Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08300		Well Classification: ERIW	Status: IJ - 8/21/2024
Well Name/No:	HAGOOD L N #A-16X (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	8/21/2024
FacilityID:	230632	LocationID:	315324
County:	RIO BLANCO #103	Location:	SESE 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5422 ft.
Basin:	PICEANCE BASIN
Planned Location:	276FSL 407 FEL	Lat/Long: 40.136525 / -108.915647	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.136610 / -108.915600	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: IJ - 8/21/2024 Measured TD: 6660 ft. Vertical TD: 6660 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 8/21/2024
Wellbore Permit
Permit #:	830552	Expiration Date:	10/8/1983
Proposed 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:	6/17/1985
Measured TD:	6660 ft.	Measured PB depth:	6660 ft.
True Vertical TD:	6660 ft.	True Vertical PB depth:
Casing:	String Type: CONDUCTOR, Hole Size: , Size: 16 in., Top: 0 ft., Depth: 53 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 93, Top: 0 ft., Bottom: 53 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 9.625 in., Top: 0 ft., Depth: 2993 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: 0 ft., Bottom: 2993 ft., Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6699 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1385, Top: , Bottom: 6699 ft., Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3512 ft.
MORRISON	3594 ft.
ENTRADA	4417 ft.
NAVAJO	4617 ft.
CHINLE	5258 ft.
WEBER	6132 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 8/21/2024 Interval Top: 6148 ft. Interval Bottom: 6615 ft.

Completed Information for Formation WEBER

1st Production Date:	6/6/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/20/2024	Treatment End Date:	8/20/2024
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/solvent and 35 bbls Fresh 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):	0	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:	6/23/2022	Treatment End Date:	6/23/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS ) 15% HCL WITH MUTUAL SOVENT AND 140 BBLS FRESH WATER
Total fluid used in treatment (bbls):	235	Max pressure during treatment (psi):	1000
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):	140	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:	3/23/2021	Treatment End Date:	3/23/2021
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/ 6% Citric acid and 50 bbls water.
Total fluid used in treatment (bbls):	97	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):	47	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	50	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:	3/17/2015	Treatment End Date:	3/17/2015
Treatment Summary:	PUMPED 15% HCL
Total fluid used in treatment (bbls):	395	Max pressure during treatment (psi):	500
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):	300	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:	6/4/2014	Treatment End Date:	6/4/2014
Treatment Summary:	PUMPED 15% HCL
Total fluid used in treatment (bbls):	245	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):	150	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized: PIPELINE
Formation Treatment
Treatment Date:	9/14/2011
Treatment Summary:	ACID STIMULATION WITH 4000 GALLONS 20% HCL THROUGH TUBING @ 6648' AT STARTING PRESSURE OF 400 PSI AT A RATE OF .7 BBLS PER MINUTE

Tubing Size:	2.875 in.	Tubing Setting Depth:	6649 ft.
Tubing Packer Depth:	6126 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6148 ft.	# Of Holes:	1569
Interval Bottom:	6615 ft.	Hole Size:	0.5 in.

All Designations		Date
Primary Well Designation: Defined Inactive i
Reported Plugged	N
Out Of Service Repurposed	N
Out Of Service	N
Inactive Exception	N
Noticed Inactive	N
Defined Inactive (UIC)	Y	Defined Inactive 04/30/2023
Low Producing	N

September 2024 - August 2025	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	0
GOR
GOR Determination
Average BOE per Day	0.000
Average MCFE per Day	0.000

Federal Financial Assurance

Tribal Well