BBakken SubsurfaceNorth Dakota well index

NDIC file 40393 · API 33-061-05295-00-00

Missouri River 25-26HD

Operated by DEVON ENERGY WILLISTON, L.L.C. · Mountrail County, North Dakota

Active (A)Oil and gasSpud 2024

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
REUNION BAY
Spud date
Total depth
24,181 ft
Legal location
SWNE Sec 24 T150N R93W
Footages
2,518 ft FNL · 2,007 ft FEL
County
Mountrail County
NDIC file no.
40393
API no.
33-061-05295-00-00

Location & navigation

Navigate with Google MapsDriving directions to the well headOpen in Google MapsSatellite view of the padOpen in Apple Maps

47.79729, -102.52219

Published surface location (NAD83). A horizontal well's lateral can run up to three miles from this point.

See it in 3D

Open in the regional 3D viewerSurveyed well path, operator and production; Bakken-system horizontals onlyBakken Subsurface 3DBasin-wide production playback

Production

22 months reported, Nov 2024 to Aug 2026, BAKKEN pool.

Cumulative oil305KbblNov ’24 to Aug ’26 · 22 of 22 months known
Peak oil rate1,614bbl/dDec 2024 · 43,588 bbl in 27 days
Oil, last 12 months79.3Kbbl12 of 12 months known
Gas–oil ratio, last 12 months2,126scf/bblfirst year 1,278 scf/bbl
Water cut, last 12 months39%first year 38% · 194K bbl water in all
Gas sold, last 12 months100%of gas produced · 649 mcf reported flared
01,0002,000Oil bbl/d144Nov ’24Jan ’25Mar ’25May ’25Jul ’25Sep ’25Nov ’25Jan ’26Mar ’26May ’26Jul ’26

Early time

First reported month
Nov 2024
Months to peak
2 (Dec 2024)
Peak month rate
1,614 bbl/d on 27 days
First 3 months, oil
74,356 bbl
First 6 months, oil
170,873 bbl
First 12 months, oil
245,318 bbl
Share of cumulative in year 1
80%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
144 bbl/d
Latest rate as share of peak
8.9%
Uptime, last 12 months
96% of days
Cumulative gas
440K mcf
Cumulative water
194K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
9,87420,7084,936303292,09733%
9,62321,1154,896313102,19434%
4,7649,8024,138162982,05846%
9,15613,1966,864312951,44143%
7,71314,9124,760302571,93338%
5,96412,5814,151272212,10941%
5,7399,6803,786311851,68740%
6,24612,5013,883302082,00138%
5,97914,9863,790311932,50639%
5,21013,9213,561301742,67241%
4,61813,0663,477311492,82943%
4,45912,2583,187311442,74942%

As first reported to NDIC in each month's report (NDIC Monthly Production Reports, Jan 2003 to Aug 2026). Operators amend past months later and the published reports are not updated, so a month can differ from the current record. A blank or missing month is unknown, not zero, and a cumulative over such months is a lower bound; two pools reported in one month are summed. Rates per producing day divide the month's volume by the days reported, so a month reported without producing days has no rate. Gas–oil ratio is gas produced over oil produced; water cut is water over oil plus water. Months from Jan 2003 to Apr 2015 are read from the Division's PDF reports, which print no flared gas and list a well in a unitized pool only inside its unit's total.

Spacing units

Units whose published footprint holds at least 660 ft of this well's surveyed lateral. Allowances are facts extracted from signed NDIC orders, machine-extracted and not human-reviewed.

Nearby wells

Closest published well heads within 3 miles; wells on one pad share a location.

Other published attributes (1)
symbolA-OG

DMR shapefile columns not shown above, unchanged.