BBakken SubsurfaceNorth Dakota well index

NDIC file 31138 · API 33-025-02921-00-00

JORGENSON FEDERAL 148-96-10-15-4HLW

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

Active (A)Oil and gasSpud 2016

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
LOST BRIDGE
Spud date
Total depth
21,125 ft
Legal location
SWSW Sec 3 T148N R96W
Footages
167 ft FSL · 877 ft FWL
County
Dunn County
NDIC file no.
31138
API no.
33-025-02921-00-00

Location & navigation

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

47.66156, -102.90471

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

112 months reported, May 2017 to Aug 2026, BAKKEN pool.

Cumulative oil724KbblMay ’17 to Aug ’26 · 112 of 112 months known
Peak oil rate2,244bbl/dMay 2017 · 22,435 bbl in 10 days
Oil, last 12 months25Kbbl-3% against the 12 before
Gas–oil ratio, last 12 months2,303scf/bblfirst year 1,170 scf/bbl
Water cut, last 12 months29%first year 21% · 239K bbl water in all
Gas sold, last 12 months98%of gas produced · 119 mcf reported flared
01,0002,0003,000Oil bbl/d76201820192020202120222023202420252026

Early time

First reported month
May 2017
Months to peak
3 (Jul 2017)
Peak month rate
2,244 bbl/d on 10 days
First 3 months, oil
81,815 bbl
First 6 months, oil
145,308 bbl
First 12 months, oil
268,233 bbl
First 24 months, oil
405,887 bbl
Share of cumulative in year 1
37%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
76 bbl/d
Latest rate as share of peak
3.4%
Uptime, last 12 months
91% of days
Cumulative gas
1.35M mcf
Cumulative water
239K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
2,3696,4891,02630792,73930%
2,5907,4411,17931842,87331%
230699904583,03928%
1,8182,54270825731,39828%
2,5014,98387031811,99226%
2,2685,32394028812,34729%
2,1604,85476931702,24726%
2,1584,81889830722,23329%
2,2605,0731,08531732,24532%
2,2205,0981,17930742,29635%
2,1265,01572331692,35925%
2,2815,20876030762,28325%

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.