Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-05718		Well Classification: ERIW	Status: IJ - 8/21/2024
Well Name/No:	MCLAUGHLIN, A C #23 (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	8/21/2024
FacilityID:	228741	LocationID:	314447
County:	RIO BLANCO #103	Location:	NWSW 23 2N103W 6
Field:	RANGELY - #72370	Elevation:	5534 ft.
Basin:	PICEANCE BASIN
Planned Location:	1880FSL 660 FWL	Lat/Long: 40.126425 / -108.930698	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.126550 / -108.930700	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 8/21/2024 Measured TD: 6721 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 8/21/2024
Wellbore Permit
Permit #:	10001	Expiration Date:	8/23/1980
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:	7/17/2015
Spud Date:	10/10/1946	Spud Date Is:	ACTUAL
Measured TD:	6721 ft.	Measured PB depth:	6710 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	CBL - will submit the electronic version when received from vender.
Casing:	String Type: CONDUCTOR, Hole Size: 20 in., Size: 16 in., Top: 0 ft., Depth: 36 ft., Weight: 55 , Citings Type: ACTUAL
Cement:	Sacks: 60, Top: 0 ft., Bottom: 36 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 10.75 in., Top: 0 ft., Depth: 718 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 5000, Top: 0 ft., Bottom: 718 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.25 in., Size: 7 in., Top: 0 ft., Depth: 6176 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: , Bottom: 6176 ft., Determination Method:
Casing:	String Type: 2ND, Hole Size: 6.125 in., Size: 5.5 in., Top: 0 ft., Depth: 6031 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 265, Top: 0 ft., Bottom: 6031 ft., Determination Method: CBL
Casing:	String Type: 1ST LINER, Hole Size: 6.125 in., Size: 5 in., Top: 6031 ft., Depth: 6717 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 220, Top: 6031 ft., Bottom: 6717 ft., Determination Method: CALC
Additional Cement:	String Type: 1ST , Top: 1732 ft., Depth: 1732 ft., Bottom: 1803 ft., Sacks: 165, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
WEBER	6031 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 8/21/2024 Interval Top: 6180 ft. Interval Bottom: 6668 ft.

Completed Information for Formation WEBER

1st Production Date:	5/8/1972	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/19/2024	Treatment End Date:	8/19/2024
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:	11/10/2022	Treatment End Date:	11/10/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 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):		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:	11/18/2021	Treatment End Date:	11/18/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT AND 40 BBLS FRESH WATER
Total fluid used in treatment (bbls):		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):		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:	3/6/2021	Treatment End Date:	3/6/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/6% CITRIC ACID AND 40 BBLS WATER
Total fluid used in treatment (bbls):	135	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):	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:	4/2/2020	Treatment End Date:	4/2/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT AND 37 BBLS FRESH WATER
Total fluid used in treatment (bbls):	84	Max pressure during treatment (psi):	2250
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):	37	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	3/25/2009
Treatment Summary:	ACID STIMULATION 3/25/09 PUMPED 4000 GALS HEATED 20% HCI W/ADDITIVES THROUGH TUBING AT 6415'.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6148 ft.
Tubing Packer Depth:	5973 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6180 ft.	# Of Holes:	552
Interval Bottom:	6668 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