Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-09284		Well Classification: ERIW	Status: IJ - 10/27/2025
Well Name/No:	UNION PACIFIC #52A-29 (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 #:
Facility Status:	IJ	Status Date	10/27/2025
FacilityID:	231613	LocationID:	315807
County:	RIO BLANCO #103	Location:	SENW 29 2N102W 6
Field:	RANGELY - #72370	Elevation:	5253 ft.
Basin:	PICEANCE BASIN
Planned Location:	1854FNL 2101 FWL	Lat/Long: 40.116195 / -108.869276	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.116230 / -108.869181	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 10/27/2025 Measured TD: 6480 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 10/27/2025
Wellbore Permit
Permit #:	860829	Expiration Date:	4/8/1987
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	3/19/1987
Measured TD:	6480 ft.	Measured PB depth:	6421 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 2100 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 680, Top: 0 ft., Bottom: 2100 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6480 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1150, Top: , Bottom: 6480 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3067 ft.
MORRISON	3170 ft.
ENTRADA	3932 ft.
NAVAJO	4149 ft.
CHINLE	4742 ft.
WEBER	5606 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 10/27/2025 Interval Top: 5626 ft. Interval Bottom: 6243 ft.

Completed Information for Formation WEBER

1st Production Date:	3/19/1987	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	10/22/2025	Treatment End Date:	10/22/2025
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 180 bbls fresh water, 170 bbls fresh water recycled.
Total fluid used in treatment (bbls):	227	Max pressure during treatment (psi):	1700
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):	170	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	180	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:	10/17/2024	Treatment End Date:	10/17/2024
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 34 bbls Fresh water.
Total fluid used in treatment (bbls):	81	Max pressure during treatment (psi):	2321
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):	34	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:	11/10/2023	Treatment End Date:	11/10/2023
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) WITH 15% HCL w/SOLVENT AND 35 BBLS OF WATER.
Total fluid used in treatment (bbls):	130	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):	95	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:	11/9/2022	Treatment End Date:	11/9/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH INHIBITOR AND MUTUAL SOLVENT, 35 BBLS OF WATER.
Total fluid used in treatment (bbls):	130	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):	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:	9/22/2020	Treatment End Date:	9/22/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 6% CITRIC ACID, 60 BBLS OF WATER.
Total fluid used in treatment (bbls):	147	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):	60	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:	9/13/2019	Treatment End Date:	9/13/2019
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):	2300
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):	90	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:	8/13/2015	Treatment End Date:	8/13/2015
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL WITH 195 GALLONS MUSOL SOLVENT
Total fluid used in treatment (bbls):	299	Max pressure during treatment (psi):	2439
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:	3/16/2012
Treatment Summary:	STIMULATION WITH 4000 GALLONS 15% HCL.
Formation Treatment
Treatment Date:	4/14/2010
Treatment Summary:	ACID STIMULATION 8-10-2009 PUMPED 4000 GALLONS OF 20% HCL THROUGH TUBING AT 5494.8'. AVERAGE 2.8 BPM @ 1845 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	5495 ft.
Tubing Packer Depth:	5410 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5626 ft.	# Of Holes:	129
Interval Bottom:	6243 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