Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-07426		Well Classification: ERIW	Status: IJ - 7/15/2019
Well Name/No:	UNION PACIFIC #78X-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	7/15/2019
FacilityID:	229769	LocationID:	314857
County:	RIO BLANCO #103	Location:	SWSE 21 2N102W 6
Field:	RANGELY - #72370	Elevation:	5394 ft.
Planned Location:	1317FSL 1355 FEL	Lat/Long: 40.124845 / -108.843495	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.124915 / -108.843686	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: OTH Status: IJ - 7/15/2019 Measured TD: 6658 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: OTH IJ - 7/15/2019
Wellbore Permit
Permit #:	10001	Expiration Date:	7/22/1972
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:

Wellbore Completed
Completion Date:	N/A
Measured TD:	6658 ft.	Measured PB depth:	6465 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	SECTOR CEMENT BOND GR/CCL LOG 8/31/2007
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 10.75 in., Top: 0 ft., Depth: 778 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 525, Top: 0 ft., Bottom: , Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6558 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 700, Top: 0 ft., Bottom: , Determination Method:
Casing:	String Type: 1ST LINER, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 6465 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 235, Top: 1950 ft., Bottom: , Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3540 ft.
MORRISON	3664 ft.
CURTIS	4310 ft.
ENTRADA	4450 ft.
CARMEL	4567 ft.
CHINLE	5212 ft.
NAVAJO	5212 ft.
SHINARUMP	5342 ft.
MOENKOPI	5406 ft.
WEBER	6098 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 7/15/2019 Interval Top: 6120 ft. Interval Bottom: 6477 ft.

Completed Information for Formation WEBER

1st Production Date:	5/8/1972	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	7/12/2019	Treatment End Date:	7/12/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/ 3% CIRTRIC ACID. FIRST INJECTION 4/3/1975
Total fluid used in treatment (bbls):	47	Max pressure during treatment (psi):	2183
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):		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:	1/16/2015	Treatment End Date:	1/16/2015
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL AT 3.0 BPM AT 1700 PSI
Total fluid used in treatment (bbls):	145	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):	95	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:
Treatment Date:	12/18/2014	Treatment End Date:	12/18/2014
Treatment Summary:	ADDED ADDITIONAL PERFORATION IN THE WEBER FORMATION 6473-6477,6443-6458,6427-6430,6414-6418, 6367-6403.6432-6360, 6326-6330,6284-6292'. TOTAL OF 306 NEW HOLES, 657 TOTAL PERFORATION HOLES
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:	9/4/2007
Treatment Summary:	PUMP 4200 GALLONS HEATED 15% HCI WITH ADDITIVES @ 2 8 BPM & 1176 PSI THROUGH END OF TUBING @ 5591'

Tubing Size:	2.875 in.	Tubing Setting Depth:	6309 ft.
Tubing Packer Depth:	6045 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6120 ft.	# Of Holes:	657
Interval Bottom:	6477 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

August 2023 - July 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	76330
GOR
GOR Determination	MCFE
Average BOE per Day	35.939
Average MCFE per Day	208.437

Federal Financial Assurance

Tribal Well