Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06328		Well Classification: ERIW	Status: IJ - 12/2/2025
Well Name/No:	HAGOOD M C #A-1 (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 #:
Facility Status:	IJ	Status Date	12/2/2025
FacilityID:	229237	LocationID:	314677
County:	RIO BLANCO #103	Location:	NESW 15 2N103W 6
Field:	RANGELY - #72370	Elevation:	5576 ft.
Basin:	PICEANCE BASIN
Planned Location:	0FL 0 FL	Lat/Long: 40.141235 / -108.944718	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.141360 / -108.944820	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 12/2/2025 Measured TD:

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 12/2/2025
Wellbore Permit
Permit #:	012042	Expiration Date:	11/25/2002
Proposed Depth/Form:
Surface Mineral Owner Same:	Yes
Mineral Owner:	FEDERAL	Surface Owner:	FEDERAL
Unit:		Unit Number:
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: , Unit Acreage: , Drill Unit:

Wellbore Completed
Completion Date:	12/21/1946
Spud Date:	8/4/1946	Spud Date Is:	ACTUAL
Measured TD:		Measured PB depth:	6719 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Bottom Hole Location:	Sec: Twp:	Footage: FL FL
Log Types:	NO NEW LOGS
Casing:	String Type: SURF, Hole Size: , Size: 13.375 in., Top: 0 ft., Depth: 375 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 250, Top: , Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: , Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: , Bottom: , Determination Method:
Casing:	String Type: 2ND, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 3557 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: , Top: , Bottom: , Determination Method:
Casing:	String Type: 3RD, Hole Size: , Size: 7 in., Top: 3557 ft., Depth: 6460 ft., Weight: 20 , Citings Type: ACTUAL
Cement:	Sacks: 1000, Top: , Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOB-FT HYS-CODELL-SUSSEX	2630 ft.	2800 ft.	N	N
FRONTIER	3534 ft.		N	N
MOWRY	3620 ft.		N	N
DAKOTA	3797 ft.		N	N
MORRISON	3887 ft.		N	N
CURTIS	3976 ft.		N	N
ENTRADA	4679 ft.		N	N
CARMEL	4775 ft.		N	N
NAVAJO	4923 ft.		N	N
CHINLE	5610 ft.		N	N
SHINARUMP	5719 ft.		N	N
MOENKOPI	5792 ft.	6010 ft.	N	N
WEBER	6466 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 12/2/2025 Interval Top: 6460 ft. Interval Bottom: 6719 ft.

Completed Information for Formation WEBER

1st Production Date:	10/8/2002	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	12/1/2025	Treatment End Date:	12/1/2025
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):	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:	ACID JOB
Treatment Date:	6/16/2025	Treatment End Date:	6/16/2025
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):	2450
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:	7/22/2024	Treatment End Date:	7/22/2024
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 30 bbls fresh water
Total fluid used in treatment (bbls):	77	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):	30	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:	9/5/2023	Treatment End Date:	9/5/2023
Treatment Summary:	PUMPED 47.6 BBLS 15% HCL W/SOLVENT AND 35 BBLS FRESH WATER Converted to injection 10/08/2002
Total fluid used in treatment (bbls):	82	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):	47	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:	11/12/2021	Treatment End Date:	11/12/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT AND 45 BBLS WATER CONVERTED TO INJECITON 10/08/2002
Total fluid used in treatment (bbls):		Max pressure during treatment (psi):	1800
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):	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:	8/14/2021	Treatment End Date:	8/15/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT AND 130 BBLS WATER CONVERTED TO INJECITON 10/08/2002
Total fluid used in treatment (bbls):	225	Max pressure during treatment (psi):	1950
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):	130	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:	12/29/2017	Treatment End Date:	12/29/2017
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 80 BBLS WATER.
Total fluid used in treatment (bbls):	127	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):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	80	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	12/21/1946
Treatment Summary:	ACID STIMULATION 11/10/2005 PUMPED 3000 GALLONS 15% HCL THROUGH TUBING.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6486 ft.
Tubing Packer Depth:	6171 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6460 ft.	# Of Holes:
Interval Bottom:	6719 ft.	Hole Size:

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