Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06326		Well Classification: ERIW	Status: IJ - 7/22/2021
Well Name/No:	HAGOOD M C #A-4 (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 #:
Facility Status:	IJ	Status Date	7/22/2021
FacilityID:	229235	LocationID:	314675
County:	RIO BLANCO #103	Location:	NENW 15 2N103W 6
Field:	RANGELY - #72370	Elevation:	5608 ft.
Planned Location:	0FL 0 FL	Lat/Long: 40.148394 / -108.944678	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.148530 / -108.944920	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: OW Status: IJ - 7/22/2021 Measured TD: 6743 ft. Vertical TD: 6743 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: OW IJ - 7/22/2021
Wellbore Permit
Permit #:	011239	Expiration Date:	6/26/2002
Prop Depth/Form:
Surface Mineral Owner Same:	Yes
Mineral Owner:	FEDERAL	Surface Owner:	FEDERAL
Unit:	RANGELY WEBER S	Unit Number:
Formation And Spacing:	Code: UNK , Formation: UNKNOWN , Order: 0 , Unit Acreage: 0, Drill Unit:
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 2-38 , Unit Acreage: , Drill Unit:

Wellbore Completed
Completion Date:	5/7/2002
Spud Date:	8/29/2001	Spud Date Is:	ACTUAL
Measured TD:	6743 ft.	Measured PB depth:	6743 ft.
True Vertical TD:	6743 ft.	True Vertical PB depth:	6743 ft.
Log Types:
Casing:	String Type: SURF, Hole Size: , Size: 13.375 in., Top: 0 ft., Depth: 364 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 270, Top: 0 ft., Bottom: 364 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6592 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 900, Top: , Bottom: 6592 ft., Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5.5 in., Top: 0 ft., Depth: 6407 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 214, Top: 0 ft., Bottom: 6407 ft., Determination Method: CALC
Additional Cement:	String Type: 1ST , Top: , Depth: 497 ft., Bottom: 497 ft., Sacks: 700, Method: Squeeze

Formation WEBR Formation Classification: ERIW Status: IJ - 7/22/2021 Interval Top: 6596 ft. Interval Bottom: 6743 ft.

Completed Information for Formation WEBER

1st Production Date:	5/10/2002	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	7/20/2021	Treatment End Date:	7/20/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/6% CITRIC ACID AND 40 BBLS WATER
Total fluid used in treatment (bbls):	135	Max pressure during treatment (psi):	2085
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:	10/8/2015	Treatment End Date:	10/8/2015
Treatment Summary:	Pump 165 gallons solvent and 4000 gallons 15% hcl @ 2046psi.
Total fluid used in treatment (bbls):	249	Max pressure during treatment (psi):	2046
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):	150	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:	12/4/2014	Treatment End Date:	12/4/2014
Treatment Summary:	PUMP 4000 GALLONS 15% AT 3.25 BPM @ 1700 PSI
Total fluid used in treatment (bbls):	217	Max pressure during treatment (psi):	1700
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):	122	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	8/4/2010
Treatment Summary:	ACID STIMULATION 08/04/20108 PUMPED 4000 GALLONS OF HEATED 20% HCI THROUGH TUBING AT 6362.8'
Formation Treatment
Treatment Date:	5/7/2002
Treatment Summary:	PRODUCER CONVERTED TO INJECTOR 08/04/2005

Test Type	Measure
Tubing Size:	2.875 in.	Tubing Setting Depth:	6362 ft.
Tubing Packer Depth:	6299 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
Initial Test Data:
Test Date:	N/A	Test Method:
Hours Tested:		Gas Type:
Gas Disposal:
BBLS_H2O	1178
BBLS_OIL	167
GRAVITY_OIL	34
MCF_GAS	50

Perforation Data:
Interval Top:	6596 ft.	# Of Holes:
Interval Bottom:	6743 ft.	Hole Size:

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)	125928
GOR
GOR Determination	MCFE
Average BOE per Day	59.422
Average MCFE per Day	344.659

Federal Financial Assurance

Tribal Well