Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06144		Well Classification: ERIW	Status: IJ - 5/31/2023
Well Name/No:	FEE #29 (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	5/31/2023
FacilityID:	229066	LocationID:	314571
County:	RIO BLANCO #103	Location:	NWNE 19 2N102W 6
Field:	RANGELY - #72370	Elevation:	5373 ft.
Planned Location:	800FNL 1980 FEL	Lat/Long: 40.133595 / -108.883796	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.133622 / -108.883793	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 5/31/2023 Measured TD:

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 5/31/2023
Wellbore Permit
Permit #:	100001	Expiration Date:	10/1/1977
Proposed 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:

Wellbore Completed
Completion Date:	9/28/1946
Spud Date:	7/31/1946	Spud Date Is:	ACTUAL
Measured TD:		Measured PB depth:
True Vertical TD:		True Vertical PB depth:
Log Types:
Casing:	String Type: SURF, Hole Size: , Size: 16 in., Top: 0 ft., Depth: 34 ft., Weight: 65 , Citings Type: ACTUAL
Cement:	Sacks: 60, Top: , Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6075 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 2ND, Hole Size: , Size: 10.75 in., Top: 0 ft., Depth: 1013 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 650, Top: , Bottom: , Determination Method:
Casing:	String Type: 3RD, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6075 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: , Bottom: , Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5.5 in., Top: 5913 ft., Depth: 6543 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 250, Top: , Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2172 ft.	2350 ft.	N	N
FRONTIER	3109 ft.	3192 ft.	N	N
MOWRY	3380 ft.		N	N
DAKOTA	3467 ft.		N	N
MORRISON	3542 ft.		N	N
CURTIS	4258 ft.		N	N
ENTRADA	4360 ft.		N	N
CARMEL	4508 ft.		N	N
NAVAJO	4560 ft.		N	N
CHINLE	5184 ft.		N	N
SHINARUMP	5312 ft.		N	N
MOENKOPI	5597 ft.		N	N
WEBER	6062 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 5/31/2023 Interval Top: 6106 ft. Interval Bottom: 6540 ft.

Completed Information for Formation WEBER

1st Production Date:	7/1/1977	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	5/23/2023	Treatment End Date:	5/23/2023
Treatment Summary:	PUMPED 163 BBLS 15% HCL & STIMWRX-DVG WITH MUTUAL SOLVENT AND 35 BBLS FRESH WATER
Total fluid used in treatment (bbls):	198	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):	163	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:	1/25/2023	Treatment End Date:	1/25/2023
Treatment Summary:	PUMPED 2016 GALLONS (47.9 BBL.)15% HCL WITH MUTUAL SOLVENT, 312 BBL. FRESH WATER
Total fluid used in treatment (bbls):	360	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):	48	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	312	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:	5/17/2022	Treatment End Date:	5/17/2022
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH MUTUAL SOLVENT, 35 BBLS FRESH WATER
Total fluid used in treatment (bbls):	82	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):	47	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:	3/28/2020	Treatment End Date:	3/28/2020
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 1.9 BBLS MUTUAL SOLVENT, 38 BBLS FRESH WATER
Total fluid used in treatment (bbls):	85	Max pressure during treatment (psi):	850
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):	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:	2/9/2019	Treatment End Date:	2/9/2019
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 110 GALLONS SOLVENT, 110 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	160	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):	48	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 Type:	ACID JOB
Treatment Date:	11/15/2017	Treatment End Date:	11/16/2017
Treatment Summary:	CORRECTED NUMBER OF PERF HOLES AND THE FIRST INJECTION 7/1/1977 PUMPED 3800 GALLONS 15% HCL WITH 360 BBLS WATER
Total fluid used in treatment (bbls):	450	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):	90	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	360	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:	10/1/2015	Treatment End Date:	10/1/2015
Treatment Summary:	PUMP 165 GALLONS MOSUL SOLVENT AND 4000 GALLONS 15% HCL AT 3.0 BPM @ 2083 PSI
Total fluid used in treatment (bbls):	279	Max pressure during treatment (psi):	2303
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):	180	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:	2/27/2013	Treatment End Date:	2/27/2013
Treatment Summary:	COILED TUBING UNIT ACID JOB.
Total fluid used in treatment (bbls):	263	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):	23	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	240	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	9/28/1946
Treatment Summary:

Tubing Size:	2.875 in.	Tubing Setting Depth:	5653 ft.
Tubing Packer Depth:	5598 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6106 ft.	# Of Holes:	64
Interval Bottom:	6540 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

December 2023 - November 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	187315
GOR
GOR Determination	MCFE
Average BOE per Day	88.639
Average MCFE per Day	514.103

Federal Financial Assurance

Tribal Well