Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-09207		Well Classification: ERIW	Status: IJ - 11/22/2021
Well Name/No:	MCLAUGHLIN, A C #3AX (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 #:
Facility Status:	IJ	Status Date	11/22/2021
FacilityID:	231536	LocationID:	315773
County:	RIO BLANCO #103	Location:	SESE 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5436 ft.
Planned Location:	925FSL 637 FEL	Lat/Long: 40.138305 / -108.916457	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.138390 / -108.916420	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 11/22/2021 Measured TD: 6692 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 11/22/2021
Wellbore Permit
Permit #:	841334	Expiration Date:	5/17/1985
Prop 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:	4/4/1985
Measured TD:	6692 ft.	Measured PB depth:	6570 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 2501 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 545, Top: 0 ft., Bottom: 2501 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6690 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1550, Top: , Bottom: 6690 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3570 ft.
MORRISON	3670 ft.
ENTRADA	4465 ft.
NAVAJO	4660 ft.
CHINLE	5300 ft.
WEBER	6174 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 11/22/2021 Interval Top: 6192 ft. Interval Bottom: 6591 ft.

Completed Information for Formation WEBER

1st Production Date:	5/1/1985	Choke Size:
Formation Name:	WEBER	Commingled:
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	11/21/2021	Treatment End Date:	11/21/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT AND 40 BBLS FRESH WATER
Total fluid used in treatment (bbls):	87	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):	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:	2/9/2021	Treatment End Date:	2/9/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT AND 48 BBLS FRESH WATER
Total fluid used in treatment (bbls):	96	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):	48	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:	4/3/2020	Treatment End Date:	4/3/2020
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):	2300
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 Type:	ACID JOB
Treatment Date:	10/15/2017	Treatment End Date:	10/15/2017
Treatment Summary:	Pumped 2000 gallons 15% HCl and 110 gallons mutual solvent with 158 bbls water at average 2.7 bpm @ 1622 psi.
Total fluid used in treatment (bbls):	205	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):	158	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:	10/21/2015	Treatment End Date:	10/21/2015
Treatment Summary:	Pumped 110 gallons Musol solvent and 4000 gallons 15% HCl during wellwork through workstring tubing. Estimated first injection date.
Total fluid used in treatment (bbls):	221	Max pressure during treatment (psi):	1850
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):	124	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:	10/22/2013	Treatment End Date:	10/22/2013
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL AT END OF COILED TUBING @ 6342'
Total fluid used in treatment (bbls):	95	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):	95	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 Date:	9/9/2009
Treatment Summary:	ACID STIMULATION BY PUMPING 20% HCI THROUGH END OF COILED TUBING @6330'

Tubing Size:	2.875 in.	Tubing Setting Depth:	6552 ft.
Tubing Packer Depth:	6161 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6192 ft.	# Of Holes:	126
Interval Bottom:	6591 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)	121465
GOR
GOR Determination	MCFE
Average BOE per Day	56.709
Average MCFE per Day	328.932

Federal Financial Assurance

Tribal Well