Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-05763		Well Classification: ERIW	Status: IJ - 11/24/2025
Well Name/No:	MCLAUGHLIN, A C #24 (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	11/24/2025
FacilityID:	228779	LocationID:	314465
County:	RIO BLANCO #103	Location:	NWNW 23 2N103W 6
Field:	RANGELY - #72370	Elevation:	5504 ft.
Basin:	PICEANCE BASIN
Planned Location:	660FNL 660 FWL	Lat/Long: 40.133955 / -108.930598	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.133950 / -108.930670	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 11/24/2025 Measured TD: 6690 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 11/24/2025
Wellbore Permit
Permit #:	10001	Expiration Date:	3/7/1978
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:	D-032675
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	2/18/1978
Measured TD:	6690 ft.	Measured PB depth:	0 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Casing:	String Type: SURF, Hole Size: , Size: 10.75 in., Top: 0 ft., Depth: 755 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 500, Top: 0 ft., Bottom: 755 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6208 ft., Weight: 26 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: 0 ft., Bottom: 6208 ft., Determination Method: CALC
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5.5 in., Top: 6015 ft., Depth: 6690 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 150, Top: 0 ft., Bottom: 6690 ft., Determination Method: CALC

Formation WEBR Formation Classification: ERIW Status: IJ - 11/24/2025 Interval Top: 6224 ft. Interval Bottom: 6654 ft.

Completed Information for Formation WEBER

1st Production Date:	2/18/1978	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	11/20/2025	Treatment End Date:	11/20/2025
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT AND 37 BBLS FRESH WATER
Total fluid used in treatment (bbls):	132	Max pressure during treatment (psi):	2476
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):	37	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	8/21/2025	Treatment End Date:	N/A
Treatment Summary:	WELLWORK TO CLEAN OUT, REPLACED TUBING AND PACKER, AND UPGRADED COMPLETE WELLHEAD. OPERATIONS SUMMARY AND WBD ATTACHED. RETURN TO INJECTION PENDING AN APPROVED FORM 21. Converted to injection 2/18/1978
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):		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 Type:	ACID JOB
Treatment Date:	6/13/2025	Treatment End Date:	6/13/2025
Treatment Summary:	Pumped 1000 gallons (23.8 bbls) 15% HCL w/solvent and 50 bbls fresh water.
Total fluid used in treatment (bbls):	73	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):	23	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	55	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:	12/15/2023	Treatment End Date:	12/15/2023
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:	10/7/2022	Treatment End Date:	10/7/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/MUTUAL SOLVENT AND 35 BBLS WATER.
Total fluid used in treatment (bbls):	130	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):	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:	12/16/2021	Treatment End Date:	12/17/2021
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15%HCL w/ 6% Citric Acid and 65 bbls Water.
Total fluid used in treatment (bbls):	112	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):	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:	3/26/2021	Treatment End Date:	3/26/2021
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15%HCL w/ 6% Citric Acid and 40 bbls Water.
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	1820
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):	87	Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	6/14/2019	Treatment End Date:	6/14/2019
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BLLS) OF 15% HCL WITH 80 BBLS OF FRESH WATER
Total fluid used in treatment (bbls):	175	Max pressure during treatment (psi):	1330
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):	80	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:	6/30/2016	Treatment End Date:	6/30/2016
Treatment Summary:	Pumped 2 bbls solvent, 47.6 bbls 15% HCl, and 175 bbls water at starting rate 2.8 bpm @ 2470 psi.
Total fluid used in treatment (bbls):	225	Max pressure during treatment (psi):	2470
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	48	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	175	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	8/8/2011
Treatment Summary:	ACID STIMULATION - PUMPED 3000 GALLONS OF 20% HCL THROUGH END OF COILED TUBING AT 6336' ATA A STARTING PRESSURE OF 300 PSI @ 1.1 BPM.
Formation Treatment
Treatment Date:	8/18/2010
Treatment Summary:	ACID STIMULATION 8/18/2010 PUMPED 3000 GALLONS FO 20% HCL THROUGH END OF TUBING 6336 AT STARTING PRESSURE OF 1600 1 BPM.
Formation Treatment
Treatment Date:	11/7/2007
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS 15% HCI, EOT @ 6340'.

Tubing Size:	2.875 in.	Tubing Setting Depth:	5956 ft.
Tubing Packer Depth:	5911 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6224 ft.	# Of Holes:	294
Interval Bottom:	6654 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