Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06160		Well Classification: ERIW	Status: IJ - 2/20/2025
Well Name/No:	FEE #47 (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	2/20/2025
FacilityID:	229081	LocationID:	314585
County:	RIO BLANCO #103	Location:	NWSW 21 2N102W 6
Field:	RANGELY - #72370	Elevation:	5302 ft.
Basin:	PICEANCE BASIN
Planned Location:	1980FSL 730 FWL	Lat/Long: 40.126665 / -108.855145	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.126719 / -108.855161	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 2/20/2025 Measured TD: 6552 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 2/20/2025
Wellbore Permit
Permit #:	10001	Expiration Date:	2/24/2000
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:
Casing:	String Type: 2ND, Hole Size: , Size: 5.5 in., Top: 0 ft., Depth: 5809 ft., Weight: 17 , Citings Type: PLANNED
Cement:	Sacks: 260, Top: 0 ft., Bottom: 5809 ft.

Wellbore Completed
Completion Date:	8/29/1947
Spud Date:	6/28/1947	Spud Date Is:	ACTUAL
Measured TD:	6552 ft.	Measured PB depth:	6552 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	CBL
Casing:	String Type: CONDUCTOR, Hole Size: 23 in., Size: 16 in., Top: 0 ft., Depth: 46 ft., Weight: 65 , Citings Type: ACTUAL
Cement:	Sacks: 4, Top: 0 ft., Bottom: 46 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 10.75 in., Top: 0 ft., Depth: 710 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 500, Top: 0 ft., Bottom: 710 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 5969 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: 1100 ft., Bottom: 5969 ft., Determination Method: CBL
Casing:	String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 5809 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 303, Top: 0 ft., Bottom: 5809 ft., Determination Method: CALC
Casing:	String Type: 1ST LINER, Hole Size: 7 in., Size: 5 in., Top: 5809 ft., Depth: 6552 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 250, Top: 5809 ft., Bottom: 6552 ft., Determination Method: CALC
Additional Cement:	String Type: 1ST , Top: 4047 ft., Depth: 4154 ft., Bottom: 4089 ft., Sacks: 35, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2290 ft.
FRONTIER	3040 ft.
DAKOTA	3393 ft.		N	N
MORRISON	3460 ft.		N	N
CURTIS	4176 ft.		N	N
ENTRADA	4320 ft.		N	N
CARMEL	4430 ft.		N	N
NAVAJO	4483 ft.		N	N
MOENKOPI	5305 ft.
WEBER	5987 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 2/20/2025 Interval Top: 5980 ft. Interval Bottom: 6526 ft.

Completed Information for Formation WEBER

1st Production Date:	10/30/1976	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	2/19/2025	Treatment End Date:	2/19/2025
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):	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:	1/29/2024	Treatment End Date:	1/29/2024
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH SOLVENT AND 36 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	131	Max pressure during treatment (psi):	2502
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):	36	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:	7/24/2018	Treatment End Date:	7/24/2018
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL, WITH 80 GALLONS MUTUAL SOLVENT AND 133 BBLS FRESH WATER
Total fluid used in treatment (bbls):	182	Max pressure during treatment (psi):	1864
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):	133	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:	2/17/2017	Treatment End Date:	2/17/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL, 120 GALLONS SOLVENT, AND 350 BBLS FRESH WATER
Total fluid used in treatment (bbls):	448	Max pressure during treatment (psi):	1300
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):	350	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:	6/30/2015	Treatment End Date:	6/30/2015
Treatment Summary:	168 gallons solvent with the 4000 gallons 15% at 2.1 bpm @ 2460psi max pressure.
Total fluid used in treatment (bbls):	212	Max pressure during treatment (psi):	2460
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):	113	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:	5866 ft.
Tubing Packer Depth:	5754 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5980 ft.	# Of Holes:	311
Interval Bottom:	6526 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 05/31/2023
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