Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08299		Well Classification: ERIW	Status: IJ - 11/9/2022
Well Name/No:	FEE #116X (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	11/9/2022
FacilityID:	230631	LocationID:	315323
County:	RIO BLANCO #103	Location:	NENW 19 2N102W 6
Field:	RANGELY - #72370	Elevation:	5356 ft.
Planned Location:	1249FNL 1308 FWL	Lat/Long: 40.132345 / -108.890777	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.132370 / -108.890625	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 11/9/2022 Measured TD: 6610 ft. Vertical TD: 6610 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 11/9/2022
Wellbore Permit
Permit #:	840060	Expiration Date:	5/23/1985
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:	4/22/1985
Measured TD:	6610 ft.	Measured PB depth:	6520 ft.
True Vertical TD:	6610 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 9.625 in., Top: 0 ft., Depth: 2982 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 1050, Top: 0 ft., Bottom: 2982 ft., Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6609 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1080, Top: 4000 ft., Bottom: 6609 ft., Determination Method:
Casing:	String Type: STAGE TOOL, Hole Size: , Size: 7 in., Top: , Depth: 4000 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 960, Top: 0 ft., Bottom: 4000 ft., Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3407 ft.
MORRISON	3486 ft.
ENTRADA	4323 ft.
NAVAJO	4490 ft.
CHINLE	5114 ft.
WEBER	6009 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 11/9/2022 Interval Top: 6029 ft. Interval Bottom: 6520 ft.

Completed Information for Formation WEBER

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

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	11/8/2022	Treatment End Date:	11/8/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH INHIBITOR AND MUTUAL SOLVENT AND 35 BBLS OF 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:	9/21/2019	Treatment End Date:	9/21/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 6% CITRIC ACID, 40 BBLS OF WATER.
Total fluid used in treatment (bbls):	90	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):	50	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:	5/17/2017	Treatment End Date:	5/17/2017
Treatment Summary:	Pumped 4000 gallons 15% HCL and 240 bbls water at 0.75 bpm @ 1390 psi. First injection 5/1/1985
Total fluid used in treatment (bbls):	335	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):	240	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	8/12/2015	Treatment End Date:	N/A
Treatment Summary:	DOCUMENT PURPOSE IS TO VERIFY THE PERFORATION INTERVAL. ORIGINAL PERFORATIONS AT COMPLETION 6029-6421. WELL WORK IN APRIL 1985 ADDED PERFS AT 6445, 6498, 6512 AND 6520 WITH 3SPF.
Total fluid used in treatment (bbls):		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 Type:	ACID JOB
Treatment Date:	5/15/2015	Treatment End Date:	5/15/2015
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 Date:	7/29/2008
Treatment Summary:	ACIDIZE FORMATION WITH 4500 GALLONS HEATED 15% HCL, EOT @ 5961'.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6533 ft.
Tubing Packer Depth:	5913 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6029 ft.	# Of Holes:	147
Interval Bottom:	6520 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)	147260
GOR
GOR Determination	MCFE
Average BOE per Day	70.668
Average MCFE per Day	409.867

Federal Financial Assurance

Tribal Well