Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06425		Well Classification: ERIW	Status: IJ - 12/3/2025
Well Name/No:	MCLAUGHLIN, A C #52X (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	12/3/2025
FacilityID:	229324	LocationID:	314698
County:	RIO BLANCO #103	Location:	SWNW 23 2N103W 6
Field:	RANGELY - #72370	Elevation:	5504 ft.
Basin:	PICEANCE BASIN
Planned Location:	1320FNL 1220 FWL	Lat/Long: 40.132145 / -108.928618	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.132266 / -108.928670	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 12/3/2025 Measured TD: 6700 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 12/3/2025
Wellbore Permit
Permit #:	660263	Expiration Date:	4/10/1980
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:	7/22/1966
Spud Date:	7/20/1966	Spud Date Is:	ACTUAL
Measured TD:	6700 ft.	Measured PB depth:	6680 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:	LOGS PREVIOUSLY SUBMITTED
Log Types:
Casing:	String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 721 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 450, Top: 0 ft., Bottom: 721 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 9 in., Size: 7 in., Top: 0 ft., Depth: 6180 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 625, Top: 0 ft., Bottom: 6180 ft., Determination Method: CALC
Casing:	String Type: 1ST LINER, Hole Size: 7 in., Size: 5.5 in., Top: 6097 ft., Depth: 6699 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 330, Top: 6097 ft., Bottom: 6699 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
FRONTIER	3236 ft.	3504 ft.	N	N
MOWRY	3504 ft.	3584 ft.	N	N
DAKOTA	3584 ft.	3698 ft.	N	N
MORRISON	3698 ft.	4380 ft.	N	N
CURTIS	4380 ft.	4480 ft.	N	N
ENTRADA	4480 ft.	4622 ft.	N	N
CARMEL	4622 ft.	4680 ft.	N	N
NAVAJO	4680 ft.	5310 ft.	N	N
CHINLE	5310 ft.	5420 ft.	N	N
SHINARUMP	5420 ft.	5503 ft.	N	N
MOENKOPI	5503 ft.	6175 ft.	N	N
WEBER	6175 ft.	6700 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 12/3/2025 Interval Top: 6197 ft. Interval Bottom: 6640 ft.

Completed Information for Formation WEBER

1st Production Date:	5/19/1986	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	12/2/2025	Treatment End Date:	12/2/2025
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:	6/23/2025	Treatment End Date:	6/23/2025
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT AND 60 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	155	Max pressure during treatment (psi):	1700
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):	60	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:	5/17/2024	Treatment End Date:	5/17/2024
Treatment Summary:	PUPMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 70 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	118	Max pressure during treatment (psi):	2600
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):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	70	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:	8/7/2023	Treatment End Date:	8/7/2023
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/inhibitor and 40 bbls fresh water
Total fluid used in treatment (bbls):	88	Max pressure during treatment (psi):	2487
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):	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:	8/2/2022	Treatment End Date:	8/2/2022
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL with mutual solvent and 35 bbls water.
Total fluid used in treatment (bbls):	83	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):	48	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:	8/18/2021	Treatment End Date:	8/18/2021
Treatment Summary:	PUMPED 2000 GALLONS 47.6 BBLS 15% HCL W/6% CITRIC ACID AND 120 BBLS WATER
Total fluid used in treatment (bbls):	167	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	120	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:	9/16/2020	Treatment End Date:	9/17/2020
Treatment Summary:	PUMPED 2000 GALLONS 47.6 BBLS 15% HCL W/6% CITRIC ACID AND 80 BBLS POTABLE WATER
Total fluid used in treatment (bbls):	127	Max pressure during treatment (psi):	1900
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 Type:	ACID JOB
Treatment Date:	2/2/2019	Treatment End Date:	2/2/2019
Treatment Summary:	ACID STIMULATION WITH 2000 GALLONS 15% HCL, 30 BBLS SOLVENT AND 105 BBLS FRESH WATER. STARTING AT 4.0 BPM AT 2140 PSI.
Total fluid used in treatment (bbls):	183	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):	48	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	105	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:	8/16/2017	Treatment End Date:	8/16/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL WITH 155 GALLONS ADDITIVES, 160 BBLS WATER
Total fluid used in treatment (bbls):	259	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):	160	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	3/12/2012
Treatment Summary:	ACID STIMULATION WITH 4000 GALLONS 15% HCL
Formation Treatment
Treatment Date:	3/29/2011
Treatment Summary:	ACID STIMULATION 3/29/2011 PUMPED 3100 GALLONS 20% HCL THROUGH COILED TUBING AT 6186' @ .5 BBLS PER MIN AT A MAX PRESSURE OF 1800 PSI.
Formation Treatment
Treatment Date:	8/7/2009
Treatment Summary:	ACID STIMULATION 8/7/09 PUMPED 2000 GALS 20% HCI 10,500 GALS CHLORINE DIOXIDE IN FOUR STAGES THROUGH TUBING AT 6660.0 AVERAGE 4.2 BPM @ 2216 PSI

Tubing Size:	2.875 in.	Tubing Setting Depth:	6660 ft.
Tubing Packer Depth:	5967 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6197 ft.	# Of Holes:	87
Interval Bottom:	6640 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