BBakken SubsurfaceNorth Dakota well index

NDIC file 35922 · API 33-105-05083-00-00

Chloe 4-20H

Operated by CONTINENTAL RESOURCES, INC. · Williams County, North Dakota

Active (A)Oil and gasSpud 2022

Well facts

Operator
CONTINENTAL RESOURCES, INC.
Status
Active (A)
Well type
Oil and gas (OG)
Field
EAST FORK
Spud date
Total depth
21,331 ft
Legal location
SESW Sec 20 T156N R99W
Footages
325 ft FSL · 1,383 ft FWL
County
Williams County
NDIC file no.
35922
API no.
33-105-05083-00-00

Location & navigation

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

48.31450, -103.44778

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

46 months reported, Nov 2022 to Aug 2026, BAKKEN pool.

Cumulative oil304KbblNov ’22 to Aug ’26 · 46 of 46 months known
Peak oil rate1,127bbl/dDec 2022 · 28,181 bbl in 25 days
Oil, last 12 months24.5Kbbl-31% against the 12 before
Gas–oil ratio, last 12 months3,104scf/bblfirst year 962 scf/bbl
Water cut, last 12 months72%first year 61% · 568K bbl water in all
Gas sold, last 12 months92%of gas produced · 2,205 mcf reported flared
05001,0001,500Oil bbl/d36Nov ’22May ’23Nov ’23May ’24Nov ’24May ’25Nov ’25May ’26

Early time

First reported month
Nov 2022
Months to peak
3 (Jan 2023)
Peak month rate
1,127 bbl/d on 25 days
First 3 months, oil
69,707 bbl
First 6 months, oil
125,208 bbl
First 12 months, oil
188,184 bbl
First 24 months, oil
251,489 bbl
Share of cumulative in year 1
62%

Today

Last reported month
Aug 2026
Last month with oil
Aug 2026
Latest oil rate
36 bbl/d
Latest rate as share of peak
3.2%
Uptime, last 12 months
95% of days
Cumulative gas
469K mcf
Cumulative water
568K bbl
Pools reported
BAKKEN
Last 12 months as a table
MonthOil bblGas mcfWater bblDaysOil bbl/dGOR scf/bblWater cut
2,3856,4645,89827882,71071%
2,8419,2836,58831923,26870%
2,4658,4695,99430823,43671%
2,3768,6055,80231773,62271%
1,5216,5894,81230514,33276%
1,5685,1784,45027583,30274%
2,2895,3115,88631742,32072%
2,2746,0385,44228812,65571%
1,8104,4855,16926702,47874%
2,4716,3425,68030822,56770%
1,4204,6234,17926553,25675%
1,1194,7754,63731364,26781%

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.