Mid-Continent
The Mid-Continent footprint produced 47.2 MMbbl of oil and 948.4 Bcf of natural gas in 2025. 124,570 producing wells tracked, trailing 12 months per region.
- Ninth-largest of the US supply areas by natural gas, 2025.
- 2.0% of the natural gas produced in the United States, 2025.
- Natural gas production fell 7% in 2025 from 2024.
Production
- filling in (est. · missed) . Hatching marks our estimate of the volume still to be filed. That estimate draws on our own production forecast. A check on the forecast behind this estimate measured a miss. It updates as filings arrive
All from what the source published. 96.1% held at well grain.
How the volume breaks down
- 81.1% Reported by the official source by well
- 3.9% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 15.0% 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.
Every cubic foot through April 2026 starts from what the official source published for those months. Measured over January 1993 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.
- filling in (est. · missed) . Hatching marks our estimate of the volume still to be filed. That estimate draws on our own production forecast. A check on the forecast behind this estimate measured a miss. It updates as filings arrive
Still arriving: Oct 2026 <1% filed.
All from what the source published. 85.5% held at well grain.
How the volume breaks down
- 32.6% Reported by the official source by well
- 14.5% Reported by the official source as a lease, facility, field or state total. Published without per-well detail.
- 52.9% 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.
Every barrel through April 2026 starts from what the official source published for those months. Measured over January 1993 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 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.
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 allocated
| Year | Oil (MMbbl) | Gas produced (Bcf) |
|---|---|---|
| 2025 | 47.2 | 948 |
| 2024 | 50.4 | 1,015 |
| 2023 | 53.2 | 1,134 |
| 2022 | 53.0 | 1,186 |
| 2021 | 52.1 | 1,180 |
| 2020 | 52.5 | 1,252 |
| 2019 | 61.8 | 1,404 |
| 2018 | 64.7 | 1,464 |
| 2017 | 66.1 | 1,584 |
| 2016 | 69.7 | 1,702 |
| 2015 | 81.9 | 1,952 |
| 2014 | 89.7 | 2,179 |
| 2013 | 88.1 | 2,217 |
| 2012 | 81.1 | 2,277 |
| 2011 | 79.6 | 2,310 |
| 2010 | 74.9 | 2,218 |
| 2009 | 72.3 | 2,007 |
| 2008 | 71.5 | 1,693 |
| 2007 | 65.7 | 1,414 |
| 2006 | 65.9 | 1,328 |
| 2005 | 64.1 | 1,265 |
| 2004 | 64.3 | 1,265 |
| 2003 | 65.1 | 1,272 |
| 2002 | 64.8 | 1,267 |
| 2001 | 66.8 | 1,333 |
| 2000 | 68.7 | 1,385 |
| 1999 | 56.0 | 1,415 |
| 1998 | 60.2 | 1,466 |
| 1997 | 83.7 | 1,573 |
| 1996 | 85.1 | 1,622 |
| 1995 | 86.0 | 1,630 |
| 1994 | 91.1 | 1,694 |
| 1993 | 98.0 | 1,699 |
Source: CommoVision (commovision.com)
Monthly table (last 24 months)
| Month | Oil (Mbbl) | Gas produced (MMcf) |
|---|---|---|
| 2026-05 | 3,810.0 | 75,543 |
| 2026-04 | 3,786.2 | 73,681 |
| 2026-03 | 4,040.9 | 81,230 |
| 2026-02 | 3,624.7 | 70,850 |
| 2026-01 | 3,612.8 | 77,503 |
| 2025-12 | 4,002.2 | 80,233 |
| 2025-11 | 3,749.6 | 76,583 |
| 2025-10 | 3,979.5 | 80,974 |
| 2025-09 | 3,917.5 | 78,295 |
| 2025-08 | 3,943.5 | 78,948 |
| 2025-07 | 4,057.3 | 79,181 |
| 2025-06 | 3,873.4 | 76,531 |
| 2025-05 | 4,000.6 | 80,727 |
| 2025-04 | 3,961.4 | 80,041 |
| 2025-03 | 4,071.0 | 83,006 |
| 2025-02 | 3,711.9 | 77,510 |
| 2025-01 | 3,980.2 | 76,396 |
| 2024-12 | 4,253.8 | 79,890 |
| 2024-11 | 3,934.8 | 79,432 |
| 2024-10 | 4,418.5 | 84,004 |
| 2024-09 | 4,172.3 | 82,760 |
| 2024-08 | 4,220.5 | 86,076 |
| 2024-07 | 4,281.4 | 87,293 |
| 2024-06 | 4,094.4 | 82,732 |
Source: CommoVision (commovision.com)
Source: CommoVision · Mid-Continent, data through September 2026.
Well map
- Oil 454,598
- Natural gas 175,087
- Undetermined 174,318
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
453 of the drawn cohorts’ wells are not in these curves yet: each is still producing and joins its curve once it carries a forecast.
453 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
Average production per well, for wells grouped by when they first produced.
