Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08301		Well Classification: ERIW	Status: IJ - 6/27/2025
Well Name/No:	MCLAUGHLIN, A C #70X (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	6/27/2025
FacilityID:	230633	LocationID:	315325
County:	RIO BLANCO #103	Location:	SWSE 13 2N103W 6
Field:	RANGELY - #72370	Elevation:	5409 ft.
Basin:	PICEANCE BASIN
Planned Location:	229FSL 2437 FEL	Lat/Long: 40.136385 / -108.904137	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.136450 / -108.904030	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 6/27/2025 Measured TD: 6674 ft. Vertical TD: 6674 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 6/27/2025
Wellbore Permit
Permit #:	830544	Expiration Date:	10/4/1983
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:	D-032675A
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	4/30/1985
Measured TD:	6674 ft.	Measured PB depth:	6649 ft.
True Vertical TD:	6674 ft.	True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 9.625 in., Top: 0 ft., Depth: 2986 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6665 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3524 ft.
MORRISON	3595 ft.
ENTRADA	4435 ft.
NAVAJO	4611 ft.
CHINLE	5246 ft.
WEBER	6129 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 6/27/2025 Interval Top: 6140 ft. Interval Bottom: 6524 ft.

Completed Information for Formation WEBER

1st Production Date:	4/23/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	6/26/2025	Treatment End Date:	6/26/2025
Treatment Summary:	Pumped 2000 gallons (47.6 BBLS) 15% HCL w/solvent and 35 BBLS Fresh water.
Total fluid used in treatment (bbls):	83	Max pressure during treatment (psi):	2333
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):	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:	12/12/2024	Treatment End Date:	12/13/2024
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 80 BBLS FRESH WATER
Total fluid used in treatment (bbls):	128	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):	48	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	0	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:	5/23/2024	Treatment End Date:	5/23/2024
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 35 BBLS FRESH WATER
Total fluid used in treatment (bbls):	83	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):	48	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:	2/18/2021	Treatment End Date:	2/18/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/6% CITRIC ACID WTIH MUTUAL SOLVENT AND 47 BBLS WATER
Total fluid used in treatment (bbls):	95	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):	48	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	47	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	6/7/2010
Treatment Summary:	ACID STIMULATION 06/07/2010 PUMPED 4000 GALLONS OF HEATED 20% HCI THROUGH 1.25" COILED TUBING AT 6340-6391 AT STARTING PRESSURE OF 1400 PSI
Formation Treatment
Treatment Date:	7/14/2009
Treatment Summary:	ACID STIMULATION 7-14-2009 PUMPED 4000 GALLONS OF HEATED 20% HCL THROUGH SIE AT 6545' SIE (SPECIALIZED INJECTION EQUIPMENT).

Tubing Size:	2.875 in.	Tubing Setting Depth:	6550 ft.
Tubing Packer Depth:	6071 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6140 ft.	# Of Holes:	111
Interval Bottom:	6524 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