BBakken SubsurfaceNorth Dakota well index

NDIC file 39696 · API 33-025-04659-00-00

North John Elk 28-27HIL

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

Active (A)Oil and gasSpud 2023

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
21,624 ft
Legal location
NWSW Sec 28 T150N R93W
Footages
2,139 ft FSL · 157 ft FWL
County
Dunn County
NDIC file no.
39696
API no.
33-025-04659-00-00

Location & navigation

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

47.78112, -102.59913

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

32 months reported, Jan 2024 to Aug 2026, BAKKEN pool.

Cumulative oil336KbblJan ’24 to Aug ’26 · 32 of 32 months known
Peak oil rate1,645bbl/dJan 2024 · 39,472 bbl in 24 days
Oil, last 12 months38.2Kbbl-57% against the 12 before
Gas–oil ratio, last 12 months3,739scf/bblfirst year 1,443 scf/bbl
Water cut, last 12 months51%first year 37% · 230K bbl water in all
Gas sold, last 12 months99%of gas produced · 2,060 mcf reported flared
01,0002,000Oil bbl/d104Jan ’24Apr ’24Jul ’24Oct ’24Jan ’25Apr ’25Jul ’25Oct ’25Jan ’26Apr ’26Jul ’26

Early time

First reported month
Jan 2024
Months to peak
3 (Mar 2024)
Peak month rate
1,645 bbl/d on 24 days
First 3 months, oil
107,698 bbl
First 6 months, oil
179,066 bbl
First 12 months, oil
253,737 bbl
First 24 months, oil
313,718 bbl
Share of cumulative in year 1
75%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
104 bbl/d
Latest rate as share of peak
6.3%
Uptime, last 12 months
90% of days
Cumulative gas
666K mcf
Cumulative water
230K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
4,33314,4413,950301443,33348%
4,09514,4704,004311323,53449%
3,92513,7123,042301313,49444%
3,15212,6392,503271174,01044%
2,3479,1682,191191243,90648%
2,2719,5742,243221034,21650%
3,71912,3103,077311203,31045%
3,30811,8983,533301103,59752%
3,25912,1844,498311053,73958%
1,1725,9472,19015785,07465%
3,39312,6805,107311093,73760%
3,22813,8273,420311044,28351%

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.