Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-10727		Well Classification: ERIW	Status: IJ - 9/1/2022
Well Name/No:	MCLAUGHLIN, A C #93X (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 #:	D 032675
Facility Status:	IJ	Status Date	9/1/2022
FacilityID:	284108	LocationID:	316529
County:	RIO BLANCO #103	Location:	SWSW 12 2N103W 6
Field:	RANGELY - #72370	Elevation:	5484 ft.
Planned Location:	47FSL 1168 FWL	Lat/Long: 40.150422 / -108.910060	Lat/Long Source: Field Measured
As Drilled Location:	Footages Not Available	Lat/Long: 40.150425 / -108.910069	Lat/Long Source: Field Measured


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

Wellbore #00 Wellbore Classification: OTH Status: IJ - 9/1/2022 Measured TD: 6670 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: OTH IJ - 9/1/2022
Wellbore Permit
Permit #:	20060507	Expiration Date:	4/4/2007
Prop Depth/Form:	6794 ft.
Surface Mineral Owner Same:	Yes
Mineral Owner:	FEDERAL	Surface Owner:	FEDERAL
Unit:	RANGELY WEBR SD	Unit Number:	COC 47675X
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: , Unit Acreage: , Drill Unit:

Wellbore Completed
Completion Date:	10/6/2006
Spud Date:	8/13/2006	Spud Date Is:	ACTUAL
Measured TD:	6670 ft.	Measured PB depth:	6670 ft.
True Vertical TD:		True Vertical PB depth:
Bottom Hole Location:	Sec: Twp:	Footage: FL FL	Depth
Log Types:	AI/SFL; COMP PHOTO DENSITY/CDNL; CBL/GR/CCL
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 2019 ft., Weight: 36.0 , Citings Type: ACTUAL
Cement:	Sacks: 790, Top: 0 ft., Bottom: 2019 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6512 ft., Weight: 23.0 , Citings Type: ACTUAL
Cement:	Sacks: 625, Top: 1900 ft., Bottom: 6512 ft., Determination Method: CBL
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3883 ft.		N	N
MORRISON	3972 ft.		N	N
CURTIS	4700 ft.		N	N
ENTRADA	4795 ft.		N	N
CARMEL	4938 ft.		N	N
NAVAJO	5001 ft.		N	N
CHINLE	5630 ft.		N	N
SHINARUMP	5762 ft.		N	N
MOENKOPI	5826 ft.		N	N
WEBER	6508 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 9/1/2022 Interval Top: 6512 ft. Interval Bottom: 6670 ft.

Completed Information for Formation WEBER

1st Production Date:	11/6/2006	Choke Size:
Formation Name:	WEBER	Commingled:
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:
Treatment Date:	11/28/2022	Treatment End Date:	N/A
Treatment Summary:	Rig up. Release top PS1 packer and lokset packer also released. Laid down injection string and picked up workstring. Ran 7” casing scrapper to end of casing then ran 6-18” bit and cleaned out to PBTD at 6670’. Ran and set 7” lokset packer at 6451’ and tested casing successfully. Ran and set 7” PS1 packer @ 6399’. Tested casing to 1200 psi for 30 minutes and tubing to 3000 psi. Rig Down. Pressure test reported on Document# 403133819
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:	11/12/2021	Treatment End Date:	11/12/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL AND 6% CITRIC ACID WITH 46 BBLS WATER
Total fluid used in treatment (bbls):	141	Max pressure during treatment (psi):	2150
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):	46	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:	7/19/2021	Treatment End Date:	7/19/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL AND 6% CITRIC ACID WITH 40 BBLS WATER
Total fluid used in treatment (bbls):	135	Max pressure during treatment (psi):	2090
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):	40	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	10/6/2006
Treatment Summary:	6512-6670'= OPEN HOLE

Tubing Size:	2.875 in.	Tubing Setting Depth:	6487 ft.
Tubing Packer Depth:	6399 ft.	Tubing Multiple Packer:
Open Hole Top:	6512 ft.	Open Hole Bottom:	6670 ft.
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6512 ft.	# Of Holes:
Interval Bottom:	6670 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

June 2023 - May 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	240351
GOR
GOR Determination	MCFE
Average BOE per Day	114.222
Average MCFE per Day	662.500

Federal Financial Assurance

Tribal Well