Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-06317		Well Classification: ERIW	Status: IJ - 8/2/2022
Well Name/No:	MCLAUGHLIN, A C #17 (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 #:
Facility Status:	IJ	Status Date	8/2/2022
FacilityID:	229227	LocationID:	314668
County:	RIO BLANCO #103	Location:	SWSE 11 2N103W 6
Field:	RANGELY - #72370	Elevation:	5530 ft.
Planned Location:	660FSL 1880 FEL	Lat/Long: 40.152005 / -108.920858	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.152110 / -108.920930	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 8/2/2022 Measured TD: 6915 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 8/2/2022
Wellbore Permit
Permit #:	999999	Expiration Date:	1/1/1955
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:	10/24/1947
Spud Date:	9/3/1947	Spud Date Is:	ACTUAL
Measured TD:	6915 ft.	Measured PB depth:	6743 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	NO NEW LOGS
Casing:	String Type: CONDUCTOR, Hole Size: , Size: 16 in., Top: 0 ft., Depth: 57 ft., Weight: 55 , Citings Type: ACTUAL
Cement:	Sacks: 4, Top: 0 ft., Bottom: 57 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 10.75 in., Top: 0 ft., Depth: 693 ft., Weight: 40.5 , Citings Type: ACTUAL
Cement:	Sacks: 400, Top: 0 ft., Bottom: 693 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 9 in., Size: 7 in., Top: 0 ft., Depth: 6579 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1075, Top: 3474 ft., Bottom: 6579 ft., Determination Method: CBL
Additional Cement:	String Type: 1ST , Top: 5118 ft., Depth: 5118 ft., Bottom: 5123 ft., Sacks: 150, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
NIOBRARA	2631 ft.
FRONTIER	3580 ft.
MOWRY	3845 ft.
DAKOTA	3924 ft.		N	N
MORRISON	4008 ft.		N	N
CURTIS	4750 ft.		N	N
ENTRADA	4855 ft.		N	N
NAVAJO	5052 ft.		N	N
CARMEL	5090 ft.		N	N
CHINLE	5684 ft.		N	N
SHINARUMP	5803 ft.		N	N
MOENKOPI	5886 ft.		N	N
WEBER	6576 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 8/2/2022 Interval Top: 6579 ft. Interval Bottom: 67 ft.

Completed Information for Formation WEBER

1st Production Date:	6/24/1963	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/1/2022	Treatment End Date:	8/1/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/MUTUAL SOLVENT, 35 BBLS WATER
Total fluid used in treatment (bbls):	130	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):	95	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:	11/19/2021	Treatment End Date:	11/19/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/MUTUAL SOLVENT, 45 BBLS WATER
Total fluid used in treatment (bbls):	140	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):	95	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:	ACID JOB
Treatment Date:	6/29/2021	Treatment End Date:	6/29/2021
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):	2110
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:	ACID JOB
Treatment Date:	8/5/2020	Treatment End Date:	8/5/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/MUTUAL SOLVENT, 52 BBLS WATER
Total fluid used in treatment (bbls):	99	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):	47	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:
Treatment Date:	8/23/2017	Treatment End Date:	N/A
Treatment Summary:	Pulled tubing and packer, run clean out assembly, run in hole with 202 joints fiberlined tubing and 7" loc-set packer., WELL IS CURRENTLY SHUT IN, A WITNESSED MIT IS SCHEDULED FOR 8/22/17. THE WELL WILL BE RETURNED TO SERVICE AFTER APPROVED FORM 21.
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:	8/17/2017	Treatment End Date:	N/A
Treatment Summary:	WELLWORK TO REPLACE TUBING AND PACKER, WELL IS CURRENTLY SHUT IN, A WITNESSED MIT IS SCHEDULED FOR 8/22/17. THE WELL WILL BE RETURNED TO SERVICE AFTER APPROVED FORM 21.
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:	1/9/2017	Treatment End Date:	N/A
Treatment Summary:	AC MCLAUGHLIN 17 SHOWED HIGH CASING PRESSURE, WELL WAS SHUT IN AND WELL WORK COMPLETED TO REPLACE TUBING AND PACKER. THE WELL IS SCHEDULED FOR A WITNESSED MIT ON 1/11/2017 WITH COGCC CHUCK BROWNING
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:	6/5/2014	Treatment End Date:	6/5/2014
Treatment Summary:	PUMP 15% HCL
Total fluid used in treatment (bbls):	245	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):	150	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	7/30/2010
Treatment Summary:	ACID STIMULATION 7/30/2010 PUMPED 4000 GALLONS 20% HCI THROUGH TUBING 6581.9' AT 4.2 BPM @ 1700 PSI.
Formation Treatment
Treatment Date:	12/9/2009
Treatment Summary:	OPEN HOLE 6579-6742'. ACID STIMULATION 12/9/09 PUMPED 4,000 GALS 20% HCI THROUGH TUBING 6581.9'. AVERAGE 2.9 BPM @ 1980 PSI.

Test Type	Measure
Tubing Size:	2.875 in.	Tubing Setting Depth:	6528 ft.
Tubing Packer Depth:	6441 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
Initial Test Data:
Test Date:	N/A	Test Method:
Hours Tested:		Gas Type:
Gas Disposal:
GRAVITY_OIL	34

Perforation Data:
Interval Top:	6579 ft.	# Of Holes:
Interval Bottom:	67 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

August 2023 - July 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	204956
GOR
GOR Determination	MCFE
Average BOE per Day	95.469
Average MCFE per Day	553.727

Federal Financial Assurance

Tribal Well