Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-09177		Well Classification: ERIW	Status: IJ - 10/22/2025
Well Name/No:	UNION PACIFIC #37AX-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 #:	47443
Facility Status:	IJ	Status Date	10/22/2025
FacilityID:	231507	LocationID:	315755
County:	RIO BLANCO #103	Location:	NWSE 29 2N102W 6
Field:	RANGELY - #72370	Elevation:	5281 ft.
Basin:	PICEANCE BASIN
Planned Location:	1942FSL 1797 FEL	Lat/Long: 40.112085 / -108.864126	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.112136 / -108.864199	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 10/22/2025 Measured TD: 6549 ft. Vertical TD: 6546 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 10/22/2025
Wellbore Permit
Permit #:	110000	Expiration Date:	10/26/1984
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEE	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:	9/13/1984
Measured TD:	6549 ft.	Measured PB depth:	6451 ft.
True Vertical TD:	6546 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: 2512 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 380, Top: 0 ft., Bottom: 2512 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6547 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1050, Top: , Bottom: 6547 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3060 ft.
MORRISON	3140 ft.
ENTRADA	3913 ft.
NAVAJO	4112 ft.
CHINLE	4721 ft.
WEBER	5574 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 10/22/2025 Interval Top: 5656 ft. Interval Bottom: 6088 ft.

Completed Information for Formation WEBER

1st Production Date:	9/21/1984	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	10/21/2025	Treatment End Date:	10/21/2025
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 170 bbls fresh water, no recycled fluids.
Total fluid used in treatment (bbls):	217	Max pressure during treatment (psi):	1900
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):	170	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	7/28/2025	Treatment End Date:	N/A
Treatment Summary:	This injection well was shut in 09/27/2023 for experiencing high casing pressure. UIC repair work completed, fished out packer and attempted to fish/mill up joints left in hole. Cleaned out well to 5881 feel (getting scale and metel in returns. Return well to injection pending an approved Form 21.
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:	3/28/2025	Treatment End Date:	3/28/2025
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):	2281
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:	9/18/2024	Treatment End Date:	9/18/2024
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:	9/26/2023	Treatment End Date:	9/26/2023
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH INHIBITOR AND 132 BBLS FRESH WATER
Total fluid used in treatment (bbls):	179	Max pressure during treatment (psi):	2438
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):	90	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	42	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):	2200
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):	80	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:	5/11/2017	Treatment End Date:	5/12/2017
Treatment Summary:	pumped 4000 gallons 15% HCL with 140 bbls fresh water starting 0.7 bpm @ 1400 psi
Total fluid used in treatment (bbls):	235	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):	140	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	5/3/2012
Treatment Summary:	BULLHEAD 3000 GALLONS 20% HCL AT 1.0 BPM @ 1750 PSI.
Formation Treatment
Treatment Date:	9/20/2010
Treatment Summary:	ACID STIMULATION 9-20-10 PUMPED 4000 GALLONS 20% HCL THROUGH COILED TUBING @ 60216'.
Formation Treatment
Treatment Date:	9/13/1984
Treatment Summary:	ACID STIMULATION 2/20/06 PUMPED 3000 GALS 15% HCI THROUGH TUBING.

Tubing Size:	2.875 in.	Tubing Setting Depth:	5630 ft.
Tubing Packer Depth:	5603 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5656 ft.	# Of Holes:	90
Interval Bottom:	6088 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