Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-10726		Well Classification: ERIW	Status: IJ - 4/26/2023
Well Name/No:	A.C.MCLAUGHLIN #91X (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	4/26/2023
FacilityID:	284109	LocationID:	316528
County:	RIO BLANCO #103	Location:	SWSW 11 2N103W 6
Field:	RANGELY - #72370	Elevation:	5532 ft.
Planned Location:	59FSL 1265 FEL	Lat/Long: 40.150453 / -108.918760	Lat/Long Source: Field Measured
As Drilled Location:	Footages Not Available	Lat/Long: 40.150460 / -108.918780	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: OTH Status: IJ - 4/26/2023 Measured TD: 6705 ft. Vertical TD: 6697 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: OTH IJ - 4/26/2023
Wellbore Permit
Permit #:	20060514	Expiration Date:	4/4/2007
Prop Depth/Form:	6832 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:	8/18/2006
Spud Date:	7/31/2006	Spud Date Is:	ACTUAL
Measured TD:	6705 ft.	Measured PB depth:	6705 ft.
True Vertical TD:	6697 ft.	True Vertical PB depth:
Log Types:	ARRAY INDUCTION, SECTOR BOND GAMMA RAY CCL, COMP.PHOTO DENSITY, DUAL NEUTRON LOG
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 2098 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 790, Top: 0 ft., Bottom: 2098 ft., Determination Method: CALC
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6494 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 620, Top: 0 ft., Bottom: 6494 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3912 ft.		N	N
MORRISON	4023 ft.		N	N
CURTIS	4722 ft.		N	N
ENTRADA	4823 ft.		N	N
CARMEL	4966 ft.		N	N
NAVAJO	5019 ft.		N	N
CHINLE	5661 ft.		N	N
SHINARUMP	5792 ft.		N	N
MOENKOPI	5856 ft.		N	N
WEBER	6536 ft.		N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 4/26/2023 Interval Top: 6494 ft. Interval Bottom: 6705 ft.

Completed Information for Formation WEBER

1st Production Date:	9/15/2006	Choke Size:
Formation Name:	WEBER	Commingled:	No
Production Method:
Open Hole Completion:	Yes

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	4/25/2023	Treatment End Date:	4/25/2023
Treatment Summary:	PUMPED 640 gallons (15.2 BBLS) of 15% HCL, 104 gallons (2.4 BBLS) Acroline and 290 BBLS Fresh water.
Total fluid used in treatment (bbls):	307	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):	17	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	290	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:	5/18/2022	Treatment End Date:	5/18/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.2 BBLS) 15% HCL WITH MUTUAL SOLVENT AND 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:	2/8/2021	Treatment End Date:	2/8/2021
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL WITH MUTUAL SOLVENT AND 48 BBLS WATER.
Total fluid used in treatment (bbls):	96	Max pressure during treatment (psi):	2340
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):	48	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 4000 GALLONS (95.2 BBLS) 15% HCL W/SOLVENT, 50 BBLS WATER
Total fluid used in treatment (bbls):	145	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):	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:	11/7/2019	Treatment End Date:	11/7/2019
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL, 38.0 BBLS FRESH WATER
Total fluid used in treatment (bbls):	85	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):	38	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:	5/14/2014	Treatment End Date:	5/14/2014
Treatment Summary:	ACID STIMULATION
Total fluid used in treatment (bbls):	170	Max pressure during treatment (psi):	1900
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):	75	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:	8/17/2010
Treatment Summary:	acid stimulation 8/17/10 pumped 4000 gal 20% HCL through end of coil tubing 6506' at starting pressure of 1000psi.
Formation Treatment
Treatment Date:	8/18/2006
Treatment Summary:

Tubing Size:	2.875 in.	Tubing Setting Depth:	6506 ft.
Tubing Packer Depth:	6418 ft.	Tubing Multiple Packer:
Open Hole Top:	6494 ft.	Open Hole Bottom:	6705 ft.
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	6494 ft.	# Of Holes:
Interval Bottom:	6705 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)	150449
GOR
GOR Determination	MCFE
Average BOE per Day	70.655
Average MCFE per Day	409.806

Federal Financial Assurance

Tribal Well