Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08530		Well Classification: ERIW	Status: IJ - 4/30/2024
Well Name/No:	UNION PACIFIC #110X-21 (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	4/30/2024
FacilityID:	230861	LocationID:	315459
County:	RIO BLANCO #103	Location:	NESW 21 2N102W 6
Field:	RANGELY - #72370	Elevation:	5304 ft.
Planned Location:	1439FSL 1409 FWL	Lat/Long: 40.125185 / -108.852705	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.125269 / -108.852743	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 4/30/2024 Measured TD: 6559 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 4/30/2024
Wellbore Permit
Permit #:	806677	Expiration Date:	10/11/1980
Prop 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:
Casing:	String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 5870 ft., Weight: 17 , Citings Type: PLANNED
Cement:	Sacks: , Top: 0 ft., Bottom:

Wellbore Completed
Completion Date:	7/26/1980
Spud Date:	7/7/1980	Spud Date Is:	ACTUAL
Measured TD:	6559 ft.	Measured PB depth:	6506 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 9.625 in., Top: 0 ft., Depth: 798 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 485, Top: 0 ft., Bottom: 798 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6545 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 750, Top: 4108 ft., Bottom: 6545 ft., Determination Method: CALC
Casing:	String Type: 2ND, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 5854 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 353, Top: 0 ft., Bottom: 5854 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2283 ft.
FRONTIER	3029 ft.
DAKOTA	3382 ft.		N	N
MORRISON	3477 ft.		N	N
ENTRADA	4300 ft.		N	N
NAVAJO	4470 ft.		N	N
WEBER	5960 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 4/30/2024 Interval Top: 5960 ft. Interval Bottom: 6457 ft.

Completed Information for Formation WEBER

1st Production Date:	10/7/1980	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	4/29/2024	Treatment End Date:	4/29/2024
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:	1/27/2023	Treatment End Date:	1/27/2023
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH MUTUAL SOLVENT AND INHIBITORS, 35 BBLS OF WATER.
Total fluid used in treatment (bbls):	130	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):	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:	9/12/2019	Treatment End Date:	9/12/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH 6% CITRIC ACID, 80 BBLS OF WATER.
Total fluid used in treatment (bbls):	127	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):	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:	8/16/2018	Treatment End Date:	8/16/2018
Treatment Summary:	WELLWORK TO REPAIR CASING. RAN LINER FROM SURFACE TO 5854', ADD ADDITIONAL PERFORATION, ACID STIMULATION WITH 71 BBLS HCL AND 32 BBLS BRINE WATER. COGCC WITNESSED MIT SCHEDULED FOR 8/23/2018
Total fluid used in treatment (bbls):	103	Max pressure during treatment (psi):	1100
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):		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:	2/16/2017	Treatment End Date:	2/16/2017
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL, 110 GALLONS SOLVENT AND 153.8 BBLS FRESH WATER
Total fluid used in treatment (bbls):	204	Max pressure during treatment (psi):	2605
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):	153	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:	11/14/2015	Treatment End Date:	11/14/2015
Treatment Summary:	PUMPED 2000 GALLONS 15% HCL AND 102 GALLONS MUTUAL SOLVENT
Total fluid used in treatment (bbls):	250	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):	47	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:	12/8/2014	Treatment End Date:	12/8/2014
Treatment Summary:	PUMPED 4000 GALLONS OF 15% HCL AT 2.6 BPM @ 2300 PSI
Total fluid used in treatment (bbls):	305	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):	95	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	210	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:	5871 ft.
Tubing Packer Depth:	5784 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:	138
Interval Bottom:	6457 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

June 2023 - May 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	206825
GOR
GOR Determination	MCFE
Average BOE per Day	97.548
Average MCFE per Day	565.804

Federal Financial Assurance

Tribal Well