Facility Detail

COGIS - WELL SCOUT CARD

Related Insp MIT GIS Doc COA Wellbore Orders Bradenhead
Surface Location API# 05-103-09178		Well Classification: ERIW	Status: IJ - 10/13/2022
Well Name/No:	RAVEN #A-1AX (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	10/13/2022
FacilityID:	231508	LocationID:	315756
County:	RIO BLANCO #103	Location:	NWSE 30 2N102W 6
Field:	RANGELY - #72370	Elevation:	5337 ft.
Planned Location:	2464FSL 1899 FEL	Lat/Long: 40.113515 / -108.883536	Lat/Long Source: Calculated From Footages
As Drilled Location:	Footages Not Available	Lat/Long: 40.113554 / -108.883482	Lat/Long Source: Field Measured

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

Wellbore #00 Wellbore Classification: ERIW Status: IJ - 10/13/2022 Measured TD: 6596 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: ERIW IJ - 10/13/2022
Wellbore Permit
Permit #:	100001	Expiration Date:	10/26/1984
Proposed Depth/Form:
Surface Mineral Owner Same:	Not available
Mineral Owner:	FEDERAL	Surface Owner:	Not available
Unit:		Unit Number:	D-032783A
Formation And Spacing:	Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:

Wellbore Completed
Completion Date:	7/19/2014
Spud Date:	9/8/1984	Spud Date Is:	ACTUAL
Measured TD:	6596 ft.	Measured PB depth:	6532 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	CEMENT BOND LOG AND CIRCUMFERENTILA ACOUSTIC SCANNING TOOL LOG
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 2478 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 570, Top: 0 ft., Bottom: 2478 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 6593 ft., Weight: 23 , Citings Type: ACTUAL
Cement:	Sacks: 1060, Top: 3830 ft., Bottom: 6593 ft., Determination Method: CBL
Casing:	String Type: 1ST LINER, Hole Size: 7 in., Size: 5.5 in., Top: 0 ft., Depth: 6544 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 340, Top: 1806 ft., Bottom: 6544 ft., Determination Method: CBL
Additional Cement:	String Type: 1ST , Top: 0 ft., Depth: 2538 ft., Bottom: 2830 ft., Sacks: 500, Method: SQUEEZE
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	3056 ft.
MORRISON	3156 ft.
ENTRADA	3927 ft.
NAVAJO	4125 ft.
CHINLE	4736 ft.
WEBER	5600 ft.	6596 ft.	N	N

Formation WEBR Formation Classification: ERIW Status: IJ - 10/13/2022 Interval Top: 5684 ft. Interval Bottom: 6448 ft.

Completed Information for Formation WEBER

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

Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	10/11/2022	Treatment End Date:	10/11/2022
Treatment Summary:	PUMPED 4000 GALLONS (95