Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06167		Well Classification: ERIW	Status: IJ - 9/6/2024
Well Name/No:	UNION PACIFIC #56-21 (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	9/6/2024
FacilityID:	229088	LocationID:	314590
County:	RIO BLANCO #103	Location:	SENE 21 2N102W 6
Field:	RANGELY - #72370	Elevation:	5357 ft.
Planned Location:	1980FNL 664 FEL	Lat/Long: 40.130385 / -108.841135	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.130350 / -108.841220	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 9/6/2024 Measured TD: 6556 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 9/6/2024
Wellbore Permit
Permit #:	100001	Expiration Date:	9/6/1981
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:	2/12/1982
Spud Date:	11/3/1981	Spud Date Is:	ACTUAL
Measured TD:	6556 ft.	Measured PB depth:	6540 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:
Casing:	String Type: CONDUCTOR, Hole Size: 20 in., Size: 16 in., Top: 0 ft., Depth: 57 ft., Weight: 43 , Citings Type: ACTUAL
Cement:	Sacks: 75, Top: 0 ft., Bottom: 57 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 10.75 in., Top: 0 ft., Depth: 506 ft., Weight: 32.75 , Citings Type: ACTUAL
Cement:	Sacks: 235, Top: 57 ft., Bottom: 506 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 9 in., Size: 7 in., Top: 0 ft., Depth: 6256 ft., Weight: 26 , Citings Type: ACTUAL
Cement:	Sacks: 1000, Top: 2515 ft., Bottom: 6256 ft., Determination Method: CBL
Casing:	String Type: 2ND, Hole Size: , Size: 5.5 in., Top: 0 ft., Depth: 6070 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 272, Top: 0 ft., Bottom: 6070 ft., Determination Method: VISU
Casing:	String Type: 1ST LINER, Hole Size: , Size: 5 in., Top: 6070 ft., Depth: 6554 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 200, Top: 6070 ft., Bottom: 6554 ft., Determination Method: CALC
Additional Cement:	String Type: 2ND , Top: 0 ft., Depth: 6022 ft., Bottom: 6070 ft., Sacks: 272, Method: STAGE TOOL
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2564 ft.
FRONTIER	3327 ft.
DAKOTA	3604 ft.		N	N
MOWRY	3604 ft.
MORRISON	3692 ft.		N	N
CURTIS	3765 ft.		N	N
ENTRADA	4413 ft.		N	N
CARMEL	4586 ft.		N	N
NAVAJO	4711 ft.		N	N
CHINLE	4760 ft.		N	N
SHINARUMP	5352 ft.		N	N
MOENKOPI	5495 ft.		N	N
WEBER	5592 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 9/6/2024 Interval Top: 6245 ft. Interval Bottom: 6468 ft.

Completed Information for Formation WEBER

1st Production Date:	6/23/1974	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/27/2024	Treatment End Date:	8/27/2024
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):	1700
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:	11/14/2023	Treatment End Date:	11/14/2023
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) WITH 15% HCL w/SOLVENT AND 40 BBLS OF WATER.
Total fluid used in treatment (bbls):	87	Max pressure during treatment (psi):	2528
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:	ACID JOB
Treatment Date:	11/7/2022	Treatment End Date:	11/7/2022
Treatment Summary:	PUMED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 35 BBLS WATER
Total fluid used in treatment (bbls):	82	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):	47	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:	4/7/2022	Treatment End Date:	4/7/2022
Treatment Summary:	PUMED 2000 GALLONS (47.6 BBLS) 15% HCL W/SOLVENT AND 40 BBLS WATER
Total fluid used in treatment (bbls):	87	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):	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:	7/14/2021	Treatment End Date:	7/14/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/MUTUAL SOLVENT, 45 BBLS WATER
Total fluid used in treatment (bbls):	92	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):	45	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	1/28/2020	Treatment End Date:	N/A
Treatment Summary:	Wellwork to change out 188 joints tubing and packer.
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:	12/19/2019	Treatment End Date:	12/19/2019
Treatment Summary:	WELL WORK TO CLEANOUT, INSTALL TIEBACK LINER, RE-PERFORATE (6262' TO 6270' AND 6287' TO 6300') , ACIDIZE (PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH 110 BBLS WATER).
Total fluid used in treatment (bbls):	205	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):	110	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:	4/10/2018	Treatment End Date:	4/10/2018
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL WITH 100 BBLS WATER AT 0.6 BPM AT 1400 PSI.
Total fluid used in treatment (bbls):	195	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):	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:
Treatment Date:	12/7/2017	Treatment End Date:	N/A
Treatment Summary:	High casing pressure was found on UP56-21 and the well was shut in. Well work has been completed, fiberlined tubing and packer were replaced. The top packer was set at 5970' and the tubing landed at 6480.7. A COGCC witnessed MIT is scheduled for November 30th.
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:
Treatment Date:	6/28/2017	Treatment End Date:	N/A
Treatment Summary:	Tubing plug was set at 5999' on 8/1/2016. Well was converted to gas injection 11/24/1954, converted back to production 2/23/1961, converted back to injection 11/21/1974.
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:	4/15/2010
Treatment Summary:	ACID STIMULATION 4/15/2010 PUMPED 4000 GALLONS OF 20% HCI THROUGH END OF TUBING 6480'. AT STARTING 2.8 BPM @ 25800 PSI.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6082 ft.
Tubing Packer Depth:	5995 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6245 ft.	# Of Holes:	210
Interval Bottom:	6468 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)	107033
GOR
GOR Determination	MCFE
Average BOE per Day	50.639
Average MCFE per Day	293.722

Federal Financial Assurance

Tribal Well