Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-09147		Well Classification: ERIW	Status: IJ - 9/3/2025
Well Name/No:	EMERALD #91Y (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	9/3/2025
FacilityID:	231477	LocationID:	315738
County:	RIO BLANCO #103	Location:	NWNW 25 2N103W 6
Field:	RANGELY - #72370	Elevation:	5429 ft.
Basin:	PICEANCE BASIN
Planned Location:	179FNL 682 FWL	Lat/Long: 40.120725 / -108.911847	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.120800 / -108.911775	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 9/3/2025 Measured TD: 6701 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 9/3/2025
Wellbore Permit
Permit #:	840326	Expiration Date:	7/19/1984
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:	9/18/2013
Spud Date:	6/7/1984	Spud Date Is:	ACTUAL
Measured TD:	6701 ft.	Measured PB depth:	6576 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:	ACOUSTIC CEMENT BOND LOG, MULTI-FINGER CALIPER LOG, COMPENSTATED NEUTRON LOG SENT TO DON SHARPE ON 10/8/2013
Casing:	String Type: CONDUCTOR, Hole Size: , Size: 16 in., Top: 0 ft., Depth: 31 ft., Weight: 65 , Citings Type: ACTUAL
Cement:	Sacks: , Top: 0 ft., Bottom: 31 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 2472 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 380, Top: 0 ft., Bottom: 2472 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6698 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 900, Top: 500 ft., Bottom: 6698 ft., Determination Method: CBL
Casing:	String Type: 1ST LINER, Hole Size: 7 in., Size: 5.5 in., Top: 5550 ft., Depth: 6586 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 60, Top: 5550 ft., Bottom: 6586 ft., Determination Method: CALC
Casing:	String Type: STAGE TOOL, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 4230 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 690, Top: , Bottom: 4230 ft., Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3250 ft.
MORRISON	3345 ft.
CHINLE	4970 ft.
WEBER	5828 ft.	6701 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 9/3/2025 Interval Top: 6069 ft. Interval Bottom: 6541 ft.

Completed Information for Formation WEBER

1st Production Date:	11/8/2013	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/26/2025	Treatment End Date:	8/26/2025
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/solvent and 43 bbls fresh water
Total fluid used in treatment (bbls):	138	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):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	43	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:	2/17/2025	Treatment End Date:	2/17/2025
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/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):	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:	7/23/2024	Treatment End Date:	7/23/2024
Treatment Summary:	Pumped 4000 gallons (95.2 bbls) 15% HCL w/solvent and 40 bbls fresh water.
Total fluid used in treatment (bbls):	135	Max pressure during treatment (psi):	2508
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):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	40	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:	9/6/2023	Treatment End Date:	9/7/2023
Treatment Summary:	PUMPED 95.2 BBLS 15% HCL W/SOLVENT AND 38 BBLS FRESH WATER
Total fluid used in treatment (bbls):	133	Max pressure during treatment (psi):	2440
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):	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:	11/27/2019	Treatment End Date:	11/27/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15%HCL 6% CITRIC MUTSOL AND 40 BBLS FRESH WATER
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	2100
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):	40	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	3/3/2014	Treatment End Date:	N/A
Treatment Summary:	CEMENTED ORIGINAL COMPLETION PERFORATIONS AND 5 1/2" LINER SELECTIVELY PERFORATED INJECTION ZONES
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:

Tubing Size:	2.875 in.	Tubing Setting Depth:	6093 ft.
Tubing Packer Depth:	6006 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6069 ft.	# Of Holes:	834
Interval Bottom:	6541 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