Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06330		Well Classification: ERIW	Status: IJ - 11/12/2025
Well Name/No:	HAGOOD M C #A-3 (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	11/12/2025
FacilityID:	229239	LocationID:	314678
County:	RIO BLANCO #103	Location:	NWNE 15 2N103W 6
Field:	RANGELY - #72370	Elevation:	5560 ft.
Basin:	PICEANCE BASIN
Planned Location:	660FNL 2030 FEL	Lat/Long: 40.148394 / -108.940268	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.148530 / -108.940310	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 11/12/2025 Measured TD: 6673 ft. Vertical TD: 6673 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 11/12/2025
Wellbore Permit
Permit #:	011238	Expiration Date:	6/26/2002
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: 2-38 , Unit Acreage: , Drill Unit:
Casing:	String Type: SURF, Hole Size: , Size: 13.375 in., Top: , Depth: 373 ft., Weight: 40 , Citings Type: PLANNED
Cement:	Sacks: 270, Top: 0 ft., Bottom: 373 ft.
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: , Depth: 3810 ft., Weight: 23 , Citings Type: PLANNED
Cement:	Sacks: , Top: 0 ft., Bottom: 3810 ft.

Wellbore Completed
Completion Date:	4/5/2002
Spud Date:	3/5/2002	Spud Date Is:	ACTUAL
Measured TD:	6673 ft.	Measured PB depth:
True Vertical TD:	6673 ft.	True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:	NO NEW LOGS
Casing:	String Type: SURF, Hole Size: , Size: 13.375 in., Top: 0 ft., Depth: 373 ft., Weight: 40 , Citings Type: ACTUAL
Cement:	Sacks: 270, Top: , Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6538 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 2ND, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 5567 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: , Top: , Bottom: , Determination Method:
Casing:	String Type: 3RD, Hole Size: , Size: 7 in., Top: 5567 ft., Depth: 6539 ft., Weight: 20 , Citings Type: ACTUAL
Cement:	Sacks: 900, Top: , Bottom: , Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5.5 in., Top: 0 ft., Depth: 6448 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 270, Top: , Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2620 ft.	2800 ft.	N	N
FRONTIER	3572 ft.		N	N
MOWRY	3825 ft.		N	N
DAKOTA	3904 ft.		N	N
MORRISON	4000 ft.		N	N
CURTIS	4718 ft.		N	N
ENTRADA	4820 ft.		N	N
CARMEL	4962 ft.		N	N
NAVAJO	5019 ft.		N	N
CHINLE	5655 ft.		N	N
SHINARUMP	5752 ft.		N	N
MOENKOPI	5855 ft.	6075 ft.	N	N
WEBER	6535 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 11/12/2025 Interval Top: 6448 ft. Interval Bottom: 6539 ft.

Completed Information for Formation WEBER

1st Production Date:	5/25/1947	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	11/10/2025	Treatment End Date:	11/10/2025
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):	2500
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:	3/21/2025	Treatment End Date:	3/21/2025
Treatment Summary:	PUMPED 4000 GALLONS (95 BBLS) 15% HCL WITH SOLVENT AND 35 BBLS FRESH WATER
Total fluid used in treatment (bbls):	130	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):	95	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:	5/16/2022	Treatment End Date:	5/16/2022
Treatment Summary:	PUMPED 4000 GALLONS (95 BBLS) 15% HCL WITH SOLVENT AND 35 BBLS FRESH WATER
Total fluid used in treatment (bbls):	130	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):	95	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:	4/4/2020	Treatment End Date:	4/4/2020
Treatment Summary:	PUMPED 4000 GALLONS (95 BBLS) 15% HCL WITH SOLVENT AND 38 BBLS FRESH WATER
Total fluid used in treatment (bbls):	133	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):	95	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:	5/15/2014	Treatment End Date:	5/15/2014
Treatment Summary:	ACID STIMULATION
Total fluid used in treatment (bbls):		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):	50	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:	7/6/2012	Treatment End Date:	7/6/2012
Treatment Summary:	ACID STIMULATION 7/6/2012 PUMPED 4000 GALLONS 15% HCL AT 3.7 BPM @ 1400 PSI
Total fluid used in treatment (bbls):		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):	50	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	7/29/2010
Treatment Summary:	ACID STIMULATION 7/29/2010 PUMPED 4000GALLONS OF 20% HCI THROUGH TUBING AT 6444.2 AT 2.5 BPM@660PSI.'
Formation Treatment
Treatment Date:	2/8/2008
Treatment Summary:	ACIDIZE FORMATION WITH 4015 GALLONS HEATED 15% HCL, EOT @ 6360

Tubing Size:	2.875 in.	Tubing Setting Depth:	6444 ft.
Tubing Packer Depth:	6331 ft.	Tubing Multiple Packer:
Open Hole Top:	6448 ft.	Open Hole Bottom:	6539 ft.
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6448 ft.	# Of Holes:
Interval Bottom:	6539 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