BBakken SubsurfaceNorth Dakota well index

NDIC file 26600 · API 33-053-05328-00-00

SEQUOIA 24-9TFH

Operated by BURLINGTON RESOURCES OIL & GAS COMPANY LP · McKenzie County, North Dakota

Active (A)Oil and gasSpud 2013

Well facts

Operator
BURLINGTON RESOURCES OIL & GAS COMPANY LP
Status
Active (A)
Well type
Oil and gas (OG)
Field
HAWKEYE
Spud date
Total depth
21,370 ft
Legal location
SESW Sec 9 T152N R95W
Footages
385 ft FSL · 1,365 ft FWL
County
McKenzie County
NDIC file no.
26600
API no.
33-053-05328-00-00

Location & navigation

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

47.99312, -102.84959

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

145 months reported, Aug 2014 to Aug 2026, BAKKEN pool.

Cumulative oil330KbblAug ’14 to Aug ’26 · 145 of 145 months known
Peak oil rate1,316bbl/dAug 2014 · 14,478 bbl in 11 days
Oil, last 12 months8,545bbl+17% against the 12 before
Gas–oil ratio, last 12 months5,701scf/bblfirst year 1,211 scf/bbl
Water cut, last 12 months42%first year 22% · 130K bbl water in all
Gas sold, last 12 months97%of gas produced · 471 mcf reported flared
05001,0001,500Oil bbl/d15201620182020202220242026

Early time

First reported month
Aug 2014
Months to peak
5 (Dec 2014)
Peak month rate
1,316 bbl/d on 11 days
First 3 months, oil
51,724 bbl
First 6 months, oil
109,017 bbl
First 12 months, oil
154,182 bbl
First 24 months, oil
202,014 bbl
Share of cumulative in year 1
47%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
15 bbl/d
Latest rate as share of peak
1.1%
Uptime, last 12 months
97% of days
Cumulative gas
694K mcf
Cumulative water
130K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
1,4417,46666830485,18132%
1,2177,42370731396,09937%
8885,51850830306,21436%
8434,98649331275,91537%
7584,11550728275,42940%
8274,44770827315,37746%
4713,12846031156,64149%
4372,29741230155,25649%
4933,01231530166,11039%
2641,36950625115,18666%
4522,41337331155,33845%
4542,53948030155,59351%

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.