BBakken SubsurfaceNorth Dakota well index

NDIC file 23972 · API 33-105-02824-00-00

STATE 36-1 4TFH

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

Active (A)Oil and gasSpud 2012

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
STONY CREEK
Spud date
Total depth
21,336 ft
Legal location
NENE Sec 12 T154N R100W
Footages
480 ft FNL · 1,060 ft FEL
County
Williams County
NDIC file no.
23972
API no.
33-105-02824-00-00

Location & navigation

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

48.18207, -103.47902

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

157 months reported, Aug 2013 to Aug 2026, BAKKEN pool.

Cumulative oil449KbblAug ’13 to Aug ’26 · 157 of 157 months known
Peak oil rate608bbl/dNov 2013 · 18,235 bbl in 30 days
Oil, last 12 months9,723bbl-13% against the 12 before
Gas–oil ratio, last 12 months5,713scf/bblfirst year 940 scf/bbl
Water cut, last 12 months75%first year 40% · 611K bbl water in all
Gas sold, last 12 months96%of gas produced · 971 mcf reported flared
0250500750Oil bbl/d202014201620182020202220242026

Early time

First reported month
Aug 2013
Months to peak
4 (Nov 2013)
Peak month rate
608 bbl/d on 30 days
First 3 months, oil
34,475 bbl
First 6 months, oil
67,214 bbl
First 12 months, oil
111,229 bbl
First 24 months, oil
180,156 bbl
Share of cumulative in year 1
25%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
20 bbl/d
Latest rate as share of peak
3.3%
Uptime, last 12 months
91% of days
Cumulative gas
726K mcf
Cumulative water
611K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
8594,2772,86830294,97977%
8444,3312,80131275,13277%
8934,3702,87730304,89476%
8233,4834,28531274,23284%
9362,9992,75230313,20475%
451365310411380941%
1,0664,3993,40431344,12776%
8593,5232,30323374,10173%
8937,3432,90931298,22377%
7696,3792,52530268,29577%
7177,201324312310,04331%
6136,8821,207312011,22766%

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.