Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08745		Well Classification: ERIW	Status: IJ - 10/30/2025
Well Name/No:	FEE #136X (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	10/30/2025
FacilityID:	231076	LocationID:	315576
County:	RIO BLANCO #103	Location:	SWNE 20 2N102W 6
Field:	RANGELY - #72370	Elevation:	5285 ft.
Basin:	PICEANCE BASIN
Planned Location:	2501FNL 2600 FEL	Lat/Long: 40.128955 / -108.867066	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.128940 / -108.867070	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 10/30/2025 Measured TD: 6537 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 10/30/2025
Wellbore Permit
Permit #:	810807	Expiration Date:	9/19/1981
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:	6/21/1984
Measured TD:	6537 ft.	Measured PB depth:	6441 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 2971 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: 0 ft., Bottom: 2971 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6537 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: 0 ft., Bottom: 6537 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3371 ft.
MORRISON	3468 ft.
ENTRADA	4279 ft.
NAVAJO	4465 ft.
CHINLE	5053 ft.
WEBER	5945 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 10/30/2025 Interval Top: 5963 ft. Interval Bottom: 6441 ft.

Completed Information for Formation WEBER

1st Production Date:	6/21/1984	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	10/29/2025	Treatment End Date:	10/29/2025
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):	2500
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:	7/26/2024	Treatment End Date:	7/26/2024
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/solvent and 40 bbls Fresh water
Total fluid used in treatment (bbls):	135	Max pressure during treatment (psi):	2530
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):	40	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:	1/26/2023	Treatment End Date:	1/26/2023
Treatment Summary:	Pumped 4000 gallons (95.2 bbl.) 15% HCL with inhibitor and 35 bbl fresh water
Total fluid used in treatment (bbls):	130	Max pressure during treatment (psi):	2500
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:	11/29/2019	Treatment End Date:	11/29/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL,6% CITRIC,MUTSOL WITH 40 BBLS FRESH WATER
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	2300
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):	40	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:	7/31/2017	Treatment End Date:	7/31/2017
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL AND 100 GALLONS SOLVENT. 165 BBLS FRESH WATER. CTI 8/24/1984
Total fluid used in treatment (bbls):	215	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	165	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	5/8/2007
Treatment Summary:	ACIDIZE FORMATION W/ 159 BBLS 15% HCL, EOT @ 6119'

Tubing Size:	2.875 in.	Tubing Setting Depth:	6153 ft.
Tubing Packer Depth:	5833 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5963 ft.	# Of Holes:	159
Interval Bottom:	6441 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