Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06420		Well Classification: ERIW	Status: IJ - 9/25/2025
Well Name/No:	MCLAUGHLIN, A C #56X (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	9/25/2025
FacilityID:	229319	LocationID:	314697
County:	RIO BLANCO #103	Location:	SESW 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5478 ft.
Basin:	PICEANCE BASIN
Planned Location:	1315FSL 1370 FWL	Lat/Long: 40.139375 / -108.928058	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.139490 / -108.928130	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 9/25/2025 Measured TD: 6588 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 9/25/2025
Wellbore Permit
Permit #:	10001	Expiration Date:	2/5/1967
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:	D-023675
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	2/8/1985
Measured TD:	6588 ft.	Measured PB depth:	6578 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: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 693 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 450, Top: 0 ft., Bottom: 693 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 9 in., Size: 7 in., Top: 0 ft., Depth: 6260 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 625, Top: , Bottom: 6260 ft., Determination Method:
Casing:	String Type: OPEN HOLE, Hole Size: 9 in., Size: , Top: 6260 ft., Depth: 6588 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: , Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3642 ft.
MORRISON	3742 ft.
CURTIS	4442 ft.
ENTRADA	4543 ft.
CARMEL	4687 ft.
NAVAJO	4748 ft.
CHINLE	5380 ft.
SHINARUMP	5479 ft.
MOENKOPI	5538 ft.
WEBER	6259 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 9/25/2025 Interval Top: 6260 ft. Interval Bottom: 6578 ft.

Completed Information for Formation WEBER

1st Production Date:	1/28/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	9/24/2025	Treatment End Date:	9/24/2025
Treatment Summary:	PUMPED 2000 GALLONS (45.6 BBLS) 15% HCL w/SOLVENT AND 35 BBLS PRODUCED WATER NOTE: 100 % PRODUCED WATER USED PER NEW RULES
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):	0	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:	11/13/2024	Treatment End Date:	11/13/2024
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS ) 15% HCL W/SOLVENT AND 33 BBLS FRESH WATER
Total fluid used in treatment (bbls):	84	Max pressure during treatment (psi):	1726
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):	33	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:	2/1/2023	Treatment End Date:	2/1/2023
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBL.) 15% HCL W/ MUTUAL SOLVENT AND 25 BBL. FRESH WATER.
Total fluid used in treatment (bbls):	73	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):	25	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:	10/1/2020	Treatment End Date:	10/1/2020
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL/6%CITRIC ACID AND 2.8 BBLS WLC-603 INHIBITOR, 50 BBLS FRESH WATER
Total fluid used in treatment (bbls):	145	Max pressure during treatment (psi):	1600
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:	8/15/2015	Treatment End Date:	8/15/2015
Treatment Summary:	Pumped 4000 gallons 15% HCl with 165 gallons Musol solvent
Total fluid used in treatment (bbls):	299	Max pressure during treatment (psi):	600
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):	200	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	4/13/2011
Treatment Summary:	ACID STIMULATION 4/13/2011 PUMPED 4000 GALLONS 20% HCL THROUGH TUBING AT 6305'
Formation Treatment
Treatment Date:	5/1/2009
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS HEATED 20% HCI, EOT @ 6549'

Tubing Size:	2.875 in.	Tubing Setting Depth:	6116 ft.
Tubing Packer Depth:	6028 ft.	Tubing Multiple Packer:
Open Hole Top:	6260 ft.	Open Hole Bottom:	6578 ft.
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6260 ft.	# Of Holes:
Interval Bottom:	6578 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