Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08041		Well Classification: ERIW	Status: IJ - 10/29/2025
Well Name/No:	EMERALD #63X (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	10/29/2025
FacilityID:	230379	LocationID:	315184
County:	RIO BLANCO #103	Location:	NWSE 25 2N103W 6
Field:	RANGELY - #72370	Elevation:	5404 ft.
Basin:	PICEANCE BASIN
Planned Location:	2631FSL 2508 FEL	Lat/Long: 40.114017 / -108.904283	Lat/Long Source: Field Measured
As Drilled Location:	Footages Not Available	Lat/Long: 40.114017 / -108.904283	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: DSPW Status: AB - 1/14/2013 Measured TD: 6659 ft. Vertical TD: 0 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW AB - 1/14/2013
Wellbore Permit
Permit #:	10001	Expiration Date:	10/3/1977
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:	10/14/1980
Measured TD:	6659 ft.	Measured PB depth:	6658 ft.
True Vertical TD:	0 ft.	True Vertical PB depth:
Casing:	String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 799 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 425, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6659 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3171 ft.
MORRISON	3261 ft.
ENTRADA	4034 ft.
NAVAJO	4236 ft.
WEBER	5709 ft.

Formation WEBR Formation Classification: GW Status: AB - 1/14/2013 Interval Top: 5755 ft. Interval Bottom: 6536 ft.

Completed Information for Formation WEBER

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

Formation Treatment
Treatment Date:	4/30/2007
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS 15% HCL, EOT @ 6100'

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

Perforation Data:
Interval Top:	5755 ft.	# Of Holes:	200
Interval Bottom:	6536 ft.	Hole Size:	0.25 in.

Sidetrack #01 Wellbore Classification: ERIW Status: IJ - 10/29/2025 Measured TD: 6562 ft.

Wellbore Data for Sidetrack #01		Wellbore Classification: ERIW IJ - 10/29/2025
Wellbore Permit
Permit #:		Expiration Date:	7/30/2014
Proposed Depth/Form:	6558 ft.
Surface Mineral Owner Same:	Yes
Mineral Owner:	FEE	Surface Owner:	FEE
Unit:	RANGELY	Unit Number:	COC047675X
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: , Unit Acreage: , Drill Unit:
Casing:	String Type: CONDUCTOR, Hole Size: 20 in., Size: 16 in., Top: 0 ft., Depth: 40 ft., Weight: 65 , Citings Type: PLANNED
Cement:	Sacks: 4, Top: 0 ft., Bottom: 40 ft.
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 800 ft., Weight: 36 , Citings Type: PLANNED
Cement:	Sacks: 425, Top: 0 ft., Bottom: 800 ft.
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6656 ft., Weight: 23 , Citings Type: PLANNED
Cement:	Sacks: 575, Top: 0 ft., Bottom: 6656 ft.
Casing:	String Type: 1ST LINER, Hole Size: 7 in., Size: 5 in., Top: 5540 ft., Depth: 6656 ft., Weight: 18 , Citings Type: PLANNED
Cement:	Sacks: 155, Top: 5540 ft., Bottom: 6656 ft.
Casing:	String Type: 2ND LINER, Hole Size: 7 in., Size: 5.5 in., Top: 4000 ft., Depth: 5363 ft., Weight: 18 , Citings Type: PLANNED
Cement:	Sacks: 226, Top: 4000 ft., Bottom: 5363 ft.
Casing:	String Type: 1ST TAPER, Hole Size: 6.125 in., Size: 5 in., Top: 5363 ft., Depth: 6558 ft., Weight: 17 , Citings Type: PLANNED
Cement:	Sacks: 73, Top: 5363 ft., Bottom: 6658 ft.

Wellbore Completed
Completion Date:	1/5/1978
Spud Date:	4/13/2013	Spud Date Is:	Actual
Measured TD:	6562 ft.	Measured PB depth:	6483 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:	CEMENT BOND LOG SENT TO DENVER WITH FORM 33
Casing:	String Type: CONDUCTOR, Hole Size: 20 in., Size: 16 in., Top: 0 ft., Depth: 40 ft., Weight: 65 , Citings Type: ACTUAL
Cement:	Sacks: 4, Top: 0 ft., Bottom: 40 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 750 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 400, Top: 0 ft., Bottom: 750 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6655 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 700, Top: 0 ft., Bottom: 6655 ft., Determination Method: CBL
Casing:	String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 5305 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 235, Top: 0 ft., Bottom: 5305 ft., Determination Method: VISU
Casing:	String Type: TAPER, Hole Size: 6.125 in., Size: 5 in., Top: 5305 ft., Depth: 6562 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 96, Top: 5305 ft., Bottom: 6562 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
WEBER	5707 ft.	6483 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 10/29/2025 Interval Top: 5990 ft. Interval Bottom: 6410 ft.

Completed Information for Formation WEBER

1st Production Date:	6/13/2013	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	10/28/2025	Treatment End Date:	10/28/2025
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 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):	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:	1/22/2025	Treatment End Date:	1/22/2025
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 150 bbls fresh water.
Total fluid used in treatment (bbls):	197	Max pressure during treatment (psi):	1800
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):	100	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:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	11/14/2024	Treatment End Date:	11/14/2024
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 33 bbls fresh water
Total fluid used in treatment (bbls):	80	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):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	33	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:	4/23/2024	Treatment End Date:	4/23/2024
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL w/SOLVENT AND 37 BBLS FRESH WATER
Total fluid used in treatment (bbls):	84	Max pressure during treatment (psi):	2460
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):	37	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:	1/5/2020	Treatment End Date:	1/5/2020
Treatment Summary:	PUMPED 2988 GALLONS (71 BBLS) OF 15% HCL AND 35 BBLS FRESH WATER
Total fluid used in treatment (bbls):	106	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):	71	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:	1/2/2020	Treatment End Date:	1/2/2020
Treatment Summary:	PUMPED 1386 GALLONS (33.0 BBLS) 15% HCL ACID WITH SOLVENT AND 120.0 BBLS OF FRESH WATER
Total fluid used in treatment (bbls):	153	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):	33	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	120	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:	4/11/2018	Treatment End Date:	4/11/2018
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL WITH 100 BBLS WATER AT 0.5BPM @ 1900PSI
Total fluid used in treatment (bbls):	195	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):	100	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:	2/17/2017	Treatment End Date:	2/17/2017
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL, 110 GALLONS SOLVENT AND 125 BBLS FRESH WATER PACKER DEPTH CORRECTED TO FORM 33.
Total fluid used in treatment (bbls):	175	Max pressure during treatment (psi):	2616
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):	125	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:	11/19/2015	Treatment End Date:	11/19/2015
Treatment Summary:	Pumped 2000 gallons 15% HCl, 200 barrels fresh water, and 115 gallons Mutual solvent @ 3.0 bpm
Total fluid used in treatment (bbls):	250	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):	200	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:	12/5/2014	Treatment End Date:	12/5/2014
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL AT 2.8 BPM @1800 PSI
Total fluid used in treatment (bbls):	275	Max pressure during treatment (psi):	1800
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:
Treatment Date:	4/4/2013	Treatment End Date:	4/4/2013
Treatment Summary:	Broke down perfs with water on 4/4/2013
Total fluid used in treatment (bbls):	1800	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):		Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	1800	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:

Tubing Size:	2.875 in.	Tubing Setting Depth:	5973 ft.
Tubing Packer Depth:	5892 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5990 ft.	# Of Holes:	411
Interval Bottom:	6410 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