Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-05708		Well Classification: ERIW	Status: IJ - 4/6/2022
Well Name/No:	M.B. LARSON C #3 (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 #:	D-053980
Facility Status:	IJ	Status Date	4/6/2022
FacilityID:	228732	LocationID:	314442
County:	RIO BLANCO #103	Location:	NWSE 22 2N103W 6
Field:	RANGELY - #72370	Elevation:	5598 ft.
Planned Location:	1980FSL 1980 FEL	Lat/Long: 40.126685 / -108.940118	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.126833 / -108.940081	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: OTH Status: AC - 8/1/2024 Measured TD: 7210 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: OTH AC - 8/1/2024
Wellbore Permit
Permit #:	20065721	Expiration Date:	12/17/2007
Prop Depth/Form:	6711 ft.
Surface Mineral Owner Same:	Yes
Mineral Owner:	FEDERAL	Surface Owner:	FEDERAL
Unit:	RANGELY WEBER S	Unit Number:	COC 47675X
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: , Unit Acreage: , Drill Unit:

Wellbore Completed
Completion Date:	N/A
Measured TD:	7210 ft.	Measured PB depth:	6734 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	CBL
Casing:	String Type: CONDUCTOR, Hole Size: , Size: 13.375 in., Top: 0 ft., Depth: 162 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 130, Top: 0 ft., Bottom: 162 ft., Determination Method: CALC
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 627 ft., Weight: 32 , Citings Type: ACTUAL
Cement:	Sacks: 200, Top: 0 ft., Bottom: 627 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6534 ft., Weight: 26 , Citings Type: ACTUAL
Cement:	Sacks: 1000, Top: , Bottom: 6534 ft., Determination Method: CALC
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5.5 in., Top: 0 ft., Depth: 6343 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 303, Top: 0 ft., Bottom: 7210 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3998 ft.		N	N
MORRISON	4072 ft.		N	N
CURTIS	4770 ft.		N	N
ENTRADA	4870 ft.		N	N
CARMEL	5023 ft.		N	N
NAVAJO	5077 ft.		N	N
CHINLE	5715 ft.		N	N
SHINARUMP	5806 ft.		N	N
MOENKOPI	5886 ft.	6103 ft.	N	N
WEBER	6530 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: AC - 8/1/2024 Interval Top: 6536 ft. Interval Bottom: 6677 ft.

Completed Information for Formation WEBER

1st Production Date:	9/29/2007	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	4/5/2022	Treatment End Date:	4/5/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 6% CITRIC ACID AND 40 BBLS WATER
Total fluid used in treatment (bbls):	87	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):	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:	7/15/2021	Treatment End Date:	7/19/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 6% CITRIC ACID AND 40 BBLS WATER
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	2180
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):	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:	4/2/2020	Treatment End Date:	4/2/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT AND 38 BBLS OF FRESH WATER
Total fluid used in treatment (bbls):	85	Max pressure during treatment (psi):	2480
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:	2/3/2019	Treatment End Date:	2/3/2019
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 110 GALLONS SOLVENT. 120 BBLS FRESH WATER
Total fluid used in treatment (bbls):	170	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):	48	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	120	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:	12/5/2016	Treatment End Date:	12/5/2016
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 110 GALLONS SOLVENT, 154 BBLS FRESH WATER
Total fluid used in treatment (bbls):	204	Max pressure during treatment (psi):	2330
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 Date:	12/10/2009
Treatment Summary:	ACID STIMULATION PUMPED 4000 GALLONS OF 20% HCI, AT AVERAGE RATE 3 BPM @ 1950 PSI

Tubing Size:	2.875 in.	Tubing Setting Depth:	6363 ft.
Tubing Packer Depth:	6281 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6536 ft.	# Of Holes:	360
Interval Bottom:	6677 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

August 2023 - July 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	92034
GOR
GOR Determination	MCFE
Average BOE per Day	42.656
Average MCFE per Day	247.403

Federal Financial Assurance

Tribal Well