Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-07978		Well Classification: ERIW	Status: IJ - 10/27/2025
Well Name/No:	LACY, S B #7X (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	10/27/2025
FacilityID:	230318	LocationID:	315138
County:	RIO BLANCO #103	Location:	NWSW 24 2N103W 6
Field:	RANGELY - #72370	Elevation:	5427 ft.
Basin:	PICEANCE BASIN
Planned Location:	2466FSL 170 FWL	Lat/Long: 40.127985 / -108.913637	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.128065 / -108.913576	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 10/27/2025 Measured TD: 6675 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 10/27/2025
Wellbore Permit
Permit #:	100010	Expiration Date:	7/25/1977
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:	D-052538
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	7/5/1977
Spud Date:	5/13/1977	Spud Date Is:	ACTUAL
Measured TD:	6675 ft.	Measured PB depth:	6496 ft.
True Vertical TD:		True Vertical PB depth:
Top PZ Location:	Sec: Twp:	Footage: 0 FL 0 FL
Log Types:
Casing:	String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 774 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 375, Top: 0 ft., Bottom: 774 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6675 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 600, Top: 0 ft., Bottom: 6675 ft., Determination Method: CALC
Casing:	String Type: S.C. 1.1, Hole Size: 8.75 in., Size: 7 in., Top: 4197 ft., Depth: 4227 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 50, Top: 4197 ft., Bottom: 4227 ft., Determination Method: CALC
Casing:	String Type: STAGE TOOL, Hole Size: , Size: 7 in., Top: , Depth: 3783 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 350, Top: 1500 ft., Bottom: 3783 ft., Determination Method: CALC
Additional Cement:	String Type: 1ST , Top: 4197 ft., Depth: 4227 ft., Bottom: 4227 ft., Sacks: 50, Method: Squeeze
Additional Cement:	String Type: 1ST , Top: 3968 ft., Depth: 4011 ft., Bottom: 4196 ft., Sacks: 65, Method: SQUEEZE
Additional Cement:	String Type: 1ST , Top: , Depth: 3783 ft., Bottom: , Sacks: , Method: DV TOOL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3380 ft.	3475 ft.	N	N
MORRISON	3475 ft.	4264 ft.	N	N
ENTRADA	4264 ft.	4460 ft.	N	N
NAVAJO	4460 ft.	5944 ft.	N	N
WEBER	5944 ft.	6678 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 10/27/2025 Interval Top: 5960 ft. Interval Bottom: 6580 ft.

Completed Information for Formation WEBER

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

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	10/24/2025	Treatment End Date:	10/24/2025
Treatment Summary:	PUMED 2000 GALLONS (47.6 BBLS) 15 % HCL W/SOLVENT AND 40 BBLS FRESH WATER.
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	2410
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):	40	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	7/25/2025	Treatment End Date:	N/A
Treatment Summary:	8/23 UIC Repair - CO well down to 6496' (bad casing from 6246-6496. Isolated casing leak from 4011' - 4043'). Squeezed w/ 15.8# class G cmt (50 sxs prepared, 44.9 sxs behind casing a 5.1 sxs in wellbore, DO cmt, still leaking. Squeezed w/ 300 psi seal maker (65 total gals), still leaking. Final squeeze attempt was w/ 13.4# fine cmt, mixed 15 sxs total (3.8 sxs behind casing rest in wellbore, DO slowly with no more than 4k on bit. casing tested - good. " Return to injection upon approval of Form 21.
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:	ACID JOB
Treatment Date:	4/24/2025	Treatment End Date:	4/24/2025
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL w/SOLVENT AND 38 BBLS FRESH WATER
Total fluid used in treatment (bbls):	85	Max pressure during treatment (psi):	1822
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):	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:	1/15/2025	Treatment End Date:	1/15/2025
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:	6/24/2024	Treatment End Date:	6/24/2024
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT AND 45 BBLS FRESH WATER
Total fluid used in treatment (bbls):	140	Max pressure during treatment (psi):	2585
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):	45	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:	10/10/2022	Treatment End Date:	10/10/2022
Treatment Summary:	Pumped 4000 gallon (95.2 bbls) 15% HCL w/ mutual solvent and 35 bbls 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):		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:	1/6/2022	Treatment End Date:	1/6/2022
Treatment Summary:	Pumped 4000 gallon (95.2 bbls) 15% HCL w/ 6% Citric Acid and 35 bbls 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):		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:	3/31/2021	Treatment End Date:	3/31/2021
Treatment Summary:	Pumped 2000 gallon (47.6 bbls) 15% HCL w/ 6% Citric Acid and 80 bbls water.
Total fluid used in treatment (bbls):	127	Max pressure during treatment (psi):	1400
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):	80	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:	8/7/2020	Treatment End Date:	8/7/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT AND 50 BBLS WATER
Total fluid used in treatment (bbls):	97	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):	50	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:	2/3/2019	Treatment End Date:	2/3/2019
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL WITH 110 GALLONS SOLVENT. 120 BBLS FRESH WATER
Total fluid used in treatment (bbls):	170	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):	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:	12/27/2017	Treatment End Date:	12/27/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL WITH 160 BBLS WATER
Total fluid used in treatment (bbls):	255	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):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	160	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:	5/16/2015	Treatment End Date:	5/16/2015
Treatment Summary:	Pumped 4000 gallons 15% HCL
Total fluid used in treatment (bbls):	255	Max pressure during treatment (psi):	2450
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):	160	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	10/1/2010
Treatment Summary:	ACID STIMULATION, PUMPED 4000 GALLONS OF 20% HCL THROUGH END OF COILED TUBING 6023' AT STARTING PRESSURE OF 1300 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	5867 ft.
Tubing Packer Depth:	5805 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5960 ft.	# Of Holes:	186
Interval Bottom:	6580 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 03/31/2023
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