Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-07530		Well Classification: ERIW	Status: IJ - 4/11/2022
Well Name/No:	MCLAUGHLIN, S W #8X (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	4/11/2022
FacilityID:	229872	LocationID:	314909
County:	RIO BLANCO #103	Location:	SESW 33 2N102W 6
Field:	RANGELY - #72370	Elevation:	5207 ft.
Planned Location:	15FSL 1461 FWL	Lat/Long: 40.092236 / -108.852485	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.092340 / -108.852550	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: OTH Status: IJ - 4/11/2022 Measured TD: 6367 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: OTH IJ - 4/11/2022
Wellbore Permit
Permit #:	730380	Expiration Date:	10/13/1973
Prop Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEE	Surface Owner:	Not available
Unit:		Unit Number:
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	8/14/1973
Spud Date:	6/23/1973	Spud Date Is:	ACTUAL
Measured TD:	6367 ft.	Measured PB depth:	6350 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	NEW CEMENT BOND LOG
Casing:	String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 749 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 525, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6364 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 700, Top: 2284 ft., Bottom: 6364 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA			N	N
MORRISON	3817 ft.		N	N
CURTIS	3920 ft.		N	N
ENTRADA	4060 ft.		N	N
CARMEL	4120 ft.		N	N
NAVAJO	4700 ft.		N	N
CHINLE	4846 ft.		N	N
SHINARUMP	4915 ft.		N	N
MOENKOPI	5118 ft.		N	N
WEBER	5549 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 4/11/2022 Interval Top: 5575 ft. Interval Bottom: 6184 ft.

Completed Information for Formation WEBER

1st Production Date:	8/2/1987	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	4/8/2022	Treatment End Date:	4/8/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/6% CITRIC ACID AND 65 BBLS WATER CONVERTED TO INJECTION 8/2/1987
Total fluid used in treatment (bbls):	112	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):	65	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:	3/9/2021	Treatment End Date:	3/9/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/6% CITRIC ACID AND 45 BBLS WATER CONVERTED TO INJECTION 8/2/1987
Total fluid used in treatment (bbls):	92	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):	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:	3/9/2020	Treatment End Date:	3/9/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 1.9 BBLS MUTUAL SOLVENT.
Total fluid used in treatment (bbls):	49	Max pressure during treatment (psi):	1500
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:	12/29/2017	Treatment End Date:	12/29/2017
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 80 BBLS WATER.
Total fluid used in treatment (bbls):	127	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):	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:	PERFORATED 5575-6366' IN SIX RUNS

Test Type	Measure
Tubing Size:	2.875 in.	Tubing Setting Depth:	5556 ft.
Tubing Packer Depth:	5520 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
Initial Test Data:
Test Date:	N/A	Test Method:
Hours Tested:		Gas Type:
Gas Disposal:
GRAVITY_OIL	34

Perforation Data:
Interval Top:	5575 ft.	# Of Holes:	525
Interval Bottom:	6184 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)	176664
GOR
GOR Determination	MCFE
Average BOE per Day	82.719
Average MCFE per Day	479.759

Federal Financial Assurance

Tribal Well