BBakken SubsurfaceNorth Dakota well index

NDIC file 30379 · API 33-105-03945-00-00

FOLVAG 5-8 7H

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

Active (A)Oil and gasSpud 2015

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
STONY CREEK
Spud date
Total depth
20,720 ft
Legal location
SWSW Sec 32 T156N R100W
Footages
800 ft FSL · 263 ft FWL
County
Williams County
NDIC file no.
30379
API no.
33-105-03945-00-00

Location & navigation

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

48.28678, -103.58181

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

108 months reported, Sep 2017 to Aug 2026, BAKKEN pool.

Cumulative oil307KbblSep ’17 to Aug ’26 · 108 of 108 months known
Peak oil rate638bbl/dApr 2018 · 16,594 bbl in 26 days
Oil, last 12 months12.3Kbbl-16% against the 12 before
Gas–oil ratio, last 12 months7,930scf/bblfirst year 965 scf/bbl
Water cut, last 12 months78%first year 68% · 662K bbl water in all
Gas sold, last 12 months96%of gas produced · 2,409 mcf reported flared
0250500750Oil bbl/d38201820192020202120222023202420252026

Early time

First reported month
Sep 2017
Months to peak
9 (May 2018)
Peak month rate
638 bbl/d on 26 days
First 3 months, oil
2,512 bbl
First 6 months, oil
3,477 bbl
First 12 months, oil
70,480 bbl
First 24 months, oil
135,245 bbl
Share of cumulative in year 1
23%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
38 bbl/d
Latest rate as share of peak
5.9%
Uptime, last 12 months
82% of days
Cumulative gas
708K mcf
Cumulative water
662K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
1,3677,3083,85630465,34674%
1,48010,0854,22931486,81474%
1,0827,8333,12325437,23974%
5825,3062,91521289,11783%
1,54511,3204,66331507,32775%
8916,6702,95220457,48677%
7517,4613,50423339,93582%
5505,7412,996153710,43884%
1,3839,4774,79131456,85278%
7807,4362,81919419,53378%
7278,6303,758223311,87184%
1,17610,3775,21731388,82482%

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.