Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-09132		Well Classification: ERIW	Status: IJ - 5/1/2024
Well Name/No:	SHARPLES-MCLAUGHLIN #16X-32 (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	5/1/2024
FacilityID:	231462	LocationID:	315728
County:	RIO BLANCO #103	Location:	SENE 32 2N102W 6
Field:	RANGELY - #72370	Elevation:	5269 ft.
Planned Location:	2071FNL 1268 FEL	Lat/Long: 40.101066 / -108.862235	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.101143 / -108.862303	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 5/1/2024 Measured TD: 6575 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 5/1/2024
Wellbore Permit
Permit #:	831758	Expiration Date:	4/29/1984
Prop Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEE	Surface Owner:	Not available
Unit:		Unit Number:
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	5/3/1984
Measured TD:	6575 ft.	Measured PB depth:	6489 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 9.625 in., Top: 0 ft., Depth: 2642 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 950, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6574 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3022 ft.
MORRISON	3144 ft.
ENTRADA	3835 ft.
NAVAJO	4100 ft.
CHINLE	4695 ft.
WEBER	5559 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 5/1/2024 Interval Top: 5600 ft. Interval Bottom: 6410 ft.

Completed Information for Formation WEBER

1st Production Date:	6/15/1989	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	1/25/2023	Treatment End Date:	1/25/2023
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS)15% HCL W/ MUTUAL SOLVENT, 35 BBLS WATER
Total fluid used in treatment (bbls):	82	Max pressure during treatment (psi):	1500
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:	5/25/2022	Treatment End Date:	5/25/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS)15% HCL W/ MUTUAL SOLVENT, 35 BBLS WATER.
Total fluid used in treatment (bbls):	130	Max pressure during treatment (psi):	1350
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:	3/11/2021	Treatment End Date:	3/11/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS)15% HCL W/6% CITRIC ACID AND MUTUAL SOLVENT, 40 BBLS WATER.
Total fluid used in treatment (bbls):	169	Max pressure during treatment (psi):	1550
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:	ACID JOB
Treatment Date:	2/15/2021	Treatment End Date:	2/15/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS)15% HCL W/6% CITRIC ACID AND MUTUAL SOLVENT, 66 BBLS WATER.
Total fluid used in treatment (bbls):	161	Max pressure during treatment (psi):	1600
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):	66	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:	6/29/2019	Treatment End Date:	6/29/2019
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH 110 GALLONS (2 BBLS) PAO103 SOLVENT AND 160 BBLS OF FRESH WATER
Total fluid used in treatment (bbls):	157	Max pressure during treatment (psi):	1051
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):	160	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:	11/18/2016	Treatment End Date:	11/18/2016
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 30 GALLONS MUSOL SOLVENT
Total fluid used in treatment (bbls):	128	Max pressure during treatment (psi):	1560
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):	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:	10/22/2015	Treatment End Date:	10/22/2015
Treatment Summary:	pumped 4000 gallons 15% HCl and 80 gallons solvent
Total fluid used in treatment (bbls):	180	Max pressure during treatment (psi):	1085
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):	83	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:	1/22/2014	Treatment End Date:	1/22/2014
Treatment Summary:	ACID STIMULATION WITH 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	175	Max pressure during treatment (psi):	1500
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:	RECYCLE
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized: PIPELINE
Formation Treatment
Treatment Date:	5/21/2010
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS 20% HCL, END OF COILED TUBING @ 6481
Formation Treatment
Treatment Date:	6/11/2009
Treatment Summary:	ACIDIZE FORMATION W/ 4000 GALS 20% HCI, END OF COILED TUBING @ 6489'.

Tubing Size:	2.875 in.	Tubing Setting Depth:	5551 ft.
Tubing Packer Depth:	5516 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5600 ft.	# Of Holes:	36
Interval Bottom:	6410 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

June 2023 - May 2024	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