Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-01047		Well Classification: ERIW	Status: IJ - 12/8/2022
Well Name/No:	MCLAUGHLIN, A C #34 (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	12/8/2022
FacilityID:	228129	LocationID:	311786
County:	RIO BLANCO #103	Location:	SESE 10 2N103W 6
Field:	RANGELY - #72370	Elevation:	5574 ft.
Planned Location:	660FSL 660 FEL	Lat/Long: 40.152014 / -108.935378	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.152120 / -108.935370	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 12/8/2022 Measured TD: 6930 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 12/8/2022
Wellbore Permit
Permit #:	100001	Expiration Date:	2/24/2000
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:	7/16/1947
Spud Date:	5/15/1947	Spud Date Is:	ACTUAL
Measured TD:	6930 ft.	Measured PB depth:	6730 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:
Casing:	String Type: CONDUCTOR, Hole Size: 20 in., Size: 16 in., Top: 0 ft., Depth: 57 ft., Weight: 55 , Citings Type: ACTUAL
Cement:	Sacks: 106, Top: 0 ft., Bottom: 57 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 10.75 in., Top: 0 ft., Depth: 731 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 500, Top: 0 ft., Bottom: 731 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 9 in., Size: 7 in., Top: 0 ft., Depth: 6606 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: 5457 ft., Bottom: 6606 ft., Determination Method: CBL
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 0 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Additional Cement:	String Type: S.C. 1.1 , Top: 0 ft., Depth: 785 ft., Bottom: 785 ft., Sacks: 105, Method: 1 INCH
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3867 ft.	3965 ft.	N	N
MORRISON	3965 ft.	4062 ft.	N	N
CURTIS	4062 ft.	4775 ft.	N	N
ENTRADA	4775 ft.	4880 ft.	N	N
CARMEL	4880 ft.	5028 ft.	N	N
NAVAJO	5028 ft.	5080 ft.	N	N
CHINLE	5080 ft.	5714 ft.	N	N
SHINARUMP	5714 ft.	5838 ft.	N	N
MOENKOPI	5838 ft.	5910 ft.	N	N
WEBER	5910 ft.	6600 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 12/8/2022 Interval Top: 6606 ft. Interval Bottom: 6730 ft.

Completed Information for Formation WEBER

1st Production Date:	10/18/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	12/5/2022	Treatment End Date:	12/5/2022
Treatment Summary:	Pumped 2000 gallons (47.6 bls) 15% HCL w/solvent and 35 bbls water
Total fluid used in treatment (bbls):	82	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):	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:	11/22/2021	Treatment End Date:	11/22/2021
Treatment Summary:	Pumped 4000 gallons (95.2 bls) 15% HCL w/solvent and 45 bbls water
Total fluid used in treatment (bbls):	140	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):	95	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:	11/6/2019	Treatment End Date:	11/6/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15%HCL WITH SOLVENT, 38 BBLS WATER.
Total fluid used in treatment (bbls):	85	Max pressure during treatment (psi):	2250
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):	38	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:	3/26/2018	Treatment End Date:	3/26/2018
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 80 GALLONS OF MUTUAL SOLVENT, 110 BBLS WATER.
Total fluid used in treatment (bbls):	160	Max pressure during treatment (psi):	2462
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):	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:	12/5/2014	Treatment End Date:	12/5/2014
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL AT 3.3 BPM
Total fluid used in treatment (bbls):	295	Max pressure during treatment (psi):	1700
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):	200	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	6/9/2010
Treatment Summary:	ACID STIMULATION 06/09/2010 PUMPED 4000 GALLONS OF 20% HCI THROUGH END OF TUBING 6407T STARTING PRESSURE OF 1870 PSI AT 2.8 BPM.
Formation Treatment
Treatment Date:	7/13/2009
Treatment Summary:	(OPEN HOLE 6606 - 6730') ACIDIZE FORMATION W/ 4,000 GALS HEATED 20% HCI, BULLHEAD @ 3.5 BPM @ 1421 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6410 ft.
Tubing Packer Depth:	6323 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6606 ft.	# Of Holes:
Interval Bottom:	6730 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)	203884
GOR
GOR Determination	MCFE
Average BOE per Day	95.005
Average MCFE per Day	551.036

Federal Financial Assurance

Tribal Well