Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06324		Well Classification: ERIW	Status: IJ - 5/2/2024
Well Name/No:	MCLAUGHLIN, A C #43 (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:	229233	LocationID:	314673
County:	RIO BLANCO #103	Location:	NWSE 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5449 ft.
Planned Location:	2079FSL 1881 FEL	Lat/Long: 40.141475 / -108.920888	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.141574 / -108.920836	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 5/2/2024 Measured TD: 6609 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 5/2/2024
Wellbore Permit
Permit #:	10001	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:	4/30/1948
Spud Date:	3/8/1948	Spud Date Is:	ACTUAL
Measured TD:	6609 ft.	Measured PB depth:	6609 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	CBL
Casing:	String Type: CONDUCTOR, Hole Size: 0 in., Size: 16 in., Top: 0 ft., Depth: 33 ft., Weight: 65 , Citings Type: ACTUAL
Cement:	Sacks: 1, Top: 0 ft., Bottom: 33 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 10.75 in., Top: 0 ft., Depth: 734 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 400, Top: 0 ft., Bottom: 734 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6267 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1100, Top: 2856 ft., Bottom: 6267 ft., Determination Method: CBL
Additional Cement:	String Type: 1ST , Top: 564 ft., Depth: 759 ft., Bottom: 759 ft., Sacks: 150, Method: SQUEEZE
Additional Cement:	String Type: 1ST , Top: 0 ft., Depth: 2530 ft., Bottom: 2530 ft., Sacks: 330, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3662 ft.		N	N
MORRISON	3737 ft.		N	N
ENTRADA	4554 ft.		N	N
NAVAJO	4758 ft.		N	N
SHINARUMP	5505 ft.		N	N
MOENKOPI	5577 ft.		N	N
WEBER	6270 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 5/2/2024 Interval Top: 6267 ft. Interval Bottom: 6609 ft.

Completed Information for Formation WEBER

1st Production Date:	11/1/1975	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	4/30/2024	Treatment End Date:	4/30/2024
Treatment Summary:	PUMPED 4000 GALLONS (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):	2440
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):	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:	5/22/2023	Treatment End Date:	5/22/2023
Treatment Summary:	PUMPED 216 BBLS 15% HCL & STIMWRK-DWG WITH MUTUAL SOLVENT AND 52 BBLS FRESH WATER
Total fluid used in treatment (bbls):	178	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):	126	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	52	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:	8/5/2022	Treatment End Date:	8/5/2022
Treatment Summary:	PUMPED 4000 GALLONS 95.2 BBLS 15% HCL WITH 35 BBLS WATER
Total fluid used in treatment (bbls):	130	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):	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:	11/12/2021	Treatment End Date:	11/12/2021
Treatment Summary:	PUMPED 4000 GALLONS 95.2 BBLS 15% HCL WITH 45 BBLS WATER
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:	1/14/2019	Treatment End Date:	1/14/2019
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL AT 2.0 BPM @ 530 PSI WITH 280 BBLS WATER
Total fluid used in treatment (bbls):	327	Max pressure during treatment (psi):	1100
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):	280	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:	2/18/2016	Treatment End Date:	2/18/2016
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL AND 200 BBLS FRESH WATER
Total fluid used in treatment (bbls):	248	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):	48	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:	9/28/2006
Treatment Summary:	ACID STIMULATION PUMPED 3,000 GALS 15% HCL THROUGH TUBING @ A DEPTH OF 6485. OPEN HOLE 6267-6609

Tubing Size:	2.875 in.	Tubing Setting Depth:	6253 ft.
Tubing Packer Depth:	6133 ft.	Tubing Multiple Packer:
Open Hole Top:	6267 ft.	Open Hole Bottom:	6609 ft.
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6267 ft.	# Of Holes:
Interval Bottom:	6609 ft.	Hole Size:

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)	193724
GOR
GOR Determination	MCFE
Average BOE per Day	91.572
Average MCFE per Day	531.141

Federal Financial Assurance

Tribal Well