How these curves are built
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. 132,977 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 | 276 | 6 | — | 0.2 | 70.2 | — | 0.0 | 1 | 100% | 60 |
| 2025 | 527 | 10.4 | — | 1.7 | 390 | — | 0.0 | 6 | 100% | 60 |
| 2024 | 653 | 10.1 | 4.4 | 3.3 | 132 | 62.1 | 0.0 | 19 | 100% | 60 |
| 2023 | 792 | 14.8 | 8.1 | 7.2 | 177 | 93.8 | 0.1 | 30 | 100% | 60 |
| 2022 | 1,152 | 14.3 | 9.7 | 10.1 | 426 | 210 | 0.2 | 42 | 100% | 60 |
| 2021 | 730 | 12.2 | 7.4 | 9.2 | 229 | 115 | 0.1 | 55 | 100% | 60 |
| 2020 | 519 | 13.1 | 8.6 | 12.9 | 401 | 148 | 0.3 | 66 | 100% | 60 |
| 2019 | 1,052 | 17.8 | 7.6 | 12.8 | 398 | 192 | 0.3 | 79 | 100% | 60 |
| 2018 | 1,444 | 15.7 | 7.3 | 11.1 | 310 | 184 | 0.3 | 91 | 100% | 60 |
| 2017 | 1,359 | 15.1 | 8.3 | 12.7 | 327 | 209 | 0.3 | 102 | 100% | 60 |
| 2016 | 1,152 | 12.7 | 6.9 | 11.5 | 389 | 194 | 0.3 | 114 | 100% | 60 |
| 2015 | 2,531 | 20 | 8.4 | 14.3 | 444 | 211 | 0.4 | 126 | 100% | 60 |
| 2010-2014 | 29,521 | 13.4 | 4.7 | 8.3 | 382 | 184 | 0.3 | 138 | 100% | 60 |
Source: CommoVision (commovision.com)
Source: CommoVision · Mid-Continent type curves, per-well production by first-production cohort.
Top operators in the Mid-Continent, 2025 best estimate incl. unsplit totals and allocated
Top operators in the Mid-Continent, 2025: full table
| Operator | Oil (Mbbl/d, 2025) | Gas produced (MMcf/d, 2025) | Share of output |
|---|---|---|---|
| Flywheel Energy | 0.0 | 556.5 | 12.3% |
| Merit Energy Company | 5.1 | 325.9 | 8.9% |
| XTO Energy | 6.8 | 117.3 | 4.8% |
| Scout Energy Management | 0.5 | 200.9 | 4.6% |
| Calyx Energy | 0.0 | 127.5 | 2.8% |
| VAN Buren Energy Production, LLC | 0.0 | 96.1 | 2.1% |
| Razorback Production, LLC | 0.0 | 81.2 | 1.8% |
| Berexco | 4.8 | 3.4 | 1.7% |
| Sanguine Gas Exploration | 0.0 | 71.2 | 1.6% |
| Trinity Operating (USG) | 0.0 | 61.7 | 1.4% |
| 2,586 other operators | 106.9 | 779.3 | 52.5% |
| Without a named operator | 5.2 | 177.4 | 5.6% |
Mbbl/d = thousand barrels per day · MMcf/d = million cubic feet per day (units).
Source: CommoVision (commovision.com)
Top counties by 2025 production best estimate incl. unsplit totals and allocated
| County | Oil (MMbbl) | Gas produced (Bcf) | Share of 2025 output |
|---|---|---|---|
| Pittsburg County, Oklahoma | 0 | 153.1 | 12.4% |
| Van Buren County, Arkansas | 0 | 72.6 | 5.9% |
| Hughes County, Oklahoma | 0.2 | 63.7 | 5.3% |
| Cleburne County, Arkansas | 0 | 62.4 | 5.1% |
| White County, Arkansas | 0 | 61.4 | 5.0% |
Share of output counts oil and gas together, gas at its market-value weight.
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 29, 2026 (57 so far), drawn hatched. Of the 1,021 approved in the 365 days to October 29, 2026, 999 are permits to drill a new well, 14 are recompletion permits and 8 are permits to deepen, sidetrack or re-enter existing wells. Permits to drill a new well: 999 in the 365 days to October 29, 2026 and 232 in the last 90 days of that window. How permits are counted.
Most permits 365 days to October 29, 2026
- In the Mid-Continent footprint, 1,021 well permits were approved in the 365 days to October 29, 2026. Of those, 236 came in the last 90 days of that window. The latest approval on record is dated October 29, 2026.
- Of the 1,021 approved in the 365 days to October 29, 2026, 999 are permits to drill a new well, 14 are recompletion permits and 8 are permits to deepen, sidetrack or re-enter existing wells. Permits to drill a new well: 999 in the 365 days to October 29, 2026 and 232 in the last 90 days of that window.
- Permits counted here come from Arkansas, Kansas, Oklahoma and Texas.
