BBakken SubsurfaceNorth Dakota well index

NDIC file 29233 · API 33-105-03698-00-00

SMITH FARM 23-14 #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
COW CREEK
Spud date
Total depth
20,965 ft
Legal location
NENW Sec 26 T155N R101W
Footages
430 ft FNL · 1,805 ft FWL
County
Williams County
NDIC file no.
29233
API no.
33-105-03698-00-00

Location & navigation

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

48.22538, -103.64004

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

132 months reported, Sep 2015 to Aug 2026, BAKKEN pool.

Cumulative oil290KbblSep ’15 to Aug ’26 · 132 of 132 months known
Peak oil rate438bbl/dOct 2015 · 13,583 bbl in 31 days
Oil, last 12 months3,979bbl-36% against the 12 before
Gas–oil ratio, last 12 months3,080scf/bblfirst year 1,077 scf/bbl
Water cut, last 12 months79%first year 65% · 540K bbl water in all
Gas sold, last 12 months96%of gas produced · 480 mcf reported flared
0200400600Oil bbl/d12201620182020202220242026

Early time

First reported month
Sep 2015
Months to peak
2 (Oct 2015)
Peak month rate
438 bbl/d on 31 days
First 3 months, oil
31,195 bbl
First 6 months, oil
60,170 bbl
First 12 months, oil
78,202 bbl
First 24 months, oil
108,131 bbl
Share of cumulative in year 1
27%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
12 bbl/d
Latest rate as share of peak
2.8%
Uptime, last 12 months
99% of days
Cumulative gas
494K mcf
Cumulative water
540K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
1667431,0573064,47686%
1917631,1623163,99586%
2951,0891,29430103,69281%
3191,0411,28227123,26380%
3921,0631,30431132,71277%
3401,0071,26028122,96279%
3029871,77331103,26885%
4261,2271,44930142,88077%
4741,1121,15631152,34671%
3491,0901,03930123,12375%
3391,0601,24631113,12779%
3861,0751,31931122,78577%

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.