BBakken SubsurfaceNorth Dakota well index

NDIC file 39262 · API 33-105-05855-00-00

FIELD 18-19F 4H

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

Active (A)Oil and gasSpud 2022

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
TODD
Spud date
Total depth
21,104 ft
Legal location
NWNE Sec 18 T154N R101W
Footages
329 ft FNL · 1,669 ft FEL
County
Williams County
NDIC file no.
39262
API no.
33-105-05855-00-00

Location & navigation

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

48.16792, -103.71903

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

44 months reported, Jan 2023 to Aug 2026, BAKKEN pool.

Cumulative oil292KbblJan ’23 to Aug ’26 · 44 of 44 months known
Peak oil rate997bbl/dFeb 2023 · 15,958 bbl in 16 days
Oil, last 12 months18.6Kbbl-47% against the 12 before
Gas–oil ratio, last 12 months2,941scf/bblfirst year 1,011 scf/bbl
Water cut, last 12 months80%first year 73% · 816K bbl water in all
Gas sold, last 12 months95%of gas produced · 1,237 mcf reported flared
05001,000Oil bbl/d63Jan ’23Jul ’23Jan ’24Jul ’24Jan ’25Jul ’25Jan ’26Jul ’26

Early time

First reported month
Jan 2023
Months to peak
7 (Jul 2023)
Peak month rate
997 bbl/d on 16 days
First 3 months, oil
34,211 bbl
First 6 months, oil
103,596 bbl
First 12 months, oil
180,593 bbl
First 24 months, oil
253,955 bbl
Share of cumulative in year 1
62%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
63 bbl/d
Latest rate as share of peak
6.3%
Uptime, last 12 months
93% of days
Cumulative gas
544K mcf
Cumulative water
816K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
4872,8942,79610495,94385%
1,1414,8887,13231374,28486%
1,6004,8327,13430533,02082%
1,8155,1477,12431592,83680%
1,4524,1705,73526562,87280%
1,4044,2686,36228503,04082%
1,7544,7786,64831572,72479%
1,9264,9375,93030642,56375%
1,8724,5325,90131602,42176%
1,6044,7186,00729552,94179%
1,6324,6635,89630542,85778%
1,9434,9596,33131632,55277%

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.