Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08492		Well Classification: ERIW	Status: IJ - 12/21/2021
Well Name/No:	EMERALD #82X (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	12/21/2021
FacilityID:	230823	LocationID:	315436
County:	RIO BLANCO #103	Location:	NENW 26 2N103W 6
Field:	RANGELY - #72370	Elevation:	5571 ft.
Planned Location:	1347FNL 1423 FWL	Lat/Long: 40.117565 / -108.928048	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.117602 / -108.928076	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 12/21/2021 Measured TD: 6821 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 12/21/2021
Wellbore Permit
Permit #:	800304	Expiration Date:	7/24/1980
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: 20, Drill Unit:

Wellbore Completed
Completion Date:	6/25/1980
Spud Date:	5/11/1980	Spud Date Is:	ACTUAL
Measured TD:	6821 ft.	Measured PB depth:	6738 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	CEMENT BOND LOG
Log Types:	New CBL ran on June 26, 2013 - hard copy mailed to Denver office 7/23/2013
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 9.625 in., Top: 0 ft., Depth: 752 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 470, Top: 0 ft., Bottom: 752 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 8.625 in., Top: 0 ft., Depth: 174 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6821 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 750, Top: 0 ft., Bottom: 6821 ft., Determination Method: CBL
Casing:	String Type: 1ST, Hole Size: 7.875 in., Size: 4.5 in., Top: 0 ft., Depth: 3251 ft., Weight: , Citings Type: HISTORICAL
Cement:	Sacks: 0, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 2ND, Hole Size: 8.75 in., Size: 5.5 in., Top: 0 ft., Depth: 6738 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 330, Top: 1900 ft., Bottom: 6738 ft., Determination Method: CBL
Additional Cement:	String Type: 2ND , Top: 3040 ft., Depth: 3340 ft., Bottom: 3340 ft., Sacks: 70, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
WEBER	6250 ft.	6821 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 12/21/2021 Interval Top: 6254 ft. Interval Bottom: 6704 ft.

Completed Information for Formation WEBER

1st Production Date:	10/11/1990	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	12/20/2021	Treatment End Date:	12/20/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT AND 91 BBLS WATER
Total fluid used in treatment (bbls):	186	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):	91	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:	7/8/2021	Treatment End Date:	7/8/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/ 6% CITRIC ACID AND 40 BBLS WATER
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	2090
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:	ACID JOB
Treatment Date:	11/26/2019	Treatment End Date:	11/26/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL 6% CITRIC MUTSOL, 38 BBLS FRESH WATER
Total fluid used in treatment (bbls):	85	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):	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:	3/28/2015	Treatment End Date:	3/28/2015
Treatment Summary:	ACID STIMULATION WITH 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	165	Max pressure during treatment (psi):	2350
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):	70	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	10/23/2013	Treatment End Date:	N/A
Treatment Summary:	RAN LINER AND RE-PERF INJECTION ZONE
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:	9/9/2011
Treatment Summary:	SHOOT ADDITIONAL PERFS 4SPF 39 GRAMS (6656-6682) (6606-6632) (6554-6586) AMD 6516-6536) TOTAL OF 104'

Tubing Size:	2.875 in.	Tubing Setting Depth:	6239 ft.
Tubing Packer Depth:	6128 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6254 ft.	# Of Holes:	396
Interval Bottom:	6704 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)	227712
GOR
GOR Determination	MCFE
Average BOE per Day	105.864
Average MCFE per Day	614.008

Federal Financial Assurance

Tribal Well