Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06223		Well Classification: ERIW	Status: IJ - 12/12/2022
Well Name/No:	FEE #40 (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	12/12/2022
FacilityID:	229140	LocationID:	314621
County:	RIO BLANCO #103	Location:	NWSE 28 2N102W 6
Field:	RANGELY - #72370	Elevation:	5282 ft.
Planned Location:	1980FSL 1980 FEL	Lat/Long: 40.112166 / -108.845735	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.112240 / -108.845680	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 12/12/2022 Measured TD: 6490 ft. Vertical TD: 6490 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 12/12/2022
Wellbore Permit
Permit #:	100001	Expiration Date:	6/17/1981
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:	7/16/1985
Measured TD:	6490 ft.	Measured PB depth:	6484 ft.
True Vertical TD:	6490 ft.	True Vertical PB depth:
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 5726 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: 0 in., Size: 5 in., Top: 5532 ft., Depth: 6488 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:

Formation WEBR Formation Classification: ERIW Status: IJ - 12/12/2022 Interval Top: 5732 ft. Interval Bottom: 6422 ft.

Completed Information for Formation WEBER

1st Production Date:	7/24/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	12/9/2022	Treatment End Date:	12/9/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 GALLONS) 15% HCL, W/MUTUAL SOLVENT AND 35 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	82	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):	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:	11/29/2019	Treatment End Date:	11/29/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 GALLONS) 15% HCL, 6% CITRIC, MUSTOL AND 40 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	2300
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):	40	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:	12/9/2017	Treatment End Date:	12/10/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL AND 410 BBLS WATER WELL PLACED ON INJECTION 7/24/1985
Total fluid used in treatment (bbls):	505	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):	410	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:	8/4/2017	Treatment End Date:	8/4/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL WITH 80 BBLS WATER. WELL PLACED ON INJECTION 7/24/1985.
Total fluid used in treatment (bbls):	175	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):	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:	10/7/2016	Treatment End Date:	10/7/2016
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 110 GALLONS P-444 SOLVENT, 200 BBLS FRESH WATER
Total fluid used in treatment (bbls):	250	Max pressure during treatment (psi):	2472
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):	200	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	2/3/2010
Treatment Summary:	ACID STIMULATION 2/03/2010 PUMPED 4500 GALLONS OF 20% HCI ES THROUGH TUBING AT 6401' AVERAGE 3 BPM @ 2250 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6401 ft.
Tubing Packer Depth:	5388 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5732 ft.	# Of Holes:	132
Interval Bottom:	6422 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)	166429
GOR
GOR Determination	MCFE
Average BOE per Day	78.769
Average MCFE per Day	456.852

Federal Financial Assurance

Tribal Well