Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-05721		Well Classification: ERIW	Status: IJ - 4/24/2025
Well Name/No:	HAGOOD L N #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 #:	47443
Facility Status:	IJ	Status Date	4/24/2025
FacilityID:	228744	LocationID:	314449
County:	RIO BLANCO #103	Location:	NESE 23 2N103W 6
Field:	RANGELY - #72370	Elevation:	5448 ft.
Basin:	PICEANCE BASIN
Planned Location:	1980FSL 660 FEL	Lat/Long: 40.126665 / -108.916607	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.126730 / -108.916550	Lat/Long Source: Field Measured


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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 4/24/2025 Measured TD:

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 4/24/2025
Wellbore Permit
Permit #:	440000	Expiration Date:	1/1/1901
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:	N/A
Measured TD:		Measured PB depth:
True Vertical TD:		True Vertical PB depth:
Casing:	String Type: CONDUCTOR, Hole Size: , Size: 16 in., Top: 0 ft., Depth: 65 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 103, Top: 0 ft., Bottom: 65 ft., Determination Method:
Casing:	String Type: SURF, Hole Size: , Size: 10.75 in., Top: 0 ft., Depth: 2031 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 400, Top: 0 ft., Bottom: 2031 ft., Determination Method:
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 5965 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 700, Top: , Bottom: 5965 ft., Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5 in., Top: 5890 ft., Depth: 6548 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 100, Top: 5890 ft., Bottom: 6548 ft., Determination Method:
Casing:	String Type: 2ND LINER, Hole Size: , Size: 5.5 in., Top: 0 ft., Depth: 5890 ft., Weight: 14 , Citings Type: ACTUAL
Cement:	Sacks: , Top: , Bottom: 5890 ft., Determination Method:

Formation WEBR Formation Classification: ERIW Status: IJ - 4/24/2025 Interval Top: 5973 ft. Interval Bottom: 6496 ft.

Completed Information for Formation WEBER

1st Production Date:	11/16/2000	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	4/23/2025	Treatment End Date:	4/23/2025
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 39 bbls fresh water.
Total fluid used in treatment (bbls):	86	Max pressure during treatment (psi):	2187
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):	39	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:	2/17/2025	Treatment End Date:	2/17/2025
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):	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:	11/7/2023	Treatment End Date:	11/7/2023
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) WITH 15% HCL w/SOLVENT AND 40 BBLS OF WATER.
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	2464
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):	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:	1/24/2023	Treatment End Date:	1/24/2023
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) and 15% HCL w/additives, inhibitor, mutual 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):		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:	8/13/2021	Treatment End Date:	8/13/2021
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL with Solvent. Converted to injection 11/16/2000
Total fluid used in treatment (bbls):	47	Max pressure during treatment (psi):	1200
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):		Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	5/2/2012
Treatment Summary:	ACID STIMULATION WITH 3000 GALLONS OF 20% HCL THROUGH END OF COILED TUBING AT 6499' AT 1.0 BPM @ 1000 PSI.
Formation Treatment
Treatment Date:	4/13/2009
Treatment Summary:	ACID STIMULATION 04-13-09 PUMPED 4000 GALLONS 20% HCL, BULLHEAD AT 2.4 BPM AND 797 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6371 ft.
Tubing Packer Depth:	5854 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5973 ft.	# Of Holes:	600
Interval Bottom:	6496 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