Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06298		Well Classification: ERIW	Status: IJ - 8/12/2022
Well Name/No:	LARSON, F V #B-4 (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	8/12/2022
FacilityID:	229210	LocationID:	314659
County:	RIO BLANCO #103	Location:	NWNW 36 2N102W 6
Field:	RANGELY - #72370	Elevation:	5283 ft.
Planned Location:	660FNL 660 FWL	Lat/Long: 40.104976 / -108.798593	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.105090 / -108.798620	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 8/12/2022 Measured TD: 6445 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 8/12/2022
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-051900
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	4/1/1947
Measured TD:	6445 ft.	Measured PB depth:	6445 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: , Size: 13.375 in., Top: 0 ft., Depth: 388 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 270, Top: 0 ft., Bottom: 388 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 5910 ft., Weight: 20&23 , Citings Type: ACTUAL
Cement:	Sacks: 900, Top: , Bottom: 5910 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
WEBER	5899 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 8/12/2022 Interval Top: 5910 ft. Interval Bottom: 6445 ft.

Completed Information for Formation WEBER

1st Production Date:	12/1/1958	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/5/2022	Treatment End Date:	8/5/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/MUTUAL SOLVENT AND 35 BBLS 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:	7/23/2021	Treatment End Date:	7/23/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/6% CITRIC ACID AND 40 BBLS WATER
Total fluid used in treatment (bbls):	135	Max pressure during treatment (psi):	2020
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:	9/12/2019	Treatment End Date:	9/12/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 6% CITRIC ACID, 80 BBLS OF WATER.
Total fluid used in treatment (bbls):	127	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):	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:	8/1/2017	Treatment End Date:	8/1/2017
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL AND 115 GALLONS SOLVENT. 168 BBLS FRESH WATER. CTI 12/1/1958
Total fluid used in treatment (bbls):	218	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	168	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:

Tubing Size:	2.875 in.	Tubing Setting Depth:	6190 ft.
Tubing Packer Depth:	5843 ft.	Tubing Multiple Packer:
Open Hole Top:	5910 ft.	Open Hole Bottom:	6445 ft.
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5910 ft.	# Of Holes:
Interval Bottom:	6445 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)	80647
GOR
GOR Determination	MCFE
Average BOE per Day	38.027
Average MCFE per Day	220.569

Federal Financial Assurance

Tribal Well