Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-07692		Well Classification: ERIW	Status: IJ - 5/2/2024
Well Name/No:	MCLAUGHLIN, A C #60X (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	5/2/2024
FacilityID:	230033	LocationID:	314986
County:	RIO BLANCO #103	Location:	NWSE 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5439 ft.
Planned Location:	1399FSL 1451 FEL	Lat/Long: 40.139605 / -108.919368	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.139703 / -108.919326	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: OTH Status: IJ - 5/2/2024 Measured TD:

Wellbore Data for Original Wellbore		Wellbore Classification: OTH IJ - 5/2/2024
Wellbore Permit
Permit #:	750147	Expiration Date:	6/20/1975
Prop Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	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:	N/A
Spud Date:	6/7/1975	Spud Date Is:	ACTUAL
Measured TD:		Measured PB depth:	6705 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:
Casing:	String Type: SURF, Hole Size: 14.75 in., Size: 10.75 in., Top: 0 ft., Depth: 762 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 525, Top: 0 ft., Bottom: 762 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6649 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 700, Top: 0 ft., Bottom: 6649 ft., Determination Method: CBL
Casing:	String Type: S.C. 1.1, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6652 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 30, Top: 3691 ft., Bottom: 3758 ft., Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: 6.366 in., Size: 4.5 in., Top: 0 ft., Depth: 6584 ft., Weight: 11.6 , Citings Type: ACTUAL
Cement:	Sacks: 413, Top: 0 ft., Bottom: 6584 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3607 ft.
MORRISON	3698 ft.
CURTIS	4402 ft.
ENTRADA	4509 ft.
CARMEL	4653 ft.
NAVAJO	4712 ft.
CHINLE	5332 ft.
SHINARUMP	5465 ft.
MOENKOPI	5556 ft.
WEBER	6207 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 5/2/2024 Interval Top: 6436 ft. Interval Bottom: 6570 ft.

Completed Information for Formation WEBER

1st Production Date:	8/1/1975	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	4/30/2024	Treatment End Date:	4/30/2024
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL with solvent and 35 bbls fresh water.
Total fluid used in treatment (bbls):	82	Max pressure during treatment (psi):	2900
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):	0	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:	8/10/2023	Treatment End Date:	8/10/2023
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL with solvent and 75 bbls fresh water.
Total fluid used in treatment (bbls):	122	Max pressure during treatment (psi):	2000
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):	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:	11/11/2022	Treatment End Date:	11/11/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH MUTUAL SOLVENT, FLUSHED WITH 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:	5/17/2022	Treatment End Date:	5/17/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH MUTUAL SOLVENT, FLUSHED WITH 40 BBLS 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:	11/20/2021	Treatment End Date:	11/20/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 6% CITRIC ACID, FLUSHED WITH 40 BBLS 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:	3/25/2021	Treatment End Date:	3/25/2021
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 6% CITRIC ACID, FLUSHED WITH 70 BBLS WATER
Total fluid used in treatment (bbls):	117	Max pressure during treatment (psi):	1460
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):	70	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:	1/5/2020	Treatment End Date:	1/5/2020
Treatment Summary:	PUMPED 2988 GALLONS (71.1 BBLS) 15% HCL ACID 6% CITRIC, MUTSOL AND 34 BBLS OF FRESH WATER
Total fluid used in treatment (bbls):	105	Max pressure during treatment (psi):	2100
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):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	34	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:	12/6/2018	Treatment End Date:	12/6/2018
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 90 GALLONS SOVENT, FLUSHED WITH 178 BBLS WATER
Total fluid used in treatment (bbls):	227	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	178	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	8/30/2016	Treatment End Date:	N/A
Treatment Summary:	CORRECTED PERFORATION DATA SUBMITTED ON DOC#401058578 TO REFLECT PERFORATION INTERVAL IN THE 4 1/2 LINER RUN IN 11/2006.
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:	6/1/2016	Treatment End Date:	6/1/2016
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 96 GALLONS MUTUAL SOLVENT WITH ADDITIVES, 160 BBLS FRESH WATER
Total fluid used in treatment (bbls):	210	Max pressure during treatment (psi):	2000
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):	160	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	2/9/2010
Treatment Summary:	SPOT 4000 GALS 20% HCI AT 6399' AND FLUSH W/ 25 BBLS WATER @ 2500 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6375 ft.
Tubing Packer Depth:	6290 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6436 ft.	# Of Holes:	398
Interval Bottom:	6570 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)	355602
GOR
GOR Determination	MCFE
Average BOE per Day	167.869
Average MCFE per Day	973.633

Federal Financial Assurance

Tribal Well