Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-05812		Well Classification: ERIW	Status: IJ - 11/17/2021
Well Name/No:	MCLAUGHLIN, A C #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	11/17/2021
FacilityID:	228825	LocationID:	314486
County:	RIO BLANCO #103	Location:	SWNE 13 2N103W 6
Field:	RANGELY - #72370	Elevation:	5436 ft.
Planned Location:	1980FNL 1980 FEL	Lat/Long: 40.144755 / -108.902497	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.144856 / -108.902393	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 11/17/2021 Measured TD: 6550 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 11/17/2021
Wellbore Permit
Permit #:	10001	Expiration Date:	2/24/2000
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:	D-032675
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:
Casing:	String Type: 2ND, Hole Size: 6.366 in., Size: 5.5 in., Top: 0 ft., Depth: 6194 ft., Weight: 17 , Citings Type: PLANNED
Cement:	Sacks: 300, Top: , Bottom:

Wellbore Completed
Completion Date:	7/3/1947
Spud Date:	5/9/1947	Spud Date Is:	ACTUAL
Measured TD:	6550 ft.	Measured PB depth:	6550 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:
Log Types:	HARD COPY OF CBL - SUBMITTED WITH FORM 21
Casing:	String Type: CONDUCTOR, Hole Size: , Size: 16 in., Top: 0 ft., Depth: 57 ft., Weight: 55 , Citings Type: ACTUAL
Cement:	Sacks: 105, Top: 0 ft., Bottom: 57 ft., Determination Method:
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 10.75 in., Top: 0 ft., Depth: 706 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 500, Top: 0 ft., Bottom: 706 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6338 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1250, Top: 3300 ft., Bottom: 6338 ft., Determination Method: CBL
Casing:	String Type: 2ND, Hole Size: 6.366 in., Size: 5.5 in., Top: 0 ft., Depth: 6179 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 270, Top: 0 ft., Bottom: 6179 ft., Determination Method: VISU
Additional Cement:	String Type: S.C. 2.1 , Top: 410 ft., Depth: 1110 ft., Bottom: 1110 ft., Sacks: 190, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2430 ft.	2610 ft.
FRONTIER	3380 ft.
MOWRY	3645 ft.
DAKOTA	3735 ft.
MORRISON	3809 ft.
CURTIS	4530 ft.
ENTRADA	4633 ft.
CARMEL	4780 ft.
NAVAJO	4832 ft.
CHINLE	5455 ft.
SHINARUMP	5569 ft.
MOENKOPI	5880 ft.
WEBER	6348 ft.	6564 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 11/17/2021 Interval Top: 6350 ft. Interval Bottom: 6480 ft.

Completed Information for Formation WEBER

1st Production Date:	6/15/1972	Choke Size:
Formation Name:	WEBER	Commingled:
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	11/13/2021	Treatment End Date:	11/13/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/6% CITRIC ACID WITH MUTUAL SOLVENT AND 52 BBLS WATER
Total fluid used in treatment (bbls):	147	Max pressure during treatment (psi):	2380
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):	52	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:	2/18/2021	Treatment End Date:	2/18/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/6% CITRIC ACID WITH MUTUAL SOLVENT AND 47 BBLS WATER
Total fluid used in treatment (bbls):	95	Max pressure during treatment (psi):	2200
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):	47	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:	11/7/2019	Treatment End Date:	11/7/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL, 37 BBLS OF FRESH WATER.
Total fluid used in treatment (bbls):	84	Max pressure during treatment (psi):	2250
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):	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:	2/17/2017	Treatment End Date:	2/17/2017
Treatment Summary:	PUMPED 4000 GALLONS 15% HCL, 110 GALLONS SOLVENT AND 250 BBLS OF FRESH WATER
Total fluid used in treatment (bbls):	347	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):	250	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:	6/30/2015	Treatment End Date:	6/30/2015
Treatment Summary:	PUMPED 4000 GALLONS 15%HCL W/ 165 GALLONS SOLVENT
Total fluid used in treatment (bbls):	211	Max pressure during treatment (psi):	2120
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):	112	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	9/29/2010
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS 20% HCL, EOT @ 6161'.
Formation Treatment
Treatment Date:	2/10/2009
Treatment Summary:	ACIDIZE FORMATION W/4,000 GALS HEATED 20% HCL, EOT @ 6161'. OPEN HOLE IS 6350-6550'. TREATED THRU COILED TUBING.

Tubing Size:	2.875 in.	Tubing Setting Depth:	6152 ft.
Tubing Packer Depth:	6032 ft.	Tubing Multiple Packer:
Open Hole Top:	6350 ft.	Open Hole Bottom:	6480 ft.
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6350 ft.	# Of Holes:
Interval Bottom:	6480 ft.	Hole Size:

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)	119632
GOR
GOR Determination	MCFE
Average BOE per Day	56.311
Average MCFE per Day	326.593

Federal Financial Assurance

Tribal Well