BBakken SubsurfaceNorth Dakota well index

NDIC file 38722 · API 33-053-09813-00-00

CALHOUN 149-98-3-10-4H

Operated by DEVON ENERGY WILLISTON, L.L.C. · McKenzie 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
PEMBROKE
Spud date
Total depth
21,580 ft
Legal location
SESW Sec 34 T150N R98W
Footages
870 ft FSL · 1,714 ft FWL
County
McKenzie County
NDIC file no.
38722
API no.
33-053-09813-00-00

Location & navigation

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

47.76341, -103.21197

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

45 months reported, Dec 2022 to Aug 2026, BAKKEN pool.

Cumulative oil247KbblDec ’22 to Aug ’26 · 45 of 45 months known
Peak oil rate1,114bbl/dJan 2023 · 34,539 bbl in 31 days
Oil, last 12 months14.1Kbbl-39% against the 12 before
Gas–oil ratio, last 12 months10,022scf/bblfirst year 3,485 scf/bbl
Water cut, last 12 months74%first year 61% · 459K bbl water in all
Gas sold, last 12 months96%of gas produced · 4,090 mcf reported flared
05001,0001,500Oil bbl/d28Dec ’22Jun ’23Dec ’23Jun ’24Dec ’24Jun ’25Dec ’25Jun ’26

Early time

First reported month
Dec 2022
Months to peak
2 (Jan 2023)
Peak month rate
1,114 bbl/d on 31 days
First 3 months, oil
65,107 bbl
First 6 months, oil
125,519 bbl
First 12 months, oil
176,885 bbl
First 24 months, oil
215,261 bbl
Share of cumulative in year 1
72%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
28 bbl/d
Latest rate as share of peak
2.5%
Uptime, last 12 months
98% of days
Cumulative gas
1.21M mcf
Cumulative water
459K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
1,37515,8094,271304611,49776%
1,25614,3943,846314111,46075%
1,21813,3823,567304110,98775%
1,52613,9073,83131499,11372%
1,55313,8783,60531508,93670%
1,19112,0513,173284310,11873%
82611,3132,925292813,69678%
1,30111,1483,22030438,56971%
4957,5412,445271815,23483%
1,3317,9443,73630445,96874%
1,1209,6292,92230378,59772%
88010,0322,941312811,40077%

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.