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 - 5/31/2022
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	5/31/2022
FacilityID:	229902	LocationID:	314926
County:	RIO BLANCO #103	Location:	NENW 28 2N102W 6
Field:	RANGELY - #72370	Elevation:	5293 ft.
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: DSPW Status: IJ - 5/31/2022 Measured TD: 6553 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 5/31/2022
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:	12/7/1973
Measured TD:	6553 ft.	Measured PB depth:	6535 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: 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: 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
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3232 ft.
MORRISON	3334 ft.
CURTIS	3918 ft.
ENTRADA	4090 ft.
CARMEL	4240 ft.
NAVAJO	4310 ft.
CHINLE	4900 ft.
SHINARUMP	5042 ft.
MOENKOPI	5120 ft.
WEBER	5780 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 5/31/2022 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:	No

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: None i
Reported Plugged	N
Out Of Service Repurposed	N
Out Of Service	N
Inactive Exception	N
Noticed Inactive	N
Defined Inactive	N
Low Producing	N

December 2023 - November 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	43316
GOR
GOR Determination	MCFE
Average BOE per Day	20.437
Average MCFE per Day	118.541

Federal Financial Assurance

Tribal Well