Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-10722		Well Classification: ERIW	Status: IJ - 6/25/2024
Well Name/No:	ASSOCIATED UNIT A #4X (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	6/25/2024
FacilityID:	284034	LocationID:	316524
County:	RIO BLANCO #103	Location:	NENE 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5492 ft.
Basin:	PICEANCE BASIN
Planned Location:	42FNL 120 FEL	Lat/Long: 40.150172 / -108.914669	Lat/Long Source: Field Measured
As Drilled Location:	Footages Not Available	Lat/Long: 40.150180 / -108.914690	Lat/Long Source: Field Measured


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

Wellbore #00 Wellbore Classification: OW Status: IJ - 6/25/2024 Measured TD: 6675 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: OW IJ - 6/25/2024
Wellbore Permit
Permit #:	20070677	Expiration Date:	4/9/2008
Proposed Depth/Form:	6792 ft.
Surface Mineral Owner Same:	No
Mineral Owner:	FEE	Surface Owner:	FEE
Unit:	RANGELY WEBER S	Unit Number:	COC47675X
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: , Unit Acreage: , Drill Unit:

Wellbore Completed
Completion Date:	6/20/2007
Spud Date:	4/1/2007	Spud Date Is:	ACTUAL
Measured TD:	6675 ft.	Measured PB depth:	6675 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	PHOTO DEN,DUAL NEU,ARRAY INDUCTION,CEMENT BOND
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: , Depth: 2070 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 780, Top: 0 ft., Bottom: 2070 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6547 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 630, Top: 2085 ft., Bottom: 6547 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3872 ft.		N	N
MORRISON	3971 ft.		N	N
CURTIS	4674 ft.		N	N
ENTRADA	4778 ft.		N	N
CARMEL	4918 ft.		N	N
NAVAJO	4995 ft.		N	N
CHINLE	5601 ft.		N	N
SHINARUMP	5737 ft.		N	N
MOENKOPI	5857 ft.		N	N
WEBER	6499 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 6/25/2024 Interval Top: 6493 ft. Interval Bottom: 6675 ft.

Completed Information for Formation WEBER

1st Production Date:	8/3/2009	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	6/21/2024	Treatment End Date:	6/21/2024
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH MUTUAL SOLVENT AND 38 BBLS WATER
Total fluid used in treatment (bbls):	85	Max pressure during treatment (psi):	2304
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):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	38	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:	6/20/2022	Treatment End Date:	6/20/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH MUTUAL SOLVENT AND 35 BBLS WATER
Total fluid used in treatment (bbls):	130	Max pressure during treatment (psi):	1900
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:	2/8/2021	Treatment End Date:	2/8/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH MUTUAL SOLVENT AND 46 BBLS WATER.
Total fluid used in treatment (bbls):	94	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):	48	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	46	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:	6/22/2020	Treatment End Date:	6/22/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W6% CITRIC ACID AND 45 BBLS WATER
Total fluid used in treatment (bbls):	92	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):	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:	5/26/2015	Treatment End Date:	5/26/2015
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	205	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):	110	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	6/8/2007
Treatment Summary:	PUMP 104 BBLS SCALE INHIBITOR@ 9 BPM 650 PSI PUMP 100,780# 20/40 RISIN COATED PROPPANT FROM 2 TO 8 BPM @ AVERAGE 917 PSI

Test Type	Measure
Tubing Size:	2.875 in.	Tubing Setting Depth:	6376 ft.
Tubing Packer Depth:	6290 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	3013
BBLS_OIL	32
CALC_BBLS_H2O	3013
CALC_BBLS_OIL	32
CALC_GOR	31
CALC_MCF_GAS	1
GRAVITY_OIL	34
MCF_GAS	1

Perforation Data:
Interval Top:	6493 ft.	# Of Holes:
Interval Bottom:	6675 ft.	Hole Size:

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