BBakken SubsurfaceNorth Dakota well index

NDIC file 30565 · API 33-105-03959-00-00

FOLVAG 5-8 1H

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
20,855 ft
Legal location
SWSW Sec 32 T156N R100W
Footages
831 ft FSL · 371 ft FWL
County
Williams County
NDIC file no.
30565
API no.
33-105-03959-00-00

Location & navigation

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

48.28687, -103.58137

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

106 months reported, Nov 2017 to Aug 2026, BAKKEN pool.

Cumulative oil280KbblNov ’17 to Aug ’26 · 106 of 106 months known
Peak oil rate374bbl/dMay 2018 · 10,838 bbl in 29 days
Oil, last 12 months5,423bbl-43% against the 12 before
Gas–oil ratio, last 12 months10,252scf/bblfirst year 1,240 scf/bbl
Water cut, last 12 months83%first year 69% · 640K bbl water in all
Gas sold, last 12 months96%of gas produced · 1,406 mcf reported flared
0200400Oil bbl/d19201820192020202120222023202420252026

Early time

First reported month
Nov 2017
Months to peak
7 (May 2018)
Peak month rate
374 bbl/d on 29 days
First 3 months, oil
644 bbl
First 6 months, oil
17,733 bbl
First 12 months, oil
65,857 bbl
First 24 months, oil
125,903 bbl
Share of cumulative in year 1
24%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
19 bbl/d
Latest rate as share of peak
5.1%
Uptime, last 12 months
100% of days
Cumulative gas
749K mcf
Cumulative water
640K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
3907,5992,578301319,48587%
4554,5082,03031159,90882%
5146,4882,895301712,62385%
4585,8592,533301512,79385%
2103,2011,29531715,24386%
2854,4732,188281015,69588%
4282,9501,38631146,89376%
3192,7131,69630118,50584%
5534,4842,61631188,10883%
5764,5812,60930197,95382%
6464,7512,68931217,35481%
5893,9892,52231196,77281%

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.