Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08320		Well Classification: ERIW	Status: IJ - 1/25/2023
Well Name/No:	MCLAUGHLIN, A C #72X (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	1/25/2023
FacilityID:	230652	LocationID:	315338
County:	RIO BLANCO #103	Location:	NWNE 24 2N103W 6
Field:	RANGELY - #72370	Elevation:	5368 ft.
Planned Location:	1303FNL 1508 FEL	Lat/Long: 40.132185 / -108.900837	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.132240 / -108.900700	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 1/25/2023 Measured TD: 6618 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 1/25/2023
Wellbore Permit
Permit #:	810748	Expiration Date:	9/12/1981
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:	5/14/1985
Measured TD:	6618 ft.	Measured PB depth:	6536 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 2977 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 750, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6618 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3395 ft.
MORRISON	3484 ft.
ENTRADA	4282 ft.
NAVAJO	4475 ft.
CHINLE	5108 ft.
WEBER	5984 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 1/25/2023 Interval Top: 6000 ft. Interval Bottom: 6484 ft.

Completed Information for Formation WEBER

1st Production Date:	5/14/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	1/24/2023	Treatment End Date:	1/24/2023
Treatment Summary:	Pumped 2000 Gallons (47.6 bbls) 15% HCL w/additives, inhibitor, mutual solvent and 35 bbls fresh 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:	11/20/2021	Treatment End Date:	11/20/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/6% CITRIC ACID AND MUTUAL SOLVENT, 46 BBLS WATER
Total fluid used in treatment (bbls):	93	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):	46	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:	2/16/2021	Treatment End Date:	2/16/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/6% CITRIC ACID AND MUTUAL SOLVENT, 47 BBLS WATER
Total fluid used in treatment (bbls):	95	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):	47	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	11/21/2019	Treatment End Date:	N/A
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL, 38.0 BBLS OF FRESH WATER.
Total fluid used in treatment (bbls):	85	Max pressure during treatment (psi):	2150
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:	12/14/2017	Treatment End Date:	12/14/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL AT STARTING 730 PSI WITH 80 BBLS WATER
Total fluid used in treatment (bbls):	175	Max pressure during treatment (psi):	810
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:
Treatment Date:	12/7/2017	Treatment End Date:	N/A
Treatment Summary:	COA from document # 401276815, provide tubing and packer information First injection 4/1/1982
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 Date:	9/17/2011
Treatment Summary:	PUMPED 4000 GALLONS 20% HCL THROUGH END OF TUBING AT 6120' @ .8 BPM AT 800 PSI. 2 7/8" tubing set on 11/12/1998
Formation Treatment
Treatment Date:	2/11/2009
Treatment Summary:	ACIDIZE FORMATION W/ 4000 GALS HEATED 20% HCI, EOT @ 6404'

Tubing Size:	2.875 in.	Tubing Setting Depth:	6501 ft.
Tubing Packer Depth:	5875 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6000 ft.	# Of Holes:	123
Interval Bottom:	6484 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)	266275
GOR
GOR Determination	MCFE
Average BOE per Day	125.072
Average MCFE per Day	725.392

Federal Financial Assurance

Tribal Well