Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-05736		Well Classification: ERIW	Status: IJ - 12/1/2023
Well Name/No:	HAGOOD L N #A-5 (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	12/1/2023
FacilityID:	228756	LocationID:	314455
County:	RIO BLANCO #103	Location:	SENE 23 2N103W 6
Field:	RANGELY - #72370	Elevation:	5427 ft.
Planned Location:	1980FNL 660 FEL	Lat/Long: 40.130335 / -108.916587	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.130390 / -108.916530	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 12/1/2023 Measured TD: 6610 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 12/1/2023
Wellbore Permit
Permit #:	10001	Expiration Date:	2/24/2000
Prop Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:	D-033586
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	11/15/1980
Measured TD:	6610 ft.	Measured PB depth:	6550 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6014 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5 in., Top: 5843 ft., Depth: 6610 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 300, Top: 5843 ft., Bottom: 6610 ft., Determination Method: CALC

Formation WEBR Formation Classification: ERIW Status: IJ - 12/1/2023 Interval Top: 6014 ft. Interval Bottom: 6164 ft.

Completed Information for Formation WEBER

1st Production Date:	10/16/1977	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	10/6/2022	Treatment End Date:	10/6/2022
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL with mutual solvent and 35 bbls water.
Total fluid used in treatment (bbls):	83	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):	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:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	12/9/2021	Treatment End Date:	12/9/2021
Treatment Summary:	PUMPED 2000 BALLONS (47.6 BBLS) 15% HCL W/MUTUAL SOLVENT AND 63 BBLS FRESH WATER
Total fluid used in treatment (bbls):	110	Max pressure during treatment (psi):	2200
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):	63	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:	6/30/2021	Treatment End Date:	6/30/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/MUTUAL SOLVENT, 45 BBLS WATER
Total fluid used in treatment (bbls):	92	Max pressure during treatment (psi):	2180
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:	4/27/2020	Treatment End Date:	4/27/2020
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) of 15% HCL with 6% citric inhibitor with 60 bbls of fresh water.
Total fluid used in treatment (bbls):	107	Max pressure during treatment (psi):	2100
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):	60	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:	4/9/2020	Treatment End Date:	4/9/2020
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL and 70 bbls fresh water.
Total fluid used in treatment (bbls):	117	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	70	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:	4/9/2019	Treatment End Date:	4/10/2019
Treatment Summary:	Pumped 4000 gallons 15% HCL with 95 gallons solvent, 40 bbls fresh water.
Total fluid used in treatment (bbls):	135	Max pressure during treatment (psi):	1910
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):	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:	3/19/2015	Treatment End Date:	3/19/2015
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	204	Max pressure during treatment (psi):	1200
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):	112	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	4/13/2010
Treatment Summary:	ACIDIZE FORMATION WITH 400 GALLSON HEATED 20% HCI, EOT @ 6700 STARTING 1.7 BPM @ 2200 PSI
Formation Treatment
Treatment Date:	2/25/2009
Treatment Summary:	ACIDIZE FORMATION W/4000 GALS HEATED 20% HCI, EOT @ 6700'

Tubing Size:	2.875 in.	Tubing Setting Depth:	5854 ft.
Tubing Packer Depth:	5759 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6014 ft.	# Of Holes:	450
Interval Bottom:	6164 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)	254114
GOR
GOR Determination	MCFE
Average BOE per Day	120.621
Average MCFE per Day	699.595

Federal Financial Assurance

Tribal Well