Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-05782		Well Classification: ERIW	Status: IJ - 4/21/2023
Well Name/No:	MCLAUGHLIN, A C #20 (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	4/21/2023
FacilityID:	228797	LocationID:	314474
County:	RIO BLANCO #103	Location:	SESW 13 2N103W 6
Field:	RANGELY - #72370	Elevation:	5420 ft.
Planned Location:	660FSL 1980 FWL	Lat/Long: 40.137575 / -108.907117	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.137631 / -108.906616	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 4/21/2023 Measured TD: 6580 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 4/21/2023
Wellbore Permit
Permit #:	10001	Expiration Date:	10/11/1979
Proposed 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:	8/27/1977
Spud Date:	7/2/1946	Spud Date Is:	ACTUAL
Measured TD:	6580 ft.	Measured PB depth:	6580 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	NO NEW LOGS
Casing:	String Type: CONDUCTOR, Hole Size: 20.5 in., Size: 16 in., Top: 0 ft., Depth: 55 ft., Weight: 55 , Citings Type: ACTUAL
Cement:	Sacks: 60, Top: 0 ft., Bottom: 55 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 10.75 in., Top: 0 ft., Depth: 1020 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 650, Top: 0 ft., Bottom: 1020 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6166 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: , Bottom: 6166 ft., Determination Method:
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6166 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: 6.25 in., Size: 5 in., Top: 6026 ft., Depth: 6516 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 200, Top: 6026 ft., Bottom: 6516 ft., Determination Method: CBL
Casing:	String Type: 1ST LINER, Hole Size: 0 in., Size: 5 in., Top: 6026 ft., Depth: 6516 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
WEBER	6170 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 4/21/2023 Interval Top: 6190 ft. Interval Bottom: 6580 ft.

Completed Information for Formation WEBER

1st Production Date:	5/1/1969	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	4/19/2023	Treatment End Date:	4/19/2023
Treatment Summary:	PUMP 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT, AND 35 BBLS WATER
Total fluid used in treatment (bbls):	82	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):	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:	11/21/2021	Treatment End Date:	11/21/2021
Treatment Summary:	PUMP 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT, AND 40 BBLS WATER
Total fluid used in treatment (bbls):	88	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):	48	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:	2/11/2021	Treatment End Date:	2/11/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2BBLS) 15% HCL W/6% CITRIC ACID WITH SOLVENT AND 94 BBLS WATER.
Total fluid used in treatment (bbls):	189	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):	94	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:	8/4/2020	Treatment End Date:	8/4/2020
Treatment Summary:	PUMP 200 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT, 50 BBLS WATER
Total fluid used in treatment (bbls):	98	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):	48	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	50	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:	6/18/2019	Treatment End Date:	6/18/2019
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) OF 15% HCL WITH 80 BBLS OF FRESH WATER
Total fluid used in treatment (bbls):	175	Max pressure during treatment (psi):	1240
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):	80	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:	6/30/2015	Treatment End Date:	6/30/2015
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL W/ 165 GALLONS SOLVENT & 3800 GAL FRESH WATER AT 3.0 BPM Open hole: 6514-6580
Total fluid used in treatment (bbls):	190	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):	91	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	2/9/2009
Treatment Summary:	ACIDIZE FORMATION W/40500 GALS HEATED 20% HCI, EOT @ .6626'. TREATED THRU COILED TUBING.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6536 ft.
Tubing Packer Depth:	5920 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6190 ft.	# Of Holes:	190
Interval Bottom:	6580 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)	90666
GOR
GOR Determination	MCFE
Average BOE per Day	42.596
Average MCFE per Day	247.042

Federal Financial Assurance

Tribal Well