Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-07560		Well Classification: ERIW	Status: IJ - 6/3/2025
Well Name/No:	UNION PACIFIC #91X-28 (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	6/3/2025
FacilityID:	229902	LocationID:	314926
County:	RIO BLANCO #103	Location:	NENW 28 2N102W 6
Field:	RANGELY - #72370	Elevation:	5293 ft.
Basin:	PICEANCE BASIN
Planned Location:	1207FNL 1423 FWL	Lat/Long: 40.117925 / -108.852625	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.118010 / -108.852710	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 6/3/2025 Measured TD: 6553 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 6/3/2025
Wellbore Permit
Permit #:	730734	Expiration Date:	1/12/1974
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:	N/A
Spud Date:	10/15/1973	Spud Date Is:	ACTUAL
Measured TD:	6553 ft.	Measured PB depth:	6535 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:
Casing:	String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 764 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 525, Top: 0 ft., Bottom: 764 ft., Determination Method: CALC
Casing:	String Type: SURF, Hole Size: 15 in., Size: 10.75 in., Top: 0 ft., Depth: 764 ft., Weight: 40.5 , Citings Type: COGCC
Cement:	Sacks: 525, Top: 0 ft., Bottom: 764 ft., Determination Method:
Casing:	String Type: 1ST, Hole Size: 10.75 in., Size: 7.625 in., Top: 0 ft., Depth: 747 ft., Weight: 26.4 , Citings Type: ACTUAL
Cement:	Sacks: 300, Top: 0 ft., Bottom: 747 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 15 in., Size: 7.625 in., Top: 0 ft., Depth: 761 ft., Weight: , Citings Type: COGCC
Cement:	Sacks: 300, Top: 0 ft., Bottom: 761 ft., Determination Method:
Casing:	String Type: 2ND, Hole Size: 6.75 in., Size: 5.5 in., Top: 0 ft., Depth: 6553 ft., Weight: 17 , Citings Type: COGCC
Cement:	Sacks: 550, Top: 2360 ft., Bottom: 6553 ft., Determination Method: CBL
Casing:	String Type: 1ST LINER, Hole Size: 7.625 in., Size: 5.5 in., Top: 0 ft., Depth: 6553 ft., Weight: 14 17 , Citings Type: ACTUAL
Cement:	Sacks: 550, Top: 0 ft., Bottom: 6553 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3232 ft.	3334 ft.	N	N
MORRISON	3334 ft.	3918 ft.	N	N
CURTIS	3918 ft.	4090 ft.	N	N
ENTRADA	4090 ft.	4240 ft.	N	N
CARMEL	4240 ft.	4310 ft.	N	N
NAVAJO	4310 ft.	4900 ft.	N	N
CHINLE	4900 ft.	5042 ft.	N	N
SHINARUMP	5042 ft.	5120 ft.	N	N
MOENKOPI	5120 ft.	5780 ft.	N	N
WEBER	5780 ft.	6553 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 6/3/2025 Interval Top: 5796 ft. Interval Bottom: 6513 ft.

Completed Information for Formation WEBER

1st Production Date:	2/2/1974	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	5/20/2025	Treatment End Date:	5/20/2025
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 150 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	197	Max pressure during treatment (psi):	2080
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):	60	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	150	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:	3/26/2025	Treatment End Date:	3/26/2025
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:	11/14/2023	Treatment End Date:	11/14/2023
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) WITH 15% HCL w/SOLVENT AND 35 BBLS OF 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:	5/23/2022	Treatment End Date:	5/23/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/ MUTUAL SOLVENT AND 35 BBLS WATER
Total fluid used in treatment (bbls):	130	Max pressure during treatment (psi):	2450
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:	1/19/2022	Treatment End Date:	1/19/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/ MUTUAL SOLVENT AND 72 BBLS WATER
Total fluid used in treatment (bbls):	167	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):	72	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:	11/14/2015	Treatment End Date:	11/14/2015
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL AND 245 GALLONS MUTUAL SOLVENT
Total fluid used in treatment (bbls):	301	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):	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:	8/16/2010
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS 20% HCL, AND OF COILED TUBING @ 6447.
Formation Treatment
Treatment Date:	5/3/2007
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS 15% HCI,EOT @ 5645'

Tubing Size:	2.875 in.	Tubing Setting Depth:	5778 ft.
Tubing Packer Depth:	5619 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5796 ft.	# Of Holes:	149
Interval Bottom:	6513 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