Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-01050		Well Classification: ERIW	Status: IJ - 8/1/2024
Well Name/No:	MCLAUGHLIN, A C #26 (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	8/1/2024
FacilityID:	228132	LocationID:	314256
County:	RIO BLANCO #103	Location:	SESE 15 2N103W 6
Field:	RANGELY - #72370	Elevation:	5515 ft.
Planned Location:	731FSL 731 FEL	Lat/Long: 40.137785 / -108.935558	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.137890 / -108.935630	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 8/1/2024 Measured TD: 6672 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 8/1/2024
Wellbore Permit
Permit #:	10001	Expiration Date:	3/9/1980
Prop 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:	2/20/1985
Measured TD:	6672 ft.	Measured PB depth:	6660 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: , Size: 10.75 in., Top: 0 ft., Depth: 697 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: 0 ft., Bottom: 697 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6301 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: , Top: 0 ft., Bottom: 6301 ft., Determination Method: CALC
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5 in., Top: 6112 ft., Depth: 6672 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 225, Top: 6112 ft., Bottom: 6672 ft., Determination Method: CALC

Formation WEBR Formation Classification: ERIW Status: IJ - 8/1/2024 Interval Top: 6320 ft. Interval Bottom: 6649 ft.

Completed Information for Formation WEBER

1st Production Date:	2/19/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/1/2022	Treatment End Date:	8/1/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL w/6% CITRIC ACID AND 35 BBLS WATER
Total fluid used in treatment (bbls):	82	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):	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:	11/12/2021	Treatment End Date:	11/12/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL w/6% CITRIC ACID AND 45 BBLS WATER
Total fluid used in treatment (bbls):	140	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):	45	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:	3/4/2021	Treatment End Date:	3/4/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL w/6% CITRIC ACID AND 44 BBLS WATER
Total fluid used in treatment (bbls):	139	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):	44	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:	7/9/2019	Treatment End Date:	7/9/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL w/ 3%CITRIC ACID AND 95 BBLS WATER. FIRST INJECTION 2/20/1985.
Total fluid used in treatment (bbls):	142	Max pressure during treatment (psi):	2273
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):	95	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:	8/2/2017	Treatment End Date:	8/2/2017
Treatment Summary:	pumped 2000 gallons 15% HCl and 110 gallons solvent with 191 bbls water. first injection 2/20/1985
Total fluid used in treatment (bbls):	241	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	191	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:	6/3/2015	Treatment End Date:	6/3/2015
Treatment Summary:	Pumped 1000 gallons 15% HCl
Total fluid used in treatment (bbls):	104	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):	24	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		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 Date:	6/2/2010
Treatment Summary:	ACID STIMULATION 6-2-2010 PUMPED 4000 GALLONS 20% HCI AT .9 BM @ 400 PSI THROUGH END OF TUBING 6569'.
Formation Treatment
Treatment Date:	8/4/2009
Treatment Summary:	ACIDIZE FORMATION W/ 4000 GALS 20% HCI, EOT @ 6569'.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6569 ft.
Tubing Packer Depth:	5988 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6320 ft.	# Of Holes:	151
Interval Bottom:	6649 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

August 2023 - July 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	15766
GOR
GOR Determination	MCFE
Average BOE per Day	7.418
Average MCFE per Day	43.027

Federal Financial Assurance

Tribal Well