BBakken SubsurfaceNorth Dakota well index

NDIC file 40581 · API 33-023-01533-00-00

STOUT 1831-4BH

Operated by KODA RESOURCES OPERATING, LLC · Divide County, North Dakota

Active (A)Oil and gasSpud 2025

Well facts

Operator
KODA RESOURCES OPERATING, LLC
Status
Active (A)
Well type
Oil and gas (OG)
Field
FERTILE VALLEY
Spud date
Total depth
24,636 ft
Legal location
SESW Sec 18 T160N R102W
Footages
655 ft FSL · 1,903 ft FWL
County
Divide County
NDIC file no.
40581
API no.
33-023-01533-00-00

Location & navigation

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

48.67902, -103.91991

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

9 months reported, Dec 2025 to Aug 2026, BAKKEN pool.

Cumulative oil96.4KbblDec ’25 to Aug ’26 · 8 of 9 months known
Peak oil rate608bbl/dDec 2025 · 18,845 bbl in 31 days
Oil, last 12 months96.4Kbbl8 of 9 months known
Gas–oil ratio, last 12 months1,080scf/bblfirst year 1,080 scf/bbl
Water cut, last 12 months76%first year 76% · 301K bbl water in all
Gas sold, last 12 months53%of gas produced · 37.6K mcf reported flared
0250500750Oil bbl/d216Dec ’25Jan ’26Feb ’26Mar ’26Apr ’26May ’26Jun ’26Jul ’26Aug ’26

Early time

First reported month
Dec 2025
Months to peak
1 (Dec 2025)
Peak month rate
608 bbl/d on 31 days
First 3 months, oil
34,273 bbl (2 of 3 known)
First 6 months, oil
72,807 bbl (5 of 6 known)

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
216 bbl/d
Latest rate as share of peak
35.6%
Uptime, last 12 months
100% of days
Cumulative gas
104K mcf
Cumulative water
301K bbl
Unknown months
1 of 9 (confidential or not in that month's report)
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
18,84511,74757,5063160862375%
———————
15,42813,40741,7522855186973%
15,39015,83541,575314961,02973%
12,51114,32236,475304171,14574%
10,63313,32334,070313431,25376%
8,75411,67829,858302921,33477%
8,11512,37432,358312621,52580%
6,70611,43727,151312161,70580%

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.