Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06327		Well Classification: ERIW	Status: IJ - 9/25/2025
Well Name/No:	M C HAGOOD A #9 (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	9/25/2025
FacilityID:	229236	LocationID:	314676
County:	RIO BLANCO #103	Location:	SWNE 15 2N103W 6
Field:	RANGELY - #72370	Elevation:	5562 ft.
Basin:	PICEANCE BASIN
Planned Location:	1961FNL 1979 FWL	Lat/Long: 40.144825 / -108.944708	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.144962 / -108.944833	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 9/25/2025 Measured TD: 6700 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 9/25/2025
Wellbore Permit
Permit #:	900048	Expiration Date:	4/19/1990
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	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:	12/21/1947
Spud Date:	10/20/1947	Spud Date Is:	ACTUAL
Measured TD:	6700 ft.	Measured PB depth:	6700 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:	NO NEW LOGS
Log Types:	CEMENT BOND LOG - HARD COPY MAILED WITH FORM 21 4/19/2011
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 611 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 225, Top: 0 ft., Bottom: 611 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6494 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1000, Top: 5150 ft., Bottom: 6494 ft., Determination Method: CBL
Casing:	String Type: 1ST LINER, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 6472 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 305, Top: 5150 ft., Bottom: 6472 ft., Determination Method: CBL
Additional Cement:	String Type: 1ST , Top: 270 ft., Depth: 2514 ft., Bottom: , Sacks: 115, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
MANCOS	0 ft.
NIOBRARA	2615 ft.
FRONTIER	3551 ft.
MOWRY	3810 ft.
DAKOTA	3890 ft.
MORRISON	3988 ft.
CURTIS	4689 ft.
ENTRADA	4790 ft.
NAVAJO	4994 ft.
CHINLE	5610 ft.
MOENKOPI	5810 ft.	6029 ft.	N	N
WEBER	6497 ft.	6700 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 9/25/2025 Interval Top: 6494 ft. Interval Bottom: 6700 ft.

Completed Information for Formation WEBER

1st Production Date:	4/14/2011	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	9/23/2025	Treatment End Date:	9/23/2025
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):	2620
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:	8/5/2025	Treatment End Date:	N/A
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:	1/22/2024	Treatment End Date:	1/22/2024
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):	2700
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:	6/18/2021	Treatment End Date:	6/19/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/MUTUAL SOLVENT, 45 BBLS WATER CONVERTED TO INJECTION 04-14-2011
Total fluid used in treatment (bbls):	140	Max pressure during treatment (psi):	1170
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):	45	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:	6558 ft.
Tubing Packer Depth:	6345 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6494 ft.	# Of Holes:
Interval Bottom:	6700 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