Well permits approved per month: full table
| Month | Permits approved |
|---|---|
| Oct 2026 (through October 29, 2026) | 57 |
| Sep 2026 | 97 |
| Aug 2026 | 82 |
| Jul 2026 | 100 |
| Jun 2026 | 109 |
| May 2026 | 112 |
| Apr 2026 | 123 |
| Mar 2026 | 94 |
| Feb 2026 | 46 |
| Jan 2026 | 47 |
| Dec 2025 | 71 |
| Nov 2025 | 73 |
| Oct 2025 | 68 |
| Sep 2025 | 63 |
| Aug 2025 | 69 |
| Jul 2025 | 107 |
| Jun 2025 | 101 |
| May 2025 | 63 |
| Apr 2025 | 58 |
| Mar 2025 | 96 |
| Feb 2025 | 65 |
| Jan 2025 | 74 |
| Dec 2024 | 121 |
| Nov 2024 | 119 |
Source: CommoVision (commovision.com)
Active drilling rigs
Interactive chart. Focus it and use the left and right arrow keys to read each week, Page Up and Page Down to move a year, Home and End for the ends of the series. The full figures are also in the table below.
- In the Mid-Continent, 0 drilling rigs were active in the week to October 30, 2026 (3 fewer than a year earlier).
- Since Oct 2016, the weekly count peaked at 19 in May 2018.
- Rig locations are rolled up to this supply area's footprint, and no rig counts toward two areas.
Average active rigs per month: full table
| Month | Oil-directed | Gas-directed | Miscellaneous | All rigs |
|---|---|---|---|---|
| Oct 2026 (through October 30, 2026) | 0.2 | 0 | 0 | 0.2 |
| Sep 2026 | 1 | 0 | 0 | 1 |
| Aug 2026 | 1 | 0 | 0 | 1 |
| Jul 2026 | 1 | 0 | 0 | 1 |
| Jun 2026 | 0.4 | 0 | 0 | 0.4 |
| May 2026 | 0 | 0 | 0 | 0 |
| Apr 2026 | 0 | 0 | 0 | 0 |
| Mar 2026 | 0.2 | 2.4 | 0 | 2.6 |
| Feb 2026 | 1 | 2 | 0 | 3 |
| Jan 2026 | 1 | 1.2 | 0 | 2.2 |
| Dec 2025 | 1.4 | 1.2 | 0 | 2.6 |
| Nov 2025 | 2.2 | 1 | 0 | 3.2 |
| Oct 2025 | 1 | 1.8 | 0 | 2.8 |
| Sep 2025 | 0.4 | 1 | 0 | 1.4 |
| Aug 2025 | 0 | 1 | 0 | 1 |
| Jul 2025 | 0.2 | 0.8 | 0 | 1 |
| Jun 2025 | 0.2 | 0.8 | 0 | 1 |
| May 2025 | 1.2 | 1 | 0 | 2.2 |
| Apr 2025 | 2 | 1 | 0 | 3 |
| Mar 2025 | 1.6 | 1 | 0 | 2.6 |
| Feb 2025 | 1 | 1 | 0 | 2 |
| Jan 2025 | 1 | 1 | 0 | 2 |
| Dec 2024 | 1 | 1 | 0 | 2 |
| Nov 2024 | 2.5 | 0.8 | 0 | 3.2 |
Source: CommoVision (commovision.com)
Formations
One cross-section through the Texas side of the Anadarko Basin.
9 formations along a 40-mile line, west-northwest to east-southeast.
Every depth drawn here is our own estimate, built from the curated formation tops of Texas wells across the basin. The pale ribbon along each boundary shows how certain that depth is. Where the ribbon is wider, the depth is less certain.
How these sections are built
The section follows one straight line across the basin's Texas side, and the map beside it shows where that line runs.
West is on the left.
The depth of each formation along the line is estimated from the depths at which Texas wells across the basin met that formation, as recorded in their completion reports.
A formation is drawn where enough wells along the line place it and where it stands clear of the formation above or below.
Key numbers
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 |
|---|---|---|---|
| Arkansas production | well | 1920-04 | ~62–101% of EIA |
| Colorado production | well | 1999-01 | ~100% of EIA |
| Kansas production | well | 1987-01 | ~99% of EIA |
| New Mexico production | well | 1924-01 | ~100% of EIA |
| Oklahoma production | lease + well | 1990-07 | ~99–100% of EIA |
| Texas production | well | 1993-01 | ~100% 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 the Mid-Continent are regenerated at every build from the same catalog of sources the data is built from.
What the data shows
- The Mid-Continent footprint produced 47.2 MMbbl of oil and 948.4 Bcf of natural gas in 2025.
- Natural gas production in the Mid-Continent footprint peaked in 2011 at 2.31 Tcf; 2025 output of 948.4 Bcf ran at 41% of that peak.
- Mid-Continent is a producing area, not a single rock target: the 804,195 wells here are grouped by where they are, across every formation and trajectory drilled inside it.
- The figures here start in 1993, when Texas filings begin. Before that only Arkansas, Kansas and Oklahoma report, together 82% of the area's volume at that point, so the earlier years are not drawn as the whole area. Colorado from 1999 (1% of the area at that point) and New Mexico from 2010 (under 1% of the area at that point) are included from their own first year.
- 124,570 producing wells tracked, trailing 12 months per region.
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