Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06419		Well Classification: ERIW	Status: IJ - 6/1/2023
Well Name/No:	MCLAUGHLIN, A C #55X (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	6/1/2023
FacilityID:	229318	LocationID:	314696
County:	RIO BLANCO #103	Location:	SWSW 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5516 ft.
Planned Location:	145FSL 79 FWL	Lat/Long: 40.136165 / -108.932658	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.136290 / -108.932740	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 6/1/2023 Measured TD: 6676 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 6/1/2023
Wellbore Permit
Permit #:	660367	Expiration Date:	1/12/1967
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:	2/23/1980
Spud Date:	9/16/1966	Spud Date Is:	ACTUAL
Measured TD:	6676 ft.	Measured PB depth:	6675 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 693 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 400, Top: 0 ft., Bottom: 693 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 9 in., Size: 7 in., Top: 0 ft., Depth: 6264 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 625, Top: 0 ft., Bottom: 6264 ft., Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: 6.366 in., Size: 5 in., Top: 6134 ft., Depth: 6675 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 125, Top: 6134 ft., Bottom: 6675 ft., Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3665 ft.
MORRISON	3758 ft.
CURTIS	4470 ft.
ENTRADA	4567 ft.
CARMEL	4700 ft.
NAVAJO	4762 ft.
CHINLE	5392 ft.
SHINARUMP	5492 ft.
MOENKOPI	5550 ft.
WEBER	6272 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 6/1/2023 Interval Top: 6280 ft. Interval Bottom: 6660 ft.

Completed Information for Formation WEBER

1st Production Date:	2/23/1980	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:
Treatment Date:	7/6/2023	Treatment End Date:	N/A
Treatment Summary:	Well work to repair well, replacing tubing and packer. Well to be returned to injection pending an approved 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:	4/11/2023	Treatment End Date:	4/12/2023
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/solvent and 75 bbls water.
Total fluid used in treatment (bbls):	170	Max pressure during treatment (psi):	500
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):	75	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 W/ 6% CITRIC ACID AND MUTUAL SOLVENT AND 48 BBLS 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:	2/10/2021	Treatment End Date:	2/10/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/ 6% CITRIC ACID AND MUTUAL SOLVENT AND 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:	9/18/2020	Treatment End Date:	9/18/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/6% CITRIC ACID
Total fluid used in treatment (bbls):	47	Max pressure during treatment (psi):	2200
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):		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:	4/12/2019	Treatment End Date:	4/12/2019
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 24.5 BBLS SOLVENT AND 100 BBLS WATER.
Total fluid used in treatment (bbls):	172	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):	100	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:	7/1/2015	Treatment End Date:	7/1/2015
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL W/ 165 GALLONS SOLVENT AT 3.5 BPM CORRECTED TUBING SETTING DEPTH.
Total fluid used in treatment (bbls):	199	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):	100	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	8/13/2011
Treatment Summary:	ACID STIMULATION - PUMPED 4000 GALLONS 20 % HCL THROUGH EOT 6424' 1100 PSI @ .9 BPM
Formation Treatment
Treatment Date:	12/17/2009
Treatment Summary:	ACID STIMULATION 12/17/09 PUMPED 4,000 GALS 20% HCI THROUGH END OF TUBING 6399' & 6424' AT 1.6 BPM @ 3500 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6649 ft.
Tubing Packer Depth:	6071 ft.	Tubing Multiple Packer:	Y ft.
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6280 ft.	# Of Holes:	321
Interval Bottom:	6660 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)	187105
GOR
GOR Determination	MCFE
Average BOE per Day	87.868
Average MCFE per Day	509.645

Federal Financial Assurance

Tribal Well