Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-07581		Well Classification: ERIW	Status: IJ - 11/25/2025
Well Name/No:	FEE #85X (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	11/25/2025
FacilityID:	229922	LocationID:	314936
County:	RIO BLANCO #103	Location:	SESE 29 2N102W 6
Field:	RANGELY - #72370	Elevation:	5235 ft.
Basin:	PICEANCE BASIN
Planned Location:	348FSL 19 FEL	Lat/Long: 40.107686 / -108.857775	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.107765 / -108.857838	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 11/25/2025 Measured TD: 6395 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 11/25/2025
Wellbore Permit
Permit #:	100001	Expiration Date:	3/9/1974
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:	1/15/1974
Spud Date:	12/23/1973	Spud Date Is:	ACTUAL
Measured TD:	6395 ft.	Measured PB depth:	6370 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:	NEW CEMENT BOND LOG - HARD COPY SUBMITTED WITH FORM 21 MAILED 1/22/2013
Casing:	String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 783 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 525, Top: 0 ft., Bottom: 783 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6395 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 700, Top: 0 ft., Bottom: 6395 ft., Determination Method: CALC
Casing:	String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 6330 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 220, Top: 3865 ft., Bottom: 6330 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3012 ft.
MORRISON	3093 ft.
CURTIS	3725 ft.
ENTRADA	3866 ft.
CARMEL	4015 ft.
NAVAJO	4085 ft.
CHINLE	4674 ft.
SHINARUMP	4790 ft.
MOENKOPI	4860 ft.
WEBER	5533 ft.	6395 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 11/25/2025 Interval Top: 5566 ft. Interval Bottom: 6329 ft.

Completed Information for Formation WEBER

1st Production Date:	5/29/1974	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	11/24/2025	Treatment End Date:	11/24/2025
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 90 BBLS FRESH WATER
Total fluid used in treatment (bbls):	137	Max pressure during treatment (psi):	2350
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):	0	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:
Treatment Date:	7/23/2025	Treatment End Date:	N/A
Treatment Summary:	1/18/2024 UIC Repair - Repair sunken wellhead and surface casing. RIH w/ injection equipment well ready to RTI pending an approved Form 21.
Total fluid used in treatment (bbls):		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):		Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):		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:	5/29/2025	Treatment End Date:	5/29/2025
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 35 BBLS FRESH WATER
Total fluid used in treatment (bbls):	82	Max pressure during treatment (psi):	2711
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):	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:	3/19/2024	Treatment End Date:	3/19/2024
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 15 BBLS FRESH WATER
Total fluid used in treatment (bbls):	62	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):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	15	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:	5/23/2022	Treatment End Date:	5/23/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT AND 35 BBLS 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):		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:	1/3/2022	Treatment End Date:	1/3/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/6% CITRIC ACID AND 47 BBLS WATER
Total fluid used in treatment (bbls):	142	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):	47	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:	3/13/2020	Treatment End Date:	3/13/2020
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/6% CITRIC ACID AND 3.8 BBLS MUTUAL SOLVENT
Total fluid used in treatment (bbls):	99	Max pressure during treatment (psi):	1700
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):		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:	7/18/2019	Treatment End Date:	7/18/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/3% CITRIC ACID AND 45 BBLS WATER.
Total fluid used in treatment (bbls):		Max pressure during treatment (psi):	2470
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):	45	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:	1/8/2013	Treatment End Date:	1/9/2013
Treatment Summary:	RUN LINER FROM SURFACE TO 6330' RE-PERF WEBER FORMATION BREAKBOWN PERFORATIONS WITH 15% HCL ACID. PUMPED ACID - SHUT WELL IN.
Total fluid used in treatment (bbls):	165	Max pressure during treatment (psi):	3840
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:	5
Total acid used in treatment (bbls):	59	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	0	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:

Tubing Size:	2.875 in.	Tubing Setting Depth:	5586 ft.
Tubing Packer Depth:	5498 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5566 ft.	# Of Holes:	756
Interval Bottom:	6329 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