BBakken SubsurfaceNorth Dakota well index

NDIC file 23965 · API 33-061-02284-00-00

ARIKARA 15-22HW

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
20,944 ft
Legal location
NENW Sec 15 T150N R93W
Footages
283 ft FNL · 2,621 ft FWL
County
Mountrail County
NDIC file no.
23965
API no.
33-061-02284-00-00

Location & navigation

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

47.81795, -102.56772

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 oil648KbblMar ’18 to Aug ’26 · 102 of 102 months known
Peak oil rate1,368bbl/dMar 2018 · 41,052 bbl in 30 days
Oil, last 12 months17Kbbl-29% against the 12 before
Gas–oil ratio, last 12 months9,388scf/bblfirst year 1,364 scf/bbl
Water cut, last 12 months67%first year 44% · 557K bbl water in all
Gas sold, last 12 months99%of gas produced · 248 mcf reported flared
05001,0001,500Oil bbl/d4020192020202120222023202420252026

Early time

First reported month
Mar 2018
Months to peak
3 (May 2018)
Peak month rate
1,368 bbl/d on 30 days
First 3 months, oil
117,534 bbl
First 6 months, oil
188,738 bbl
First 12 months, oil
323,865 bbl
First 24 months, oil
443,853 bbl
Share of cumulative in year 1
50%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
40 bbl/d
Latest rate as share of peak
2.9%
Uptime, last 12 months
94% of days
Cumulative gas
1.35M mcf
Cumulative water
557K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
1,05312,4932,168264011,86467%
1,80814,3863,31531587,95765%
1,0217,3991,82916647,24764%
1,96613,9813,94531637,11167%
1,08810,2523,37826429,42376%
1,63513,1563,92228588,04671%
1,77116,3122,57131579,21159%
1,55215,8701,862305210,22655%
1,41115,2253,169314610,79069%
1,20113,5063,697304011,24675%
1,22713,7632,458314011,21767%
1,23512,9512,515314010,48767%

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.