Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-60003		Well Classification: ERIW	Status: IJ - 11/9/2022
Well Name/No:	W. P. MELLEN #1 (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	11/9/2022
FacilityID:	232375	LocationID:	316724
County:	RIO BLANCO #103	Location:	SENE 16 2N103W 6
Field:	RANGELY - #72370	Elevation:	5623 ft.
Planned Location:	1980FNL 660 FEL	Lat/Long: 40.144774 / -108.954139	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.144975 / -108.954261	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: STRT Status: IJ - 11/9/2022 Measured TD: 7361 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: STRT IJ - 11/9/2022
Wellbore Permit
Permit #:	870742	Expiration Date:	2/10/1988
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:	D-052489
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	3/4/1947
Spud Date:	12/17/1947	Spud Date Is:	ACTUAL
Measured TD:	7361 ft.	Measured PB depth:	6775 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	1947-SP/RESISTIVITY; RADIOACTIVITY
Casing:	String Type: CONDUCTOR, Hole Size: 22 in., Size: 16 in., Top: 0 ft., Depth: 38 ft., Weight: 55 , Citings Type: ACTUAL
Cement:	Sacks: 50, Top: 0 ft., Bottom: 38 ft., Determination Method: CALC
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 10.75 in., Top: 0 ft., Depth: 700 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 500, Top: , Bottom: 700 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 9 in., Size: 7 in., Top: 0 ft., Depth: 6683 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: , Bottom: 6688 ft., Determination Method: CALC
Casing:	String Type: OPEN HOLE, Hole Size: , Size: , Top: 6683 ft., Depth: 6777 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: , Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2887 ft.		N	N
FRONTIER	3790 ft.		N	N
MOWRY	4030 ft.		N	N
DAKOTA	4109 ft.		N	N
MORRISON	4210 ft.		N	N
CURTIS	4902 ft.		N	N
ENTRADA	5005 ft.		N	N
CARMEL	5152 ft.		N	N
NAVAJO	5208 ft.		N	N
CHINLE	5842 ft.		Y	N
WEBER	6675 ft.		Y	N

Formation WEBR Formation Classification: ERIW Status: IJ - 11/9/2022 Interval Top: 6688 ft. Interval Bottom: 6775 ft.

Completed Information for Formation WEBER

1st Production Date:	6/17/1989	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	11/7/2022	Treatment End Date:	11/7/2022
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL with additives, inhibitor, mutual solvent and 35 bbls fresh water.
Total fluid used in treatment (bbls):	130	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):	35	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	2/25/2022	Treatment End Date:	N/A
Treatment Summary:	WELLWORK CONSISTED OF PULLING THE INJECTION TUBING BOTH TOP AND BOTTOM PACKERS. RAN NEW PACKERS, YELLOWBAND TUBING AND ADDED TM-40 SPOOL AND HANGER. PRESSURE TEST AND WELLBORE SCHEMATIC ATTACHED. WELL WILL BE RETURNED TO INJECTION PENDING AN APPROVED MIT. ATTACHED IS THE WELLBORE SCHEMATIC.
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:	12/28/2021	Treatment End Date:	12/28/2021
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15%HCL with 6% citric acid and inhibitor and 47 bbls fresh water.
Total fluid used in treatment (bbls):	142	Max pressure during treatment (psi):	2000
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):	47	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:	3/3/2021	Treatment End Date:	3/3/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH 6% CITRIC ACID AND 50 BBLS WATER
Total fluid used in treatment (bbls):	145	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):	95	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:
Treatment Date:	1/20/2017	Treatment End Date:	N/A
Treatment Summary:	CORRECTION TO TUBING AND PACKER DEPTHS REPORTED ON FORM 21 DOCUMENT #401109667
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 Date:	9/5/2007
Treatment Summary:	8/28/2007 PLUG BACK OPEN HOLE 7306-6775', PUMP 300 SKS CLASS G, 62 BBLS SLURRY @1.5 BPM @225 PSI. 9/4/2007 PERF 6765-6688' IN THREE RUNS WITH 3 SPF @120 DEGREE PHASING. 9/5/2007 PUMP 4200 GAL HEATED 15% HCL ACROSS PERFS 6688-6765' @3.2 BPM @1163 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6536 ft.
Tubing Packer Depth:	6448 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6688 ft.	# Of Holes:
Interval Bottom:	6775 ft.	Hole Size:	0.42 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)	168499
GOR
GOR Determination	MCFE
Average BOE per Day	78.727
Average MCFE per Day	456.612

Federal Financial Assurance

Tribal Well