Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08761		Well Classification: ERIW	Status: IJ - 9/3/2025
Well Name/No:	FEE #137X (Click Well Name for Production Data)	Click Here for Transporter Gatherer Info
Operator:	SCOUT ENERGY MANAGEMENT LLC - 10779 (Click Operator Name for Company Detail Report)	Federal Or State Lease #:	47443
Facility Status:	IJ	Status Date	9/3/2025
FacilityID:	231092	LocationID:	315582
County:	RIO BLANCO #103	Location:	SWNW 20 2N102W 6
Field:	RANGELY - #72370	Elevation:	5305 ft.
Basin:	PICEANCE BASIN
Planned Location:	2604FNL 144 FWL	Lat/Long: 40.128675 / -108.876246	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.128660 / -108.876180	Lat/Long Source: Field Measured

Wellbore And Formation Details -- select either a wellbore Or formation to expand.

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 9/3/2025 Measured TD: 6563 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 9/3/2025
Wellbore Permit
Permit #:	810879	Expiration Date:	9/28/1981
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEE	Surface Owner:	Not available
Unit:		Unit Number:
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	8/22/1984
Measured TD:	6563 ft.	Measured PB depth:	6535 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Casing:	String Type: CONDUCTOR, Hole Size: , Size: 16 in., Top: 0 ft., Depth: 40 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: 0 ft., Bottom: 40 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 3026 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 900, Top: 0 ft., Bottom: 3026 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6563 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 810, Top: , Bottom: 6563 ft., Determination Method: CALC
Additional Cement:	String Type: 1ST , Top: 6166 ft., Depth: 6196 ft., Bottom: 6196 ft., Sacks: 50, Method: Squeeze
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3338 ft.
MORRISON	3439 ft.
ENTRADA	4237 ft.
NAVAJO	4427 ft.
CHINLE	5043 ft.
WEBER	5925 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 9/3/2025 Interval Top: 5930 ft. Interval Bottom: 6438 ft.

Completed Information for Formation WEBER

1st Production Date:	10/2/1981	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/26/2025	Treatment End Date:	8/26/2025
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL s/solvent and 42 bbls fresh water.
Total fluid used in treatment (bbls):	137	Max pressure during treatment (psi):	2400
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	42	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	9/17/2024	Treatment End Date:	9/17/2024
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/solvent and 35 bbls Fresh water
Total fluid used in treatment (bbls):	130	Max pressure during treatment (psi):	2400
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	35	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	9/9/2023	Treatment End Date:	9/9/2023
Treatment Summary:	Pumped 95.2 bbls 15% HCL w/solvent and 35 bbls fresh water
Total fluid used in treatment (bbls):	130	Max pressure during treatment (psi):	2450
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	35	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	7/26/2021	Treatment End Date:	7/26/2021
Treatment Summary:	PUMPED 2000 GALLONS (4.6 BBLS) 15% HCL W/6% CITRIC ACID AND 90 BBLS WATER
Total fluid used in treatment (bbls):	137	Max pressure during treatment (psi):	1875
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	90	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	11/12/2017	Treatment End Date:	11/12/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL WITH 90 BBLS WATER
Total fluid used in treatment (bbls):	185	Max pressure during treatment (psi):
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	90	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	10/4/2010
Treatment Summary:	ACID STIMULATION 10-4-2010 PUMPED 4000 GALLONS OF 20% HCL THROUGH END OF COILED TUBING AT 6340' @ 550 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	5902 ft.
Tubing Packer Depth:	5695 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5930 ft.	# Of Holes:	117
Interval Bottom:	6438 ft.	Hole Size:	0.5 in.

All Designations		Date
Primary Well Designation: Defined Inactive i
Reported Plugged	N
Out Of Service Repurposed	N
Out Of Service	N
Inactive Exception	N
Noticed Inactive	N
Defined Inactive (UIC)	Y	Defined Inactive 04/30/2023
Low Producing	N

September 2024 - August 2025	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	0
GOR
GOR Determination
Average BOE per Day	0.000
Average MCFE per Day	0.000

Federal Financial Assurance

Tribal Well