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 - 8/1/2025
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	8/1/2025
FacilityID:	228732	LocationID:	314442
County:	RIO BLANCO #103	Location:	NWSE 22 2N103W 6
Field:	RANGELY - #72370	Elevation:	5598 ft.
Basin:	PICEANCE BASIN
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: ERIW Status: IJ - 8/1/2025 Measured TD: 7210 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 8/1/2025
Wellbore Permit
Permit #:	20065721	Expiration Date:	12/17/2007
Proposed 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:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
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: 0 ft., 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: 2500 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: IJ - 8/1/2025 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:
Treatment Date:	8/21/2025	Treatment End Date:	N/A
Treatment Summary:	Rig work performed Move in and Rig up AESC Rig #1 & Aux equipment. Roll out pkr fluid w/ 240 bbls of fresh wtr. Release 5 ½” Hydro-seal Pkr & L/D F.L. Prod tbg. Release 5 ½” Loc-set Pkr. C/O Scale from 6,529’ to PBTD @ 6,737’. RIH w/ Btm 5 ½” Loc-set Pkr. Set @ 6,303’. Have PLS set plug in profile. Test plug to 2,500 psi, good test. Test csg to 1,325 psi, good test. Roll in pkr fluid. L/D 2 7/8” W.S. P/U 5 ½” AS1-X pkr & 2 7/8” F.L. Prod tbg. Land well out in 14K of compression. N/D BOPS. N/U Injection Tree. Tested tbg to 2,500 psi for 5 mins, good. Pre-MIT test csg to 1,325 psi for 30 mins. 0 psi loss, good test. RDMO Rig. Job complete. Return to injection pending an approved Form 21, MIT scheduled for August 21, 2025. Note: No additional perforations were created as originally permitted.
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 Type:
Treatment Date:	8/5/2025	Treatment End Date:	N/A
Treatment Summary:	HIT repair, LD FL tbg and top pkr, cleanout to bottom pkr, PU YB FL tbg and top pkr, chart test csg. Return to service pending an approved Form 21.
Total fluid used in treatment (bbls):	514	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):	210	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	514	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:	6/16/2025	Treatment End Date:	6/16/2025
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 35 bbls fresh water.
Total fluid used in treatment (bbls):	82	Max pressure during treatment (psi):	2500
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):	0	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:	2/21/2025	Treatment End Date:	2/21/2025
Treatment Summary:	PUMPED 2000 GALONS (47.6 BBLS) 15% HCL w/SOLVENT AND 35 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	82	Max pressure during treatment (psi):	2700
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):	0	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:	12/15/2023	Treatment End Date:	12/15/2023
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) of 15% HCL w/Solvent and 55 bbls fresh water.
Total fluid used in treatment (bbls):	102	Max pressure during treatment (psi):	3800
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):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	55	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:	10/5/2022	Treatment End Date:	10/5/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH ADDITIVES AND 35 BBLS WATER
Total fluid used in treatment (bbls):	83	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):	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:	4/5/2022	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: 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