BBakken SubsurfaceNorth Dakota well index

NDIC file 23967 · API 33-061-02286-00-00

ARIKARA 15-22HD

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

Active (A)Oil and gasSpud 2017

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
REUNION BAY
Spud date
Total depth
21,071 ft
Legal location
NENW Sec 15 T150N R93W
Footages
403 ft FNL · 2,613 ft FWL
County
Mountrail County
NDIC file no.
23967
API no.
33-061-02286-00-00

Location & navigation

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

47.81762, -102.56775

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

102 months reported, Mar 2018 to Aug 2026, BAKKEN pool.

Cumulative oil600KbblMar ’18 to Aug ’26 · 102 of 102 months known
Peak oil rate1,786bbl/dApr 2018 · 53,574 bbl in 30 days
Oil, last 12 months12.5Kbbl-32% against the 12 before
Gas–oil ratio, last 12 months11,054scf/bblfirst year 1,074 scf/bbl
Water cut, last 12 months56%first year 42% · 353K bbl water in all
Gas sold, last 12 months99%of gas produced · 294 mcf reported flared
01,0002,000Oil bbl/d2920192020202120222023202420252026

Early time

First reported month
Mar 2018
Months to peak
2 (Apr 2018)
Peak month rate
1,786 bbl/d on 30 days
First 3 months, oil
140,931 bbl
First 6 months, oil
195,655 bbl
First 12 months, oil
276,910 bbl
First 24 months, oil
393,068 bbl
Share of cumulative in year 1
46%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
29 bbl/d
Latest rate as share of peak
1.6%
Uptime, last 12 months
89% of days
Cumulative gas
1.39M mcf
Cumulative water
353K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
1,2929,1112,37526507,05265%
1,42915,4421,993275310,80658%
1,25116,3481,986264813,06861%
1,30111,2412,04331428,64061%
1,20413,4631,802313911,18260%
1,03311,382963283711,01848%
1,01112,3711,340303412,23657%
70410,348988203514,69958%
99911,630638303311,64239%
6597,639457203311,59241%
6818,944702262613,13451%
8929,774815312910,95748%

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.