Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-10755		Well Classification: ERIW	Status: IJ - 10/12/2022
Well Name/No:	M.B. LARSON B #3 AX (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 #:	ID 053334
Facility Status:	IJ	Status Date	10/12/2022
FacilityID:	284715	LocationID:	316540
County:	RIO BLANCO #103	Location:	NWNE 22 2N103W 6
Field:	RANGELY - #72370	Elevation:	5579 ft.
Basin:	PICEANCE BASIN
Planned Location:	618FNL 2053 FEL	Lat/Long: 40.134189 / -108.940356	Lat/Long Source: Field Measured
As Drilled Location:	Footages Not Available	Lat/Long: 40.134403 / -108.940342	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 10/12/2022 Measured TD: 6889 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 10/12/2022
Wellbore Permit
Permit #:	20061343	Expiration Date:	5/10/2007
Proposed Depth/Form:	6897 ft.
Surface Mineral Owner Same:	Yes
Mineral Owner:	FEDERAL	Surface Owner:	FEDERAL
Unit:	RANGELY WEBR SD	Unit Number:	COC 47675X
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: , Unit Acreage: , Drill Unit:

Wellbore Completed
Completion Date:	10/28/2006
Spud Date:	9/16/2006	Spud Date Is:	ACTUAL
Measured TD:	6889 ft.	Measured PB depth:	6889 ft.
True Vertical TD:		True Vertical PB depth:
Bottom Hole Location:	Sec: Twp:	Footage: FL FL
Log Types:	PHOTO DENSITY/DUAL NEWTRON; ARRAY INDUCTION-SFL; HOLE VOLUME; CEMENT BOND.
Casing:	String Type: CONDUCTOR, Hole Size: , Size: 16 in., Top: 0 ft., Depth: 90 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: , Bottom: , Determination Method: CALC
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 2039 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 840, Top: 0 ft., Bottom: 2039 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6398 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 610, Top: 0 ft., Bottom: 6398 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3819 ft.		N	N
MORRISON	3914 ft.		N	N
CURTIS	4610 ft.		N	N
ENTRADA	4704 ft.		N	N
CARMEL	4854 ft.		N	N
NAVAJO	4904 ft.		N	N
CHINLE	5535 ft.		N	N
SHINARUMP	5635 ft.		N	N
MOENKOPI	5720 ft.		N	N
WEBER	6381 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 10/12/2022 Interval Top: 6398 ft. Interval Bottom: 6745 ft.

Completed Information for Formation WEBER

1st Production Date:	1/23/2007	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:
Treatment Date:	7/31/2025	Treatment End Date:	N/A
Treatment Summary:	Well work performed on UIC repair, POOH w/ both pkrs, RIH w/ CO BHA, tst csg, RBIH w/ new inj BHA and FL tbg, RDMO. Return to injection pending an approved Form 21 MIT.
Total fluid used in treatment (bbls):	1115	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):	1015	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	855	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:	10/7/2022	Treatment End Date:	10/7/2022
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL with mutual solvent and 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:	4/8/2022	Treatment End Date:	4/8/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/ 6% CITRIC ACID AND 35 BBLS WATER
Total fluid used in treatment (bbls):	140	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:	3/4/2021	Treatment End Date:	3/4/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/ 6% CITRIC ACID AND 48 BBLS WATER
Total fluid used in treatment (bbls):	143	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):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	48	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:	11/6/2019	Treatment End Date:	11/6/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT, 38 BBLS WATER.
Total fluid used in treatment (bbls):	85	Max pressure during treatment (psi):	2000
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:	7/20/2017	Treatment End Date:	7/20/2017
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 110 GALLONS SOLVENT, USED 130 BBLS FRESH WATER
Total fluid used in treatment (bbls):	180	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):	130	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	10/28/2006
Treatment Summary:

Tubing Size:	2.875 in.	Tubing Setting Depth:	6404 ft.
Tubing Packer Depth:	6317 ft.	Tubing Multiple Packer:
Open Hole Top:	6398 ft.	Open Hole Bottom:	6745 ft.
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6398 ft.	# Of Holes:
Interval Bottom:	6745 ft.	Hole Size:

All Designations		Date
Primary Well Designation: Defined Inactive i
Reported Plugged	N
Out Of Service Repurposed	N
Out Of Service	N
Inactive Exception	N
Noticed Inactive	N
Defined Inactive (UIC)	Y	Defined Inactive 04/30/2023
Low Producing	N

September 2024 - August 2025	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