Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06287		Well Classification: ERIW	Status: IJ - 2/27/2024
Well Name/No:	UNION PACIFIC #68-32 (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	2/27/2024
FacilityID:	229200	LocationID:	311808
County:	RIO BLANCO #103	Location:	SESW 32 2N102W 6
Field:	RANGELY - #72370	Elevation:	5258 ft.
Basin:	PICEANCE BASIN
Planned Location:	711FSL 1947 FWL	Lat/Long: 40.094176 / -108.869646	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.094234 / -108.869682	Lat/Long Source: Field Measured


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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 2/27/2024 Measured TD: 6325 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 2/27/2024
Wellbore Permit
Permit #:	10001	Expiration Date:	2/24/2000
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:	N/A
Spud Date:	9/13/1948	Spud Date Is:	ACTUAL
Measured TD:	6325 ft.	Measured PB depth:	6280 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:
Log Types:
Casing:	String Type: SURF, Hole Size: 16 in., Size: 10.75 in., Top: 0 ft., Depth: 2002 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 500, Top: 950 ft., Bottom: 2002 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 10.75 in., Size: 7 in., Top: 0 ft., Depth: 5677 ft., Weight: 23 20 , Citings Type: ACTUAL
Cement:	Sacks: 1000, Top: 2250 ft., Bottom: 5677 ft., Determination Method: CALC
Casing:	String Type: 1ST LINER, Hole Size: 7 in., Size: 5 in., Top: 5505 ft., Depth: 6355 ft., Weight: 18 , Citings Type: ACTUAL
Cement:	Sacks: 320, Top: 5505 ft., Bottom: 6322 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2080 ft.	2797 ft.	N	N
FRONTIER	2797 ft.	3070 ft.	N	N
MOWRY	3070 ft.	3151 ft.	N	N
DAKOTA	3151 ft.	3239 ft.	N	N
MORRISON	3239 ft.	3887 ft.	N	N
CURTIS	3887 ft.	4013 ft.	N	N
ENTRADA	4013 ft.	4178 ft.	N	N
CARMEL	4178 ft.	4228 ft.	N	N
NAVAJO	4228 ft.	4823 ft.	N	N
CHINLE	4823 ft.	4951 ft.	N	N
SHINARUMP	4951 ft.	5010 ft.	N	N
MOENKOPI	5010 ft.	5666 ft.	N	N
WEBER	5666 ft.	6325 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 2/27/2024 Interval Top: 5668 ft. Interval Bottom: 6250 ft.

Completed Information for Formation WEBER

1st Production Date:	1/18/1989	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	2/22/2024	Treatment End Date:	2/22/2024
Treatment Summary:	Pumped 2000 gallons (47.6 bbls) 15% HCL w/solvent and 37 bbls Fresh water.
Total fluid used in treatment (bbls):	84	Max pressure during treatment (psi):	2485
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):	37	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:	1/5/2022	Treatment End Date:	1/5/2022
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT 43 BBLS FRESH WATER
Total fluid used in treatment (bbls):	90	Max pressure during treatment (psi):	2477
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):	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:	4/1/2020	Treatment End Date:	4/1/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH SOLVENT 62 BBLS FRESH WATER
Total fluid used in treatment (bbls):	109	Max pressure during treatment (psi):	2485
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):	62	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	3/20/2012
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL AT 0.9 BPM @ 1150 PSI END OF COILED TUBING @ 6036'
Formation Treatment
Treatment Date:	11/18/2009
Treatment Summary:	ACID STIMULATION 11/18/09 PUMPED 4000 GALLONS OF 20% HCI AT 3.6 BPM AVERAGE PRESSURE 2750 PSI THROUGH TUBING AT 6202'.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6202 ft.
Tubing Packer Depth:	5426 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5668 ft.	# Of Holes:	114
Interval Bottom:	6250 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