Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-09893		Well Classification: ERIW	Status: IJ - 2/10/2021
Well Name/No:	MAGOR #1A (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	2/10/2021
FacilityID:	232222	LocationID:	316136
County:	RIO BLANCO #103	Location:	SENE 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5535 ft.
Planned Location:	1925FNL 510 FEL	Lat/Long: 40.144915 / -108.915977	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.145020 / -108.915980	Lat/Long Source: Field Measured


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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 2/10/2021 Measured TD: 6750 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 2/10/2021
Wellbore Permit
Permit #:	980230	Expiration Date:	3/2/1999
Prop Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEE	Surface Owner:	Not available
Unit:		Unit Number:
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit: U

Wellbore Completed
Completion Date:	6/14/1998
Spud Date:	5/27/1998	Spud Date Is:	ACTUAL
Measured TD:	6750 ft.	Measured PB depth:	6700 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	DENSITY-NEUTRON
Log Types:	NO NEW LOGS
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 8.625 in., Top: 0 ft., Depth: 1020 ft., Weight: 24 , Citings Type: ACTUAL
Cement:	Sacks: 540, Top: 0 ft., Bottom: 1020 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 7.875 in., Size: 5.5 in., Top: 0 ft., Depth: 6750 ft., Weight: 15.5 , Citings Type: ACTUAL
Cement:	Sacks: 960, Top: 0 ft., Bottom: 6750 ft., Determination Method: CBL
Additional Cement:	String Type: 1ST , Top: 4410 ft., Depth: 4647 ft., Bottom: 4582 ft., Sacks: 50, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
MANCOS	0 ft.
NIOBRARA	2500 ft.
FRONTIER	3452 ft.
MOWRY	3666 ft.
DAKOTA	3803 ft.
MORRISON	3884 ft.
CURTIS	4600 ft.
ENTRADA	4702 ft.
CARMEL	4845 ft.
NAVAJO	4896 ft.
CHINLE	5530 ft.
SHINARUMP	5660 ft.
MOENKOPI	5735 ft.
WEBER	6423 ft.	6750 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 2/10/2021 Interval Top: 6439 ft. Interval Bottom: 6654 ft.

Completed Information for Formation WEBER

1st Production Date:	7/10/1998	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	2/9/2021	Treatment End Date:	2/9/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH MUTUAL SOLVENT AND 56 BBLS FRESH WATER
Total fluid used in treatment (bbls):	103	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):	56	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 WITH MUTUAL SOLVENT AND 47 BBLS FRESH WATER
Total fluid used in treatment (bbls):	94	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):	47	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:
Treatment Date:	10/6/2017	Treatment End Date:	N/A
Treatment Summary:	Squeeze casing leak with 50 sks cement, Form 5 submitted 401421877.
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:
Treatment Date:	6/13/2017	Treatment End Date:	N/A
Treatment Summary:	TUBING PLUG WAS SET AT 6418' ON 4/4/17. TOP PERFORATION CORRECTED TO 6439' (CONTRACTOR WELLBORE SCHEMATIC WRONG).
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:	10/13/2011
Treatment Summary:	ACID STIMULATION WITH 4000 GALLONS 20% HCL THROUGH END OF TUBING @ 6634'.
Formation Treatment
Treatment Date:	8/4/1998
Treatment Summary:	ACID STIMULATION 10-10-07 PUMPED 4000 GALLONS 15% HCI THROUGH TUBING.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6414 ft.
Tubing Packer Depth:	6328 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6439 ft.	# Of Holes:	68
Interval Bottom:	6654 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

August 2023 - July 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	214071
GOR
GOR Determination	MCFE
Average BOE per Day	102.727
Average MCFE per Day	595.815

Federal Financial Assurance

Tribal Well