Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08687		Well Classification: ERIW	Status: IJ - 7/1/2024
Well Name/No:	FEE #127X (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	7/1/2024
FacilityID:	231018	LocationID:	315547
County:	RIO BLANCO #103	Location:	SENW 20 2N102W 6
Field:	RANGELY - #72370	Elevation:	6534 ft.
Planned Location:	1439FNL 1325 FWL	Lat/Long: 40.131865 / -108.872006	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.131860 / -108.871960	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 7/1/2024 Measured TD: 6544 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 7/1/2024
Wellbore Permit
Permit #:	810329	Expiration Date:	7/1/1981
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:	5/16/1984
Measured TD:	6544 ft.	Measured PB depth:	6515 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 3007 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 670, Top: 0 ft., Bottom: 3007 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6544 ft., Weight: 23,26 , Citings Type: ACTUAL
Cement:	Sacks: 300, Top: 5050 ft., Bottom: 6544 ft., Determination Method: CBL
Casing:	String Type: STAGE TOOL, Hole Size: , Size: 7 in., Top: , Depth: 4750 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 645, Top: 2450 ft., Bottom: 4750 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3421 ft.
MORRISON	3503 ft.
ENTRADA	4390 ft.
NAVAJO	4521 ft.
CHINLE	5124 ft.
WEBER	6019 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 7/1/2024 Interval Top: 6038 ft. Interval Bottom: 6463 ft.

Completed Information for Formation WEBER

1st Production Date:	5/16/1984	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:
Treatment Date:	11/29/2022	Treatment End Date:	N/A
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH 35 BBLS WATER
Total fluid used in treatment (bbls):	130	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):	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:	7/11/2019	Treatment End Date:	7/11/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 3% CITRIC ACID
Total fluid used in treatment (bbls):	47	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):		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:	5/15/2017	Treatment End Date:	5/15/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL AND 160 BBLS FRESH WATER AT STARTING RATE OF 0.9 BPM @ 1430 PSI
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:	10/9/2015	Treatment End Date:	N/A
Treatment Summary:	PUMP 165 GALLONS SOLVENT AND 4000 GALLONS 15% HCL AT 2.0 BPM
Total fluid used in treatment (bbls):	279	Max pressure during treatment (psi):	2334
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):	180	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:	7/21/2014	Treatment End Date:	7/21/2014
Treatment Summary:	ACID STIMULATION, PUMPED 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	270	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):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	95	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 Date:	4/2/2007
Treatment Summary:	ACID STIMULATION 4/2/07 PUMPED 4000 GALLONS 15% HCL THROUGH TUBING AT 6254" 6038-6463

Tubing Size:	2.875 in.	Tubing Setting Depth:	6475 ft.
Tubing Packer Depth:	5910 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6038 ft.	# Of Holes:	126
Interval Bottom:	6463 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

August 2023 - July 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	111536
GOR
GOR Determination	MCFE
Average BOE per Day	52.728
Average MCFE per Day	305.825

Federal Financial Assurance

Tribal Well