Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-01055		Well Classification: ERIW	Status: IJ - 9/3/2025
Well Name/No:	MCLAUGHLIN, A C #22 (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:	228137	LocationID:	314261
County:	RIO BLANCO #103	Location:	SESW 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5453 ft.
Basin:	PICEANCE BASIN
Planned Location:	660FSL 1980 FWL	Lat/Long: 40.137575 / -108.925868	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.137620 / -108.925910	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 9/3/2025 Measured TD: 6695 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 9/3/2025
Wellbore Permit
Permit #:	10001	Expiration Date:	2/5/1972
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:	11/23/1977
Spud Date:	8/8/1946	Spud Date Is:	ACTUAL
Measured TD:	6695 ft.	Measured PB depth:	6690 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:
Casing:	String Type: CONDUCTOR, Hole Size: 18.75 in., Size: 16 in., Top: 0 ft., Depth: 37 ft., Weight: 55 , Citings Type: ACTUAL
Cement:	Sacks: 65, Top: 0 ft., Bottom: 37 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 10.75 in., Top: 0 ft., Depth: 990 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 500, Top: 0 ft., Bottom: 990 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6205 ft., Weight: 23/26 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: 2290 ft., Bottom: 6205 ft., Determination Method: CALC
Casing:	String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 5987 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 294, Top: 0 ft., Bottom: 5987 ft., Determination Method: VISU
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5 in., Top: 5987 ft., Depth: 6690 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 450, Top: 5987 ft., Bottom: 6690 ft., Determination Method:
Casing:	String Type: TAPER, Hole Size: 7 in., Size: 5 in., Top: 5987 ft., Depth: 6690 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 450, Top: 5987 ft., Bottom: 6690 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3595 ft.		N	N
MORRISON	3701 ft.		N	N
CURTIS	4391 ft.		N	N
ENTRADA	4487 ft.		N	N
CARMEL	4627 ft.		N	N
NAVAJO	4680 ft.		N	N
CHINLE	5322 ft.		N	N
SHINARUMP	5435 ft.		N	N
MOENKOPI	5515 ft.		N	N
WEBER	6192 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 9/3/2025 Interval Top: 6220 ft. Interval Bottom: 6669 ft.

Completed Information for Formation WEBER

1st Production Date:	11/25/1977	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:

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):	2150
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:	5/20/2024	Treatment End Date:	5/20/2024
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT AND 39 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	134	Max pressure during treatment (psi):	2485
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):	39	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:	8/8/2023	Treatment End Date:	8/8/2023
Treatment Summary:	Pumped 4000 gallons (95.2 bbls ) 15% HCL with 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):		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:	10/5/2022	Treatment End Date:	10/5/2022
Treatment Summary:	PUMP 4000 GALLONS (95.2 BBLS) 15% HCL WITH 35 BBLS FRESH WATER
Total fluid used in treatment (bbls):	130	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):	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:	10/16/2021	Treatment End Date:	10/16/2021
Treatment Summary:	PUMP 2000 GALLONS (47.6 BBLS) 15% HCL WITH 38 BBLS FRESH WATER
Total fluid used in treatment (bbls):	85	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	38	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	10/11/2021	Treatment End Date:	N/A
Treatment Summary:	High casing pressure was found on AC McLaughlin 22 and the well was shut in. Wellwork was completed, ran 5-1/2”, 17#, L-80 liner to tie-back into 5” liner @ 5987’. Well scheduled for a witness mit on Sept 7th. Well will be returned to active injection upon approval of Form 21.
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:	4/4/2020	Treatment End Date:	4/4/2020
Treatment Summary:	PUMPED 4000 GALLONS (95 BBLS) 15% HCL WITH SOLVENT AND 37 BBLS FRESH WATER
Total fluid used in treatment (bbls):	132	Max pressure during treatment (psi):	2350
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):	37	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:	2/12/2019	Treatment End Date:	2/12/2019
Treatment Summary:	PUMP 4000 GALLONS 15% HCL WITH 170 BBLS FRESH WATER
Total fluid used in treatment (bbls):	265	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):	170	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	9/10/2018	Treatment End Date:	N/A
Treatment Summary:	TUBING PLUG SET AT 5950 ON 9/10/2018
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:
Treatment Date:	12/7/2017	Treatment End Date:	N/A
Treatment Summary:	COA from document #401254362, "provide updated Form 5A". First injection 11/25/1977. Corrections to tubing depth and # of perf holes.
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:	7/16/2013	Treatment End Date:	7/16/2013
Treatment Summary:	ACID STIMULATION
Total fluid used in treatment (bbls):	167	Max pressure during treatment (psi):	1500
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):	75	Disposition method For flowback:	RECYCLE
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized: PIPELINE
Formation Treatment
Treatment Date:	11/7/2008
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS HEATED 15% HCI, EOT @ 5905

Tubing Size:	2.875 in.	Tubing Setting Depth:	6009 ft.
Tubing Packer Depth:	5950 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6220 ft.	# Of Holes:	276
Interval Bottom:	6669 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