Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08035		Well Classification: ERIW	Status: IJ - 9/2/2025
Well Name/No:	GRAY #A-20X (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	9/2/2025
FacilityID:	230373	LocationID:	315180
County:	RIO BLANCO #103	Location:	NESE 24 2N103W 6
Field:	RANGELY - #72370	Elevation:	5353 ft.
Basin:	PICEANCE BASIN
Planned Location:	2570FSL 125 FEL	Lat/Long: 40.128215 / -108.895927	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.128340 / -108.895760	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 9/2/2025 Measured TD: 6603 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 9/2/2025
Wellbore Permit
Permit #:	10001	Expiration Date:	9/30/1977
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:	D-032703A
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	10/25/1977
Spud Date:	8/22/1977	Spud Date Is:	ACTUAL
Measured TD:	6603 ft.	Measured PB depth:	6560 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: 40 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: 0 ft., Bottom: 40 ft., Determination Method:
Casing:	String Type: SURF, Hole Size: , Size: 9.625 in., Top: 0 ft., Depth: 758 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 425, Top: 0 ft., Bottom: 758 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 9.625 in., Size: 7 in., Top: 0 ft., Depth: 6603 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 550, Top: 3040 ft., Bottom: 6603 ft., Determination Method: CBL
Casing:	String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 5855 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 288, Top: 0 ft., Bottom: 5855 ft., Determination Method: VISU
Additional Cement:	String Type: 1ST , Top: 0 ft., Depth: 794 ft., Bottom: 808 ft., Sacks: 90, Method: SQUEEZE
Additional Cement:	String Type: 1ST , Top: , Depth: 4725 ft., Bottom: , Sacks: 55, Method: SQUEEZE
Additional Cement:	String Type: 1ST , Top: , Depth: 4074 ft., Bottom: , Sacks: 50, Method: SQUEEZE
Additional Cement:	String Type: 1ST , Top: , Depth: 5066 ft., Bottom: , Sacks: 85, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2202 ft.
FRONTIER	2960 ft.
MOWRY	3225 ft.
DAKOTA	3314 ft.		N	N
MORRISON	3388 ft.		N	N
CURTIS	4088 ft.		N	N
ENTRADA	4189 ft.		N	N
CARMEL	4334 ft.		N	N
NAVAJO	4392 ft.		N	N
CHINLE	5137 ft.		N	N
MOENKOPI	5137 ft.		N	N
SHINARUMP	5215 ft.		N	N
WEBER	5887 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 9/2/2025 Interval Top: 5907 ft. Interval Bottom: 6510 ft.

Completed Information for Formation WEBER

1st Production Date:	10/28/1977	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/20/2025	Treatment End Date:	8/20/2025
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 65 bbls fresh water
Total fluid used in treatment (bbls):	112	Max pressure during treatment (psi):	2267
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):	65	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:	11/15/2024	Treatment End Date:	11/15/2024
Treatment Summary:	Pumped 47.6 bbls 15% HCL w/solvent and 33 bbls fresh water
Total fluid used in treatment (bbls):	80	Max pressure during treatment (psi):	2222
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):	33	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:	7/12/2021	Treatment End Date:	7/12/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/MUTUAL SOLVENT, 40 BBLS WATER
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	1860
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:	1/29/2021	Treatment End Date:	1/29/2021
Treatment Summary:	PUMPED 114 BBLS 15% HCL AND 38 BBLS OF WATER
Total fluid used in treatment (bbls):	152	Max pressure during treatment (psi):	902
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	114	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	38	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:	10/28/2013	Treatment End Date:	10/28/2013
Treatment Summary:	ACID STIMULATION WITH 4000 GALLONS 15% HCL AT 0.8 BBL PER MIN AT 1000 PSI.
Total fluid used in treatment (bbls):	95	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):		Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	4/22/2011
Treatment Summary:	ACID STIMULATION WITH 20 % HCL THROUGH END OF COILED TUBING @6493'
Formation Treatment
Treatment Date:	12/18/2008
Treatment Summary:	ACIDIZE FORMATION W/ 4000 GAL HEATED 15% HCL, EOT @ 5825

Tubing Size:	2.875 in.	Tubing Setting Depth:	5864 ft.
Tubing Packer Depth:	5777 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5907 ft.	# Of Holes:	341
Interval Bottom:	6510 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