BBakken SubsurfaceNorth Dakota well index

NDIC file 39017 · API 33-053-09883-00-00

Yellowstone 10H

Operated by LIME ROCK RESOURCES V-A, L.P. · McKenzie County, North Dakota

Active (A)Oil and gasSpud 2022

Well facts

Operator
LIME ROCK RESOURCES V-A, L.P.
Status
Active (A)
Well type
Oil and gas (OG)
Field
NORTH FORK
Spud date
Total depth
21,183 ft
Legal location
LOT3 Sec 1 T149N R97W
Footages
576 ft FNL · 2,402 ft FWL
County
McKenzie County
NDIC file no.
39017
API no.
33-053-09883-00-00

Location & navigation

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

47.75935, -103.03799

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

36 months reported, Sep 2023 to Aug 2026, BAKKEN pool.

Cumulative oil213KbblSep ’23 to Aug ’26 · 36 of 36 months known
Peak oil rate1,157bbl/dSep 2023 · 13,882 bbl in 12 days
Oil, last 12 months16.8Kbbl-54% against the 12 before
Gas–oil ratio, last 12 months20,339scf/bblfirst year 3,390 scf/bbl
Water cut, last 12 months73%first year 42% · 227K bbl water in all
Gas sold, last 12 months96%of gas produced · 9,298 mcf reported flared
05001,0001,500Oil bbl/d28Sep ’23Mar ’24Sep ’24Mar ’25Sep ’25Mar ’26

Early time

First reported month
Sep 2023
Months to peak
2 (Oct 2023)
Peak month rate
1,157 bbl/d on 12 days
First 3 months, oil
68,984 bbl
First 6 months, oil
116,237 bbl
First 12 months, oil
159,760 bbl
First 24 months, oil
196,546 bbl
Share of cumulative in year 1
75%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
28 bbl/d
Latest rate as share of peak
2.4%
Uptime, last 12 months
100% of days
Cumulative gas
1.29M mcf
Cumulative water
227K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
1,79231,0944,147306017,35270%
1,80031,8584,216315817,69970%
1,65430,7053,952305518,56470%
1,60831,9404,017315219,86371%
1,48430,9303,854314820,84272%
1,33425,4003,635284819,04073%
1,53127,7593,724314918,13171%
1,24225,2953,493304120,36674%
1,12425,1303,409313622,35875%
1,16525,3183,481303921,73275%
1,16030,0493,771313725,90476%
87125,5073,448312829,28580%

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.