Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06150		Well Classification: ERIW	Status: IJ - 8/15/2023
Well Name/No:	FEE #65 (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	8/15/2023
FacilityID:	229072	LocationID:	314576
County:	RIO BLANCO #103	Location:	NWNW 20 2N102W 6
Field:	RANGELY - #72370	Elevation:	5303 ft.
Planned Location:	660FNL 660 FWL	Lat/Long: 40.134005 / -108.874356	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.134050 / -108.874690	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 8/15/2023 Measured TD: 6541 ft. Vertical TD: 6540 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 8/15/2023
Wellbore Permit
Permit #:	10001	Expiration Date:	2/24/2000
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:	12/21/1976
Measured TD:	6541 ft.	Measured PB depth:	0 ft.
True Vertical TD:	6540 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: , Size: 10.75 in., Top: 0 ft., Depth: 720 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6074 ft., Weight: 23,26 , Citings Type: ACTUAL
Cement:	Sacks: 1100, Top: , Bottom: 6074 ft., Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5 in., Top: 5894 ft., Depth: 6541 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 60, Top: 5894 ft., Bottom: 6541 ft., Determination Method:

Formation VLCC Formation Classification: ERIW Status: IJ - 8/15/2023 Interval Top: 6096 ft. Interval Bottom: 6509 ft.

Completed Information for Formation VOLCANICS

1st Production Date:	12/22/1976	Choke Size:
Formation Name:	VOLCANICS	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	2/6/2023	Treatment End Date:	2/6/2023
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH MUTUAL SOLVENT AND 35 BBLS FRESH WATER NOTE: CORRECTION TO NUMBER OF PERFS. FROM SEPT.1979
Total fluid used in treatment (bbls):	83	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):	48	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:

Tubing Size:	2.875 in.	Tubing Setting Depth:	5908 ft.
Tubing Packer Depth:	5823 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation VLCC.

Perforation Data:
Interval Top:	6096 ft.	# Of Holes:	186
Interval Bottom:	6509 ft.	Hole Size:	0.5 in.

Formation WEBR Formation Classification: ERIW Status: IJ - 7/15/2019 Interval Top: 6096 ft. Interval Bottom: 6509 ft.

Completed Information for Formation WEBER

1st Production Date:	12/22/1976	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	7/11/2019	Treatment End Date:	7/11/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL w/3% CITRIC ACID AND 85 BBLS WATER.
Total fluid used in treatment (bbls):	132	Max pressure during treatment (psi):	2250
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):	85	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:	2/18/2017	Treatment End Date:	2/18/2017
Treatment Summary:	PUMPED 4000 GALLONS HCL, 120 GALLONS MUSOL SOLVENT AND 200 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	298	Max pressure during treatment (psi):	1800
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 Type:	ACID JOB
Treatment Date:	5/14/2015	Treatment End Date:	5/14/2015
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	175	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):	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:	10/18/2013	Treatment End Date:	10/18/2013
Treatment Summary:	PUMPED 4000 GALLONS 15% HCLTHRU 1 1/4" COILED TUBING - EOT @ 6249'
Total fluid used in treatment (bbls):	95	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 Date:	9/30/2010
Treatment Summary:	ACID STIMULATIOMN 9/30/10 PUMPED 4000 GALS 20% HCL THROUGH TUBING @5997.6'
Formation Treatment
Treatment Date:	11/9/2007
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS 15% HCL, EOT @ 6240'.

Tubing Size:	2.875 in.	Tubing Setting Depth:	5908 ft.
Tubing Packer Depth:	5823 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6096 ft.	# Of Holes:	185
Interval Bottom:	6509 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)	100143
GOR
GOR Determination	MCFE
Average BOE per Day	47.566
Average MCFE per Day	275.883

Federal Financial Assurance

Tribal Well