BBakken SubsurfaceNorth Dakota well index

NDIC file 35840 · API 33-105-05074-00-00

HALVERSON 13X-33EXH

Operated by XTO ENERGY INC · Williams County, North Dakota

Active (A)Oil and gasSpud 2018

Well facts

Operator
XTO ENERGY INC
Status
Active (A)
Well type
Oil and gas (OG)
Field
ALKALI CREEK
Spud date
Total depth
26,097 ft
Legal location
NWSW Sec 33 T155N R95W
Footages
2,526 ft FSL · 425 ft FWL
County
Williams County
NDIC file no.
35840
API no.
33-105-05074-00-00

Location & navigation

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

48.20412, -102.91294

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

33 months reported, Dec 2023 to Aug 2026, BAKKEN pool.

Cumulative oil528KbblDec ’23 to Aug ’26 · 33 of 33 months known
Peak oil rate2,063bbl/dFeb 2024 · 59,821 bbl in 29 days
Oil, last 12 months129Kbbl-14% against the 12 before
Gas–oil ratio, last 12 months2,604scf/bblfirst year 1,915 scf/bbl
Water cut, last 12 months47%first year 38% · 380K bbl water in all
Gas sold, last 12 months96%of gas produced · 2,341 mcf reported flared
01,0002,0003,000Oil bbl/d248Dec ’23Mar ’24Jun ’24Sep ’24Dec ’24Mar ’25Jun ’25Sep ’25Dec ’25Mar ’26Jun ’26

Early time

First reported month
Dec 2023
Months to peak
3 (Feb 2024)
Peak month rate
2,063 bbl/d on 29 days
First 3 months, oil
80,866 bbl
First 6 months, oil
157,381 bbl
First 12 months, oil
315,473 bbl
First 24 months, oil
438,074 bbl
Share of cumulative in year 1
60%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
248 bbl/d
Latest rate as share of peak
12.0%
Uptime, last 12 months
100% of days
Cumulative gas
1.12M mcf
Cumulative water
380K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
12,59720,05713,283304201,59251%
13,42122,93813,292314331,70950%
12,67923,48011,720304231,85248%
12,70226,01811,183314102,04847%
12,68828,92110,868314092,27946%
10,54428,0048,561283772,65645%
10,51431,9519,803313393,03948%
9,95629,3197,861303322,94544%
9,70931,4758,830313133,24248%
8,51930,1136,852302843,53545%
7,94831,2506,216312563,93244%
7,67832,2427,414312484,19949%

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.