BBakken SubsurfaceNorth Dakota well index

NDIC file 28235 · API 33-105-03513-00-00

MYRON 9-4 #7H

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

Active (A)Oil and gasSpud 2014

Well facts

Operator
DEVON ENERGY WILLISTON, L.L.C.
Status
Active (A)
Well type
Oil and gas (OG)
Field
SQUIRES
Spud date
Total depth
21,553 ft
Legal location
SWSE Sec 9 T155N R103W
Footages
350 ft FSL · 1,470 ft FEL
County
Williams County
NDIC file no.
28235
API no.
33-105-03513-00-00

Location & navigation

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

48.25677, -103.93433

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

143 months reported, Oct 2014 to Aug 2026, BAKKEN pool.

Cumulative oil204KbblOct ’14 to Aug ’26 · 143 of 143 months known
Peak oil rate238bbl/dMar 2015 · 5,723 bbl in 24 days
Oil, last 12 months4,635bbl-20% against the 12 before
Gas–oil ratio, last 12 months2,464scf/bblfirst year 943 scf/bbl
Water cut, last 12 months80%first year 82% · 804K bbl water in all
Gas sold, last 12 months81%of gas produced · 792 mcf reported flared
0100200300Oil bbl/d12201620182020202220242026

Early time

First reported month
Oct 2014
Months to peak
6 (Mar 2015)
Peak month rate
238 bbl/d on 24 days
First 3 months, oil
1,040 bbl
First 6 months, oil
8,486 bbl
First 12 months, oil
29,017 bbl
First 24 months, oil
59,795 bbl
Share of cumulative in year 1
14%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
12 bbl/d
Latest rate as share of peak
5.2%
Uptime, last 12 months
98% of days
Cumulative gas
247K mcf
Cumulative water
804K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
4501,0801,58930152,40078%
4511,0351,92331152,29581%
2476281,52022112,54386%
4178052,41031131,93085%
4178691,62031132,08480%
3959302,44928142,35486%
4301,2192,23831142,83584%
3271,01989730113,11673%
3371,03177731113,05970%
37393517730122,50732%
4209661,03831142,30071%
3719051,48930122,43980%

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.