BBakken SubsurfaceNorth Dakota well index

NDIC file 41139 · API 33-105-06325-00-00

Stangeland 7-7H

Operated by CONTINENTAL RESOURCES, INC. · Williams County, North Dakota

Active (A)Oil and gasSpud 2024

Well facts

Operator
CONTINENTAL RESOURCES, INC.
Status
Active (A)
Well type
Oil and gas (OG)
Field
CRAZY MAN CREEK
Spud date
Total depth
21,517 ft
Legal location
SESE Sec 6 T153N R99W
Footages
298 ft FSL · 1,058 ft FEL
County
Williams County
NDIC file no.
41139
API no.
33-105-06325-00-00

Location & navigation

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

48.09748, -103.45784

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

17 months reported, Apr 2025 to Aug 2026, BAKKEN pool.

Cumulative oil250KbblApr ’25 to Aug ’26 · 17 of 17 months known
Peak oil rate1,562bbl/dJun 2025 · 24,988 bbl in 16 days
Oil, last 12 months103Kbbl12 of 12 months known
Gas–oil ratio, last 12 months3,514scf/bblfirst year 2,144 scf/bbl
Water cut, last 12 months59%first year 53% · 295K bbl water in all
Gas sold, last 12 months96%of gas produced · 7,027 mcf reported flared
01,0002,000Oil bbl/d148Apr ’25Jun ’25Aug ’25Oct ’25Dec ’25Feb ’26Apr ’26Jun ’26Aug ’26

Early time

First reported month
Apr 2025
Months to peak
2 (May 2025)
Peak month rate
1,562 bbl/d on 16 days
First 3 months, oil
85,579 bbl
First 6 months, oil
160,975 bbl
First 12 months, oil
220,921 bbl
Share of cumulative in year 1
89%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
148 bbl/d
Latest rate as share of peak
9.5%
Uptime, last 12 months
100% of days
Cumulative gas
603K mcf
Cumulative water
295K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
14,73247,89519,238304913,25157%
11,71526,78516,901313782,28659%
10,31625,06414,558303442,43059%
12,03632,41713,849313882,69354%
9,84038,83715,316313173,94761%
7,44130,76016,065282664,13468%
8,59832,41811,524312773,77057%
6,86427,04613,211302293,94066%
5,94629,1095,112311924,89646%
4,79824,4635,660301605,09954%
6,50425,3919,798312103,90460%
4,57923,0359,496311485,03167%

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.