Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08321		Well Classification: ERIW	Status: IJ - 9/3/2025
Well Name/No:	MCLAUGHLIN, A C #74X (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	9/3/2025
FacilityID:	230653	LocationID:	315339
County:	RIO BLANCO #103	Location:	NWNW 24 2N103W 6
Field:	RANGELY - #72370	Elevation:	5397 ft.
Basin:	PICEANCE BASIN
Planned Location:	1037FNL 1242 FWL	Lat/Long: 40.132925 / -108.909777	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.132990 / -108.909720	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: OW Status: IJ - 9/3/2025 Measured TD: 6662 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: OW IJ - 9/3/2025
Wellbore Permit
Permit #:	840099	Expiration Date:	6/1/1984
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:	5/30/1984
Spud Date:	5/9/1984	Spud Date Is:	ACTUAL
Measured TD:	6662 ft.	Measured PB depth:	6589 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:
Casing:	String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 2805 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 900, Top: 0 ft., Bottom: 2805 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6649 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1480, Top: 0 ft., Bottom: 6649 ft., Determination Method: VISU
Formation	Interval Top	Log Bottom	Cored	DSTs
FRONTIER	3078 ft.	3342 ft.	N	N
MOWRY	3342 ft.	3433 ft.	N	N
DAKOTA	3433 ft.	3505 ft.	N	N
MORRISON	3505 ft.	4218 ft.	N	N
CURTIS	4218 ft.	4314 ft.	N	N
ENTRADA	4314 ft.	4460 ft.	N	N
CARMEL	4460 ft.	4511 ft.	N	N
NAVAJO	4511 ft.	5148 ft.	N	N
CHINLE	5148 ft.	5266 ft.	N	N
SHINARUMP	5266 ft.	5340 ft.	N	N
MOENKOPI	5340 ft.	6014 ft.	N	N
WEBER	6014 ft.	6662 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 9/3/2025 Interval Top: 6038 ft. Interval Bottom: 6549 ft.

Completed Information for Formation WEBER

1st Production Date:	7/3/1984	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/25/2025	Treatment End Date:	8/25/2025
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/solvent and 43 bbls fresh water.
Total fluid used in treatment (bbls):	138	Max pressure during treatment (psi):	2285
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):	43	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:	12/17/2024	Treatment End Date:	12/17/2024
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/solvent and 90 bbls fresh water.
Total fluid used in treatment (bbls):	182	Max pressure during treatment (psi):	700
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	92	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	90	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:	4/25/2024	Treatment End Date:	4/25/2024
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):	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:	3/1/2023	Treatment End Date:	3/1/2023
Treatment Summary:	Pumped 4000 gallons (95.2 bbl) 15% HCL w/inhibitor and 35 bbl 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:	3/22/2022	Treatment End Date:	3/22/2022
Treatment Summary:	Pulled tubing and top FH packer due to UIC failure this injection well was shut in 10/14/2021. Test casing from 5984’ to surface to 1200 psi with no leakoff. Attempt injection into downhole packer and mandrel isolation system, with no success. Fished three packers and associated tubing and mandrels down to 6451’ to allow for injection into perforations. Performed 4000 gal (95.2BBLS) 15% HCl with 6% citric acid treatment AND 92 BBLS water on perforations. Ran a new Lokset packer, On/off tool, PS1 Packer and new fiberlined tubing into well with bottom packer set at 5952’ (86’ above top perf). Tested casing to 1200 psi for 30 minutes and tubing to 2500 psi with no communication.
Total fluid used in treatment (bbls):	187	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):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	92	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:	7/10/2019	Treatment End Date:	7/10/2019
Treatment Summary:	PUMPED 1850 GALLONS (44 BBLS) 15% HCL w/ 3% CITRIC ACID AND 60 BBLS WATER.
Total fluid used in treatment (bbls):	104	Max pressure during treatment (psi):	1945
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	44	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		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:	12/22/2017	Treatment End Date:	12/22/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL WITH 140 BBLS WATER
Total fluid used in treatment (bbls):	235	Max pressure during treatment (psi):	850
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):	140	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:	3/27/2015	Treatment End Date:	3/27/2015
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	165	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):	70	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	4/14/2011
Treatment Summary:	ACID STIMULATION WITH 4000 GALLONS 20% HCL THROUGH END OF COILED TUBING AT 6153'
Formation Treatment
Treatment Date:	10/15/2009
Treatment Summary:	ACID STIMULATION 10/16/09 PUMPED 4000 GALLONS OF 20% HCI

Tubing Size:	2.875 in.	Tubing Setting Depth:	5989 ft.
Tubing Packer Depth:	5923 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6038 ft.	# Of Holes:	138
Interval Bottom:	6549 ft.	Hole Size:	0.5 in.

All Designations		Date
Primary Well Designation: None i
Reported Plugged	N
Out Of Service Repurposed	N
Out Of Service	N
Inactive Exception	N
Noticed Inactive	N
Defined Inactive	N
Low Producing	N

November 2024 - October 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