Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-08294		Well Classification: ERIW	Status: IJ - 1/25/2023
Well Name/No:	MCLAUGHLIN, A C #69X (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	1/25/2023
FacilityID:	230626	LocationID:	315318
County:	RIO BLANCO #103	Location:	SWSE 14 2N103W 6
Field:	RANGELY - #72370	Elevation:	5470 ft.
Planned Location:	135FSL 2614 FEL	Lat/Long: 40.136135 / -108.923538	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.136233 / -108.923493	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: OTH Status: IJ - 1/25/2023 Measured TD:

Wellbore Data for Original Wellbore		Wellbore Classification: OTH IJ - 1/25/2023
Wellbore Permit
Permit #:	831147	Expiration Date:	1/24/1984
Prop 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:

Wellbore Completed
Completion Date:	N/A
Measured TD:		Measured PB depth:
True Vertical TD:		True Vertical PB depth:
Log Types:	SECTOR CBL
Casing:	String Type: SURF, Hole Size: 13.75 in., Size: 9.625 in., Top: 0 ft., Depth: 3001 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 1050, Top: 0 ft., Bottom: 3001 ft., Determination Method:
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6716 ft., Weight: 23&26 , Citings Type: ACTUAL
Cement:	Sacks: 1347, Top: 700 ft., Bottom: 6716 ft., Determination Method: CALC
Casing:	String Type: 1ST LINER, Hole Size: , Size: 4.5 in., Top: 0 ft., Depth: 6634 ft., Weight: 11.6 , Citings Type: ACTUAL
Cement:	Sacks: 680, Top: 4800 ft., Bottom: 6634 ft., Determination Method: CBL
Casing:	String Type: STAGE TOOL, Hole Size: , Size: 4.5 in., Top: , Depth: 5392 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: , Top: , Bottom: , Determination Method:
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3563 ft.
MORRISON	3670 ft.
ENTRADA	4504 ft.
NAVAJO	4670 ft.
CHINLE	5311 ft.
WEBER	6183 ft.

Formation WEBR Formation Classification: ERIW Status: IJ - 1/25/2023 Interval Top: 6470 ft. Interval Bottom: 6556 ft.

Completed Information for Formation WEBER

1st Production Date:	6/24/1985	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	1/23/2023	Treatment End Date:	1/23/2023
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH MUTUAL SOLVENT AND 35 BBLS WATER
Total fluid used in treatment (bbls):	83	Max pressure during treatment (psi):	2500
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):	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:	12/14/2021	Treatment End Date:	12/14/2021
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH MUTUAL SOLVENT AND 51 BBLS WATER
Total fluid used in treatment (bbls):	146	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):	51	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:	2/10/2021	Treatment End Date:	2/10/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6BBLS) 15% HCL/6%CITRIC ACID WITH MUTUAL SOLVENT AND 47 BBLS WATER
Total fluid used in treatment (bbls):	95	Max pressure during treatment (psi):	2300
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:	8/6/2020	Treatment End Date:	8/6/2020
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT AND 50 BBLS WATER
Total fluid used in treatment (bbls):	145	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):	50	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:	6/11/2019	Treatment End Date:	6/11/2019
Treatment Summary:	PUMP 4000 GALLONS 15% HCL WITH 80 BBLS OF FRESH WATER
Total fluid used in treatment (bbls):	95	Max pressure during treatment (psi):	1800
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	15	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	80	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	7/13/2016	Treatment End Date:	N/A
Treatment Summary:	Ran new 2 3/8" tubing and 4 1/2" packer on 3/7/2016. Discovered error on previous submitted perforation interval. 6470-6556 is the correct interval, these perforations shot after the 4 1/2" liner run in 2007.
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:	5/12/2014	Treatment End Date:	5/12/2014
Treatment Summary:	PUMP 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	170	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):	75	Disposition method For flowback:	RECYCLE
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized: PIPELINE
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	10/21/2013	Treatment End Date:	10/21/2013
Treatment Summary:	PUMP 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):	95	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):		Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Date:	9/24/2011
Treatment Summary:	PUMP 4000 GALLONS OF 20% HCL THROUGH TUBINGI AT 6580' AT .5 BPM @ 16000 PSI
Formation Treatment
Treatment Date:	4/14/2010
Treatment Summary:	ACIDIZE FORMATION WITH 4000 GALLONS HEATED 20% HCL DOWN TUBING. AT 2.8 BPM @ 2140 PSI.

Tubing Size:	2.375 in.	Tubing Setting Depth:	6441 ft.
Tubing Packer Depth:	6326 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6470 ft.	# Of Holes:	288
Interval Bottom:	6556 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)	457938
GOR
GOR Determination	MCFE
Average BOE per Day	214.390
Average MCFE per Day	1243.461

Federal Financial Assurance

Tribal Well