Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06141		Well Classification: ERIW	Status: IJ - 8/27/2025
Well Name/No:	FEE #43 (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	8/27/2025
FacilityID:	229063	LocationID:	314569
County:	RIO BLANCO #103	Location:	SENW 19 2N102W 6
Field:	RANGELY - #72370	Elevation:	5327 ft.
Basin:	PICEANCE BASIN
Planned Location:	1980FNL 1980 FWL	Lat/Long: 40.130345 / -108.888386	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.130622 / -108.888346	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 8/27/2025 Measured TD:

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 8/27/2025
Wellbore Permit
Permit #:	100000	Expiration Date:	6/24/1977
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:	8/5/1947
Spud Date:	6/1/1947	Spud Date Is:	ACTUAL
Measured TD:		Measured PB depth:	6543 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:
Casing:	String Type: CONDUCTOR, Hole Size: , Size: 16 in., Top: 0 ft., Depth: 45 ft., Weight: 55 , Citings Type: ACTUAL
Cement:	Sacks: 108, Top: 0 ft., Bottom: 45 ft., Determination Method: CALC
Casing:	String Type: SURF, Hole Size: , Size: 10.75 in., Top: 0 ft., Depth: 734 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 500, Top: 0 ft., Bottom: 734 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 5955 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: , Bottom: 5955 ft., Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5 in., Top: 5801 ft., Depth: 6550 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 300, Top: 5801 ft., Bottom: 6550 ft., Determination Method: CALC
Additional Cement:	String Type: 1ST , Top: 5647 ft., Depth: 5835 ft., Bottom: 5835 ft., Sacks: 12, Method: Squeeze
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3340 ft.		N	N
MORRISON	3423 ft.		N	N
CURTIS	4132 ft.		N	N
ENTRADA	4233 ft.		N	N
CARMEL	4381 ft.		N	N
NAVAJO	4431 ft.		N	N
CHINLE	5060 ft.		N	N
SHINARUMP	5174 ft.		N	N
MOENKOPI	5262 ft.		N	N
WEBER	5935 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 8/27/2025 Interval Top: 6003 ft. Interval Bottom: 6465 ft.

Completed Information for Formation WEBER

1st Production Date:	8/6/1947	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/22/2025	Treatment End Date:	8/22/2025
Treatment Summary:	PUMPED 2000 GALLONS (47.6 bbls) 15% HCL w/SOLVENT AND 35 BBLS FRESH WATER, 0 BBLS RECYCLED. CONVERTED TO INJECTION 06/03/1969
Total fluid used in treatment (bbls):	82	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):	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:
Treatment Date:	7/29/2025	Treatment End Date:	N/A
Treatment Summary:	UIC Failure post workover, well was shut in for high casing pressure. Pulled top packer, ran new top packer with FL injection string. Return to injection upon approval of a Form 21. CONVERTED TO INJECTION 06/03/1969
Total fluid used in treatment (bbls):	410	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):	407	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	402	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	7/24/2025	Treatment End Date:	N/A
Treatment Summary:	UIC Failure post workover, well failed MIT pretest decided to run 5.5" tie back liner from 5801 feet to surface. Return to injection upon approval of a Form 21. CONVERTED TO INJECTION 06/03/1969
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:	4/17/2025	Treatment End Date:	4/17/2025
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 35 BBLS WATER CONVERTED TO INJECTIN 06/03/1969
Total fluid used in treatment (bbls):	82	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):	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:
Treatment Date:	8/10/2023	Treatment End Date:	N/A
Treatment Summary:	Rig work to attempt to fish SIE equipment, only got out top swellable pkr and top SIE packer, retested with a RBP and received a passing MIT, upgraded WH and RIH w/ new injection equipment . Return to injection pending an approved form 21. CONVERTED TO INJECTION 06/1969
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 Date:	12/16/2009
Treatment Summary:	ACID STIMULATION 12/16/09 PUMPED 4000 GALS 20% HCI DOWN TUBING

Tubing Size:	2.875 in.	Tubing Setting Depth:	5984 ft.
Tubing Packer Depth:	5766 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6003 ft.	# Of Holes:	196
Interval Bottom:	6465 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 03/31/2023
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