BBakken SubsurfaceNorth Dakota well index

NDIC file 35983 · API 33-105-05096-00-00

WM JOHNSON 157-99-3B-10-4B

Operated by ENERPLUS RESOURCES USA CORPORATION · Williams County, North Dakota

Active (A)Oil and gasSpud 2019

Well facts

Operator
ENERPLUS RESOURCES USA CORPORATION
Status
Active (A)
Well type
Oil and gas (OG)
Field
LONE TREE LAKE
Spud date
Total depth
20,889 ft
Legal location
LOT4 Sec 3 T157N R99W
Footages
330 ft FNL · 1,315 ft FWL
County
Williams County
NDIC file no.
35983
API no.
33-105-05096-00-00

Location & navigation

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

48.45872, -103.46675

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

85 months reported, Aug 2019 to Aug 2026, BAKKEN pool.

Cumulative oil342KbblAug ’19 to Aug ’26 · 85 of 85 months known
Peak oil rate1,862bbl/dAug 2019 · 7,448 bbl in 4 days
Oil, last 12 months16.3Kbbl-8% against the 12 before
Gas–oil ratio, last 12 months2,133scf/bblfirst year 1,454 scf/bbl
Water cut, last 12 months71%first year 72% · 851K bbl water in all
Gas sold, last 12 months96%of gas produced · 1,160 mcf reported flared
01,0002,000Oil bbl/d202020202120222023202420252026

Early time

First reported month
Aug 2019
Months to peak
2 (Sep 2019)
Peak month rate
1,862 bbl/d on 4 days
First 3 months, oil
71,872 bbl
First 6 months, oil
126,343 bbl
First 12 months, oil
183,548 bbl
First 24 months, oil
233,626 bbl
Share of cumulative in year 1
54%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
20 bbl/d
Latest rate as share of peak
1.1%
Uptime, last 12 months
96% of days
Cumulative gas
533K mcf
Cumulative water
851K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
1,3722,1533,06729471,56969%
1,4662,4544,48631471,67475%
1,7753,6874,24730592,07771%
1,4643,6052,95631472,46267%
1,7272,8922,81431561,67562%
1,6224,5023,89228582,77671%
1,6954,5964,36031552,71272%
1,6274,6173,46030542,83868%
2,1025,1524,63331682,45169%
5954572,552302076881%
203571,405171228187%
6195321,180312085966%

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.