Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-09201		Well Classification: ERIW	Status: IJ - 2/18/2021
Well Name/No:	MCLAUGHLIN, A C #41AX (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	2/18/2021
FacilityID:	231530	LocationID:	315769
County:	RIO BLANCO #103	Location:	NWNE 24 2N103W 6
Field:	RANGELY - #72370	Elevation:	5392 ft.
Planned Location:	464FNL 1814 FEL	Lat/Long: 40.134485 / -108.901917	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.134540 / -108.901800	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 2/18/2021 Measured TD: 6648 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 2/18/2021
Wellbore Permit
Permit #:	10001	Expiration Date:	1/5/1985
Proposed 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:	3/21/1985
Measured TD:	6648 ft.	Measured PB depth:	6600 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: 2477 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 580, Top: 0 ft., Bottom: 2477 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6646 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 460, Top: , Bottom: 6646 ft., Determination Method: CALC
Casing:	String Type: STAGE TOOL, Hole Size: , Size: 7 in., Top: , Depth: , Weight: , Citings Type: ACTUAL
Cement:	Sacks: 1290, Top: , Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3456 ft.
MORRISON	3538 ft.
ENTRADA	4357 ft.
NAVAJO	4552 ft.
CHINLE	5184 ft.
WEBER	6058 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 2/18/2021 Interval Top: 6077 ft. Interval Bottom: 6556 ft.

Completed Information for Formation WEBER

1st Production Date:	3/22/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	2/16/2021	Treatment End Date:	2/16/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/6% CITRIC ACID AND MUTUAL SOLVENT, 47 BBLS WATER
Total fluid used in treatment (bbls):	95	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):	47	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:	2/9/2019	Treatment End Date:	2/9/2019
Treatment Summary:	Pump 2000 gallons 15% HCl with 110 gallons solvent, and 110 bbls water.
Total fluid used in treatment (bbls):	160	Max pressure during treatment (psi):	2117
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):	110	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:	10/16/2017	Treatment End Date:	10/16/2017
Treatment Summary:	Pumped 2000 gallons 15% HCl and 110 gallons mutual solvent with 166 bbls water at average 2.9 bpm @ 994 psi.
Total fluid used in treatment (bbls):	213	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):	166	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:	3/18/2015	Treatment End Date:	3/18/2015
Treatment Summary:	PUMP 4000 GALLONS 15% HCL THROUGH END OF COILED TUBING AT 6175'
Total fluid used in treatment (bbls):	205	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):	150	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:	2/26/2013	Treatment End Date:	2/26/2013
Treatment Summary:	15% ACID STIMULATION THROUGH COILED TUBING AT 6182'.
Total fluid used in treatment (bbls):	143	Max pressure during treatment (psi):	1300
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	71	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	72	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:	4/8/2011
Treatment Summary:	ACID STIMULATION 4/8/11 PUMPED 3000 GALLONS ON 20% HCL THOUGH END O F TUBING @ 6182', PUMPING AT 800 PSI @ .8 BPM.
Formation Treatment
Treatment Date:	8/14/2009
Treatment Summary:	ACID STIMULATION 8/14/09 PUMPED 2000 GALS OF HEATED 20% HCI & 10,500 GALS CHLORINE DIOXIDE IN FOUR STAGES THROUGH TUBING @ 6176'. AVERAGE 3.0 BPM @ 2200 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6102 ft.
Tubing Packer Depth:	5975 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6077 ft.	# Of Holes:	208
Interval Bottom:	6556 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

December 2023 - November 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	58600
GOR
GOR Determination	MCFE
Average BOE per Day	27.890
Average MCFE per Day	161.770

Federal Financial Assurance

Tribal Well