Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-07475		Well Classification: ERIW	Status: IJ - 10/1/2025
Well Name/No:	LEVISON #32X (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	10/1/2025
FacilityID:	229818	LocationID:	314880
County:	RIO BLANCO #103	Location:	SESE 27 2N102W 6
Field:	RANGELY - #72370	Elevation:	5327 ft.
Basin:	PICEANCE BASIN
Planned Location:	1301FSL 1253 FEL	Lat/Long: 40.110296 / -108.824324	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.110350 / -108.824430	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 10/1/2025 Measured TD: 6472 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 10/1/2025
Wellbore Permit
Permit #:	10001	Expiration Date:	12/31/1972
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEE	Surface Owner:	Not available
Unit:		Unit Number:	D-052561
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	12/17/1981
Measured TD:	6472 ft.	Measured PB depth:	6470 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 785 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 525, Top: 0 ft., Bottom: 785 ft., Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6471 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 700, Top: 600 ft., Bottom: 6471 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3332 ft.
MORRISON	3420 ft.
CURTIS	4032 ft.
ENTRADA	4155 ft.
CARMEL	4305 ft.
NAVAJO	4367 ft.
CHINLE	4955 ft.
SHINARUMP	5110 ft.
MOENKOPI	5187 ft.
WEBER	5828 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 10/1/2025 Interval Top: 5834 ft. Interval Bottom: 6441 ft.

Completed Information for Formation WEBER

1st Production Date:	11/9/1972	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:
Treatment Date:	4/29/2025	Treatment End Date:	N/A
Treatment Summary:	PER MOU REPORTING ON/OFF TOOL SET AT 5569'.
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:	12/11/2024	Treatment End Date:	N/A
Treatment Summary:	UIC Failure. Isolated csg holes from 182'-187'. Perf'd 850' per COGCC request. No inj. Ran CBL, good bond to 600'. Perf 550'. Set CICR @488', pump 50 sks circulating to surf, sting out and then pump 35 sks through holes @187'. Upgrade WH. DO cmt and cicr. Still leaking. Pump 2 - 320 gal 300 psi treatments on leak. Run new FL inj tbg and AS1 pkr. Return to injection pending an approved Form 21. MIT scheduled.
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:	ACID JOB
Treatment Date:	3/28/2024	Treatment End Date:	3/28/2024
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 37 bbls fresh water.
Total fluid used in treatment (bbls):	84	Max pressure during treatment (psi):	2145
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):	37	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	12/7/2017	Treatment End Date:	N/A
Treatment Summary:	COA from document # 401254688, provide current tubing and packer depths FIRST INJECTION 2/3/1976
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:	ACID JOB
Treatment Date:	12/11/2014	Treatment End Date:	12/11/2014
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	295	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):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	200	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	3/21/2012
Treatment Summary:	PUMP 4000 GALLONS 15% HCL AT 2.5 BPM @ 2000 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	5615 ft.
Tubing Packer Depth:	5530 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5834 ft.	# Of Holes:	128
Interval Bottom:	6441 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