Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08029		Well Classification: ERIW	Status: IJ - 12/15/2022
Well Name/No:	FEE #113X (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	12/15/2022
FacilityID:	230367	LocationID:	315175
County:	RIO BLANCO #103	Location:	SESE 19 2N102W 6
Field:	RANGELY - #72370	Elevation:	5308 ft.
Planned Location:	147FSL 14 FEL	Lat/Long: 40.121705 / -108.876876	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.121695 / -108.876738	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 12/15/2022 Measured TD: 6558 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 12/15/2022
Wellbore Permit
Permit #:	10001	Expiration Date:	9/30/1977
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:	3/19/1981
Measured TD:	6558 ft.	Measured PB depth:	6525 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 775 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 425, Top: 0 ft., Bottom: 775 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6557 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 325, Top: 0 ft., Bottom: 6556 ft., Determination Method: CALC
Casing:	String Type: STAGE TOOL, Hole Size: , Size: , Top: , Depth: 3000 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: 3000 ft., Bottom: 6567 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3178 ft.
MORRISON	3266 ft.
ENTRADA	4054 ft.
NAVAJO	4256 ft.
WEBER	5747 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 12/15/2022 Interval Top: 5754 ft. Interval Bottom: 6459 ft.

Completed Information for Formation WEBER

1st Production Date:	11/1/1977	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	12/14/2022	Treatment End Date:	12/14/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/MUTUAL SOLVENT AND 35 BBLS 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:	7/13/2019	Treatment End Date:	7/13/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/3% CITRIC ACID AND 45 BBLS WATER.
Total fluid used in treatment (bbls):	92	Max pressure during treatment (psi):	2156
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):	45	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:	8/6/2017	Treatment End Date:	8/7/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL WITH 160 BBLS WATER
Total fluid used in treatment (bbls):	255	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):	160	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:	10/6/2016	Treatment End Date:	10/6/2016
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL AND 30 GALLONS MUSOL SOLVENT, 200 BBLS FRESH WATER
Total fluid used in treatment (bbls):	248	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):	48	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:	10/31/2014	Treatment End Date:	10/31/2014
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	234	Max pressure during treatment (psi):	2350
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):	139	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	3/10/2010
Treatment Summary:	ACID STIMULATION 3/10/2010 PUMPED 4000 GALLONS OF 20% HCI THROUGH END OF TUBING 5719.5' AT 1 BPM AT A STARTING PRESSURE OF 2572 PSI

Tubing Size:	2.875 in.	Tubing Setting Depth:	5719 ft.
Tubing Packer Depth:	5494 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5754 ft.	# Of Holes:	243
Interval Bottom:	6459 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)	104990
GOR
GOR Determination	MCFE
Average BOE per Day	49.600
Average MCFE per Day	287.694

Federal Financial Assurance

Tribal Well