BBakken SubsurfaceNorth Dakota well index

NDIC file 34817 · API 33-105-04776-00-00

MYRNA 21X-2B

Operated by XTO ENERGY INC · Williams County, North Dakota

Active (A)Oil and gasSpud 2019

Well facts

Operator
XTO ENERGY INC
Status
Active (A)
Well type
Oil and gas (OG)
Field
ALKALI CREEK
Spud date
Total depth
20,366 ft
Legal location
LOT3 Sec 2 T154N R95W
Footages
776 ft FNL · 1,979 ft FWL
County
Williams County
NDIC file no.
34817
API no.
33-105-04776-00-00

Location & navigation

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

48.19526, -102.86321

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

55 months reported, Feb 2022 to Aug 2026, BAKKEN pool.

Cumulative oil247KbblFeb ’22 to Aug ’26 · 55 of 55 months known
Peak oil rate844bbl/dJun 2022 · 18,575 bbl in 22 days
Oil, last 12 months23.4Kbbl-34% against the 12 before
Gas–oil ratio, last 12 months4,167scf/bblfirst year 1,618 scf/bbl
Water cut, last 12 months59%first year 62% · 351K bbl water in all
Gas sold, last 12 months96%of gas produced · 2,955 mcf reported flared
05001,000Oil bbl/d72Feb ’22Aug ’22Feb ’23Aug ’23Feb ’24Aug ’24Feb ’25Aug ’25Feb ’26Aug ’26

Early time

First reported month
Feb 2022
Months to peak
5 (Jun 2022)
Peak month rate
844 bbl/d on 22 days
First 3 months, oil
245 bbl
First 6 months, oil
35,305 bbl
First 12 months, oil
96,923 bbl
First 24 months, oil
157,050 bbl
Share of cumulative in year 1
39%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
72 bbl/d
Latest rate as share of peak
8.6%
Uptime, last 12 months
97% of days
Cumulative gas
663K mcf
Cumulative water
351K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
2,1239,6713,10030714,55559%
1,7618,0362,62231574,56360%
1,5797,1432,28426614,52459%
1,8898,9542,95731614,74061%
1,4167,0892,62628515,00665%
1,1976,3502,44928435,30567%
1,2495,3782,17227464,30663%
2,4928,8511,80130833,55242%
2,5958,4183,76431843,24459%
2,6869,3173,64930903,46958%
2,2038,5582,99931713,88558%
2,2429,8812,96731724,40757%

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.