Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-05798		Well Classification: ERIW	Status: IJ - 10/11/2022
Well Name/No:	MCLAUGHLIN, A C #12 (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	10/11/2022
FacilityID:	228812	LocationID:	314479
County:	RIO BLANCO #103	Location:	NWSW 13 2N103W 6
Field:	RANGELY - #72370	Elevation:	5478 ft.
Basin:	PICEANCE BASIN
Planned Location:	1980FSL 660 FWL	Lat/Long: 40.141195 / -108.911817	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.141300 / -108.911780	Lat/Long Source: Field Measured


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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 10/11/2022 Measured TD: 6660 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 10/11/2022
Wellbore Permit
Permit #:	10001	Expiration Date:	9/5/1980
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:	5/20/1985
Spud Date:	6/9/1946	Spud Date Is:	ACTUAL
Measured TD:	6660 ft.	Measured PB depth:	6645 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:
Casing:	String Type: CONDUCTOR, Hole Size: 24 in., Size: 16 in., Top: 12 ft., Depth: 57 ft., Weight: 55 , Citings Type: ACTUAL
Cement:	Sacks: 110, Top: 0 ft., Bottom: 57 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 10.75 in., Top: 12 ft., Depth: 988 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 750, Top: 0 ft., Bottom: 988 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 10.75 in., Size: 7 in., Top: 0 ft., Depth: 6322 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: 0 ft., Bottom: 6322 ft., Determination Method: VISU
Casing:	String Type: S.C. 1.1, Hole Size: , Size: , Top: , Depth: 1038 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 400, Top: 0 ft., Bottom: 1038 ft., Determination Method: CALC
Casing:	String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 6245 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 305, Top: 0 ft., Bottom: 6245 ft., Determination Method: VISU
Casing:	String Type: OPEN HOLE, Hole Size: 7 in., Size: , Top: 6322 ft., Depth: 6660 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: , Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2561 ft.	3325 ft.	N	N
FRONTIER	3325 ft.	3584 ft.	N	N
MOWRY	3584 ft.	3678 ft.	N	N
DAKOTA	3678 ft.	3750 ft.	N	N
MORRISON	3750 ft.	4479 ft.	N	N
CURTIS	4479 ft.	4584 ft.	N	N
ENTRADA	4584 ft.	4720 ft.	N	N
CARMEL	4720 ft.	4772 ft.	N	N
NAVAJO	4772 ft.	5410 ft.	N	N
CHINLE	5410 ft.	5535 ft.	N	N
SHINARUMP	5535 ft.	5612 ft.	N	N
MOENKOPI	5612 ft.	6292 ft.	N	N
WEBER	6292 ft.	6660 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 10/11/2022 Interval Top: 6322 ft. Interval Bottom: 6604 ft.

Completed Information for Formation WEBER

1st Production Date:	5/20/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/21/2024	Treatment End Date:	8/21/2024
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/solvent and 35 bbls Fresh water
Total fluid used in treatment (bbls):	130	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):	95	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:	10/4/2022	Treatment End Date:	10/4/2022
Treatment Summary:	Pumped 95.2 bbls 15% HCL with mutual solvent and 40 bbls fresh water.
Total fluid used in treatment (bbls):	135	Max pressure during treatment (psi):	2450
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):	40	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	11/10/2021	Treatment End Date:	N/A
Treatment Summary:	Perfs from 6606-6632. Pulled injection string, drilled out the old 5-1/2” fiberglass liner to 6604’, perforated the 7” casing @ 1038’ and performed a bradenhead squeeze w/ 400 sxs. Ran new 5-1/2” 17#, L-80 liner from 0’-6245’, cemented w/ 305 sxs, and then ran the new injection string. All cement tops in this well should now say 0’ by visual since we did the bradenhead squeeze on the 7” and got returns while cementing the liner.
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:	8/4/2020	Treatment End Date:	8/4/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT, 80 BBLS WATER
Total fluid used in treatment (bbls):	128	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):	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:	12/17/2017	Treatment End Date:	12/17/2017
Treatment Summary:	PUMPED 48 BBLS 15% HCL WITH 1.5 BBLS SOLVENT AND CORRISON INHIBITOR AND 154 BBLS WATER. CONVERTED TO INJECTION 5/20/1985
Total fluid used in treatment (bbls):	203	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):	154	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:	6/30/2016	Treatment End Date:	6/30/2016
Treatment Summary:	PUMPED 2.8 BBLS MUTUAL SOLVENT, 47.2 BBLS 15% HCL AND 320 BBLS WATER AT STARTING RATE 4 BPM AT 2400 PSI.
Total fluid used in treatment (bbls):	370	Max pressure during treatment (psi):	2443
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):	320	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	3/16/2010
Treatment Summary:	ACID STIMULATION 3/16/2010 PUMPED 4000 GALLONS OF 20% HCI THROUGH END OF TUBING 6645' AT STARTING PRESSURE OF 900 PSI

Tubing Size:	2.875 in.	Tubing Setting Depth:	6298 ft.
Tubing Packer Depth:	6179 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6322 ft.	# Of Holes:	16
Interval Bottom:	6604 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

November 2024 - October 2025	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	0
GOR
GOR Determination
Average BOE per Day	0.000
Average MCFE per Day	0.000

Federal Financial Assurance

Tribal Well