Chevron since October 2020
Noble Energy produced 40.7 MMbbl of oil and 288.2 Bcf of natural gas in 2025. 2,454 operated producing wells tracked, trailing 12 months per region.
- Third-largest operator by operated oil in Colorado, 2025.
- Operated 17.9% of the oil produced in Colorado, 2025.
- Oil production rose 3% in 2025 from 2024.
Its production also counts in Chevron's figures.
Its production also counts in Chevron's figures. Under Current operator an old month can show a later company.
Production
Still arriving: Sep 2026 <1% filed.
All from what the source published. 99.35% held at well grain.
How the volume breaks down
- 86.6% Reported by the official source by well
- 0.65% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 12.8% 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.
- 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.
Every barrel here starts from what the official source published for the months measured. Measured over January 1987 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.
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: Sep 2026 <1% filed.
All from what the source published. 99.80% held at well grain.
How the volume breaks down
- 93.8% Reported by the official source by well
- 0.20% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 5.5% 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.
- 0.46% Reported by the official source for a longer period, spread across its months. The period total is the reported number.
- 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.
Every cubic foot here starts from what the official source published for the months measured. Measured over January 1987 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.
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 | 40.7 | 288 |
| 2024 | 39.6 | 283 |
| 2023 | 39.0 | 256 |
| 2022 | 35.2 | 245 |
| 2021 | 41.0 | 259 |
| 2020 | 49.6 | 281 |
| 2019 | 54.7 | 305 |
| 2018 | 56.9 | 288 |
| 2017 | 57.0 | 316 |
| 2016 | 54.3 | 323 |
| 2015 | 40.0 | 237 |
| 2014 | 34.7 | 176 |
| 2013 | 31.2 | 167 |
| 2012 | 23.7 | 177 |
| 2011 | 15.3 | 186 |
| 2010 | 14.3 | 201 |
| 2009 | 13.1 | 189 |
| 2008 | 13.9 | 190 |
| 2007 | 15.2 | 173 |
| 2006 | 17.2 | 200 |
| 2005 | 8.4 | 156 |
| 2004 | 7.2 | 116 |
| 2003 | 6.7 | 118 |
| 2002 | <0.1 | 2 |
| 2001 | <0.1 | 3 |
| 2000 | 0.1 | 3 |
| 1999 | 0.2 | 6 |
| 1998 | 0.1 | 6 |
| 1997 | 0.4 | 9 |
| 1996 | 0.5 | 8 |
| 1995 | 0.5 | 7 |
| 1994 | 0.6 | 6 |
| 1993 | 0.7 | 4 |
| 1992 | 0.7 | 4 |
| 1991 | 0.7 | 4 |
| 1990 | 0.4 | 5 |
| 1989 | <0.1 | 2 |
| 1988 | <0.1 | 3 |
| 1987 | <0.1 | 2 |
Source: CommoVision (commovision.com)
Monthly table (last 24 months)
| Month | Oil (Mbbl) | Gas produced (MMcf) |
|---|---|---|
| 2025-12 | 3,390.5 | 25,598 |
| 2025-11 | 3,295.2 | 23,848 |
| 2025-10 | 3,397.6 | 24,031 |
| 2025-09 | 3,306.3 | 23,562 |
| 2025-08 | 3,303.8 | 24,476 |
| 2025-07 | 3,421.4 | 24,843 |
| 2025-06 | 3,522.4 | 23,937 |
| 2025-05 | 3,827.6 | 24,893 |
| 2025-04 | 3,440.6 | 23,869 |
| 2025-03 | 3,574.8 | 24,482 |
| 2025-02 | 3,036.5 | 21,668 |
| 2025-01 | 3,181.9 | 23,006 |
| 2024-12 | 3,208.2 | 24,073 |
| 2024-11 | 3,192.2 | 23,768 |
| 2024-10 | 3,438.3 | 24,077 |
| 2024-09 | 3,358.6 | 22,880 |
| 2024-08 | 3,317.3 | 23,679 |
| 2024-07 | 3,189.7 | 23,949 |
| 2024-06 | 3,179.1 | 23,216 |
| 2024-05 | 3,251.2 | 24,132 |
| 2024-04 | 3,194.0 | 23,601 |
| 2024-03 | 3,519.2 | 25,109 |
| 2024-02 | 3,390.8 | 22,764 |
| 2024-01 | 3,365.6 | 21,762 |
Source: CommoVision (commovision.com)
Source: CommoVision · Noble Energy, data through June 2026.
Well map
- Oil 5,638
- Natural gas 6,848
- Undetermined 1,306
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. adjusted
Horizontal wells only. Average production per well, for wells grouped by when they first produced.
How these curves are built
Horizontal wells only: 2,687 of the 3,809 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. 122 wells are counted here but not shown on the age axis: they started producing in 2001 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 | 76 | 435 | — | 17.7 | 936 | — | 0.0 | 2 | 100% | 60 |
| 2025 | 109 | 667 | — | 117 | 1,869 | — | 0.4 | 8 | 100% | 60 |
| 2024 | 112 | 601 | 189 | 161 | 2,388 | 1,504 | 1.0 | 20 | 100% | 60 |
| 2023 | 127 | 678 | 245 | 250 | 2,087 | 1,484 | 1.2 | 33 | 100% | 60 |
| 2022 | 73 | 651 | 227 | 254 | 2,692 | 1,963 | 1.9 | 44 | 100% | 60 |
| 2021 | 80 | 654 | 223 | 279 | 2,084 | 1,387 | 1.5 | 56 | 100% | 60 |
| 2020 | 94 | 743 | 267 | 350 | 1,744 | 1,180 | 1.6 | 68 | 100% | 60 |
| 2019 | 212 | 584 | 225 | 294 | 1,992 | 1,219 | 1.6 | 80 | 100% | 60 |
| 2018 | 181 | 584 | 253 | 309 | 1,452 | 1,140 | 1.5 | 92 | 100% | 60 |
| 2017 | 183 | 606 | 208 | 278 | 3,428 | 1,856 | 2.6 | 104 | 100% | 60 |
| 2016 | 159 | 498 | 151 | 229 | 1,946 | 777 | 1.3 | 116 | 100% | 60 |
| 2015 | 209 | 412 | 100 | 165 | 1,223 | 552 | 0.9 | 128 | 100% | 60 |
| 2010-2014 | 1,072 | 257 | 67.9 | 111 | 1,231 | 539 | 0.9 | 140 | 100% | 60 |
Source: CommoVision (commovision.com)
Source: CommoVision · Noble 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 Oct 2026. The last bar is Oct 2026 through October 20, 2026 (28 so far), drawn hatched. All 79 approved in the 365 days to October 20, 2026 are permits to drill a new well. Permits to drill a new well: 79 in the 365 days to October 20, 2026 and 28 in the last 90 days of that window. How permits are counted.
- Noble Energy was granted 79 well permits in the 365 days to October 20, 2026. Of those, 28 came in the last 90 days of that window. The latest approval on record is dated October 20, 2026.
- All 79 approved in the 365 days to October 20, 2026 are permits to drill a new well. Permits to drill a new well: 79 in the 365 days to October 20, 2026 and 28 in the last 90 days of that window.
- Permits counted here come from Colorado and Texas.
- Gulf of Mexico reaches this page through production data alone.
Well permits approved per month: full table
| Month | Permits approved |
|---|---|
| Oct 2026 (through October 20, 2026) | 28 |
| Sep 2026 | 0 |
| Aug 2026 | 0 |
| Jul 2026 | 16 |
| Jun 2026 | 0 |
| May 2026 | 0 |
| Apr 2026 | 0 |
| Mar 2026 | 0 |
| Feb 2026 | 0 |
| Jan 2026 | 0 |
| Dec 2025 | 5 |
| Nov 2025 | 18 |
| Oct 2025 | 12 |
| Sep 2025 | 31 |
| Aug 2025 | 18 |
| Jul 2025 | 2 |
| Jun 2025 | 42 |
| May 2025 | 12 |
| Apr 2025 | 0 |
| Mar 2025 | 2 |
| Feb 2025 | 0 |
| Jan 2025 | 2 |
| Dec 2024 | 19 |
| Nov 2024 | 0 |
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 |
|---|---|---|---|
| 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 |
| 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 |
| 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 |
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 Noble Energy are regenerated at every build from the same catalog of sources the data is built from.
What the data shows
- Noble Energy produced 40.7 MMbbl of oil and 288.2 Bcf of natural gas in 2025.
- Noble Energy oil production peaked in 2017 at 57.0 MMbbl; 2025 output of 40.7 MMbbl ran at 71% of that peak.
- Noble Energy operated production across 14 reporting regions in 1 country (United States) in our coverage.
- 2,454 operated producing wells tracked, trailing 12 months per region.
Corporate history
- October 2020 Noble Energy became part of Chevron.
- 2017 Noble Energy acquired Clayton Williams Energy.
- July 2015 Noble Energy acquired Rosetta Resources.
- 2005 Rosetta Resources acquired Calpine Natural Gas.
- 2005 Noble Energy acquired Patina Oil & Gas Corporation.
- 2002 Noble Energy acquired Samedan Oil Corporation.
- December 2002 Patina Oil & Gas Corporation acquired Bravo Natural Resources, Inc.
- November 2002 Patina Oil & Gas Corporation acquired Lenorman Energy Corporation.
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