BBakken SubsurfaceNorth Dakota well index

NDIC file 36032 · API 33-025-03673-00-00

SKUNK CREEK 12-10-11-16H3

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

Active (A)Oil and gasSpud 2019

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
SOUTH FORK
Spud date
Total depth
21,029 ft
Legal location
NWSW Sec 10 T148N R93W
Footages
2,444 ft FSL · 299 ft FWL
County
Dunn County
NDIC file no.
36032
API no.
33-025-03673-00-00

Location & navigation

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

47.65284, -102.52324

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

82 months reported, Nov 2019 to Aug 2026, BAKKEN pool.

Cumulative oil280KbblNov ’19 to Aug ’26 · 82 of 82 months known
Peak oil rate941bbl/dNov 2019 · 28,238 bbl in 30 days
Oil, last 12 months9,543bbl-16% against the 12 before
Gas–oil ratio, last 12 months2,520scf/bblfirst year 1,071 scf/bbl
Water cut, last 12 months72%first year 66% · 527K bbl water in all
Gas sold, last 12 months100%of gas produced · 82 mcf reported flared
05001,000Oil bbl/d262020202120222023202420252026

Early time

First reported month
Nov 2019
Months to peak
1 (Nov 2019)
Peak month rate
941 bbl/d on 30 days
First 3 months, oil
63,597 bbl
First 6 months, oil
124,630 bbl
First 12 months, oil
167,878 bbl
First 24 months, oil
211,036 bbl
Share of cumulative in year 1
60%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
26 bbl/d
Latest rate as share of peak
2.7%
Uptime, last 12 months
84% of days
Cumulative gas
481K mcf
Cumulative water
527K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
5281,3641,97525212,58379%
1,3283,6843,44131432,77472%
1,0942,5292,19230362,31267%
5872,3081,76228213,93275%
9963,0111,60531323,02362%
8481,2691,20627311,49659%
1,1802,7362,05131382,31963%
3581,2671,13414263,53976%
1,0152,9193,85731332,87679%
8152,1363,71726312,62182%
0016010—100%
7948211,99731261,03472%

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.