BBakken SubsurfaceNorth Dakota well index

NDIC file 29130 · API 33-053-06180-00-00

BW-JOHNSON- 149-99-1003H-6

Operated by HESS BAKKEN INVESTMENTS II, LLC · McKenzie County, North Dakota

Active (A)Oil and gasSpud 2015

Well facts

Operator
HESS BAKKEN INVESTMENTS II, LLC
Status
Active (A)
Well type
Oil and gas (OG)
Field
CHERRY CREEK
Spud date
Total depth
21,096 ft
Legal location
SESE Sec 10 T149N R99W
Footages
466 ft FSL · 510 ft FEL
County
McKenzie County
NDIC file no.
29130
API no.
33-053-06180-00-00

Location & navigation

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

47.73371, -103.32805

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

125 months reported, Apr 2016 to Aug 2026, BAKKEN pool.

Cumulative oil269KbblApr ’16 to Aug ’26 · 125 of 125 months known
Peak oil rate699bbl/dApr 2016 · 14,670 bbl in 21 days
Oil, last 12 months8,506bbl-17% against the 12 before
Gas–oil ratio, last 12 months3,305scf/bblfirst year 1,632 scf/bbl
Water cut, last 12 months60%first year 45% · 293K bbl water in all
Gas sold, last 12 months87%of gas produced · 478 mcf reported flared
0250500750Oil bbl/d342017201820192020202120222023202420252026

Early time

First reported month
Apr 2016
Months to peak
2 (May 2016)
Peak month rate
699 bbl/d on 21 days
First 3 months, oil
43,254 bbl
First 6 months, oil
68,681 bbl
First 12 months, oil
103,442 bbl
First 24 months, oil
147,555 bbl
Share of cumulative in year 1
38%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
34 bbl/d
Latest rate as share of peak
4.9%
Uptime, last 12 months
90% of days
Cumulative gas
636K mcf
Cumulative water
293K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
7052,8351,12129244,02161%
7722,8201,24431253,65362%
6332,3901,02425253,77662%
8832,7131,33431283,07260%
7112,5731,34030243,61965%
7382,2451,10428263,04260%
5831,92289826223,29761%
3551,14650215243,22859%
8402,26398831272,69454%
3721,30960220193,51962%
8482,7061,17031273,19158%
1,0663,1931,21231342,99553%

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.