BBakken SubsurfaceNorth Dakota well index

NDIC file 23991 · API 33-053-04448-00-00

JOHNSTON 7-6 2TFH

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

Active (A)Oil and gasSpud 2013

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
BANKS
Spud date
Total depth
21,953 ft
Legal location
SESE Sec 7 T152N R98W
Footages
473 ft FSL · 774 ft FEL
County
McKenzie County
NDIC file no.
23991
API no.
33-053-04448-00-00

Location & navigation

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

47.99391, -103.26600

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

157 months reported, Aug 2013 to Aug 2026, BAKKEN pool.

Cumulative oil461KbblAug ’13 to Aug ’26 · 157 of 157 months known
Peak oil rate816bbl/dJan 2014 · 25,294 bbl in 31 days
Oil, last 12 months9,843bbl+106% against the 12 before
Gas–oil ratio, last 12 months3,915scf/bblfirst year 1,753 scf/bbl
Water cut, last 12 months66%first year 33% · 555K bbl water in all
Gas sold, last 12 months88%of gas produced · 2,392 mcf reported flared
05001,000Oil bbl/d222014201620182020202220242026

Early time

First reported month
Aug 2013
Months to peak
6 (Jan 2014)
Peak month rate
816 bbl/d on 31 days
First 3 months, oil
14,957 bbl
First 6 months, oil
40,251 bbl
First 12 months, oil
114,155 bbl
First 24 months, oil
183,298 bbl
Share of cumulative in year 1
25%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
22 bbl/d
Latest rate as share of peak
2.7%
Uptime, last 12 months
99% of days
Cumulative gas
1.35M mcf
Cumulative water
555K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
9783,1072,01130333,17767%
9814,2961,79631324,37965%
9002,9211,84830303,24667%
1,0783,3721,69331353,12861%
1,0053,5171,70831323,50063%
8423,0121,58628303,57765%
4362,9751,65631146,82379%
7472,9811,53730253,99167%
6772,7891,57128244,12070%
8413,5881,73430284,26667%
6893,4351,26831224,98565%
6692,5381,03030223,79461%

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.