Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06262		Well Classification: ERIW	Status: IJ - 4/21/2023
Well Name/No:	UNION PACIFIC #60-31 (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	4/21/2023
FacilityID:	229177	LocationID:	311803
County:	RIO BLANCO #103	Location:	SENE 31 2N102W 6
Field:	RANGELY - #72370	Elevation:	5277 ft.
Planned Location:	1955FNL 636 FEL	Lat/Long: 40.101441 / -108.878902	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.101313 / -108.879037	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 4/21/2023 Measured TD: 6186 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 4/21/2023
Wellbore Permit
Permit #:	100001	Expiration Date:	2/24/2000
Prop 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:	6/20/1948
Measured TD:	6186 ft.	Measured PB depth:	0 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: CONDUCTOR, Hole Size: 19 in., Size: 16 in., Top: 0 ft., Depth: 60 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 100, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 10.75 in., Top: 0 ft., Depth: 539 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 5645 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	1787 ft.
FRONTIER	2690 ft.
MOWRY	2956 ft.
DAKOTA	3046 ft.
MORRISON	3105 ft.
CURTIS	3758 ft.
ENTRADA	3887 ft.
CARMEL	4035 ft.
NAVAJO	4087 ft.
CHINLE	4688 ft.
SHINARUMP	4812 ft.
MOENKOPI	4888 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 4/21/2023 Interval Top: 5670 ft. Interval Bottom: 6245 ft.

Completed Information for Formation WEBER

1st Production Date:	5/29/1977	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	4/20/2023	Treatment End Date:	4/20/2023
Treatment Summary:	PUMP 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT AND 35 BBLS 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):		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:	1/14/2022	Treatment End Date:	1/14/2022
Treatment Summary:	PUMP 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT AND 98 BBLS WATER
Total fluid used in treatment (bbls):	145	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	98	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:	1/14/2019	Treatment End Date:	1/14/2019
Treatment Summary:	PUMP 2000 GALLONS 15% HCL WITH 150 BBLS WATER
Total fluid used in treatment (bbls):	197	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		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:	2/16/2017	Treatment End Date:	2/16/2017
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL, 110 GALLONS SOLVENT AND 153.8 BBLS FRESH WATER
Total fluid used in treatment (bbls):	204	Max pressure during treatment (psi):	2595
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):	153	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:	4/19/2016	Treatment End Date:	4/19/2016
Treatment Summary:	PERFORATION FROM 5630-6120 OPEN HOLE FROM 6185-6245 PUMPED 110 GALLONS MUSUL SOLVENT AND 2000 GALLONS 15% HCL AT 1.5 BPM @ 2470 PSI, FLUSH WITH 170 BBLS WATER
Total fluid used in treatment (bbls):	220	Max pressure during treatment (psi):	2470
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):	170	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	5/12/2006
Treatment Summary:	ACID STIMULATION BY PUMPING 3000 GALS 15% HCL THROUGH TUBING @ A DEPTH OF 6176'

Tubing Size:	2.875 in.	Tubing Setting Depth:	6156 ft.
Tubing Packer Depth:	5306 ft.	Tubing Multiple Packer:
Open Hole Top:	6185 ft.	Open Hole Bottom:	6245 ft.
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5670 ft.	# Of Holes:
Interval Bottom:	6245 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

June 2023 - May 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	227454
GOR
GOR Determination	MCFE
Average BOE per Day	107.163
Average MCFE per Day	621.515

Federal Financial Assurance

Tribal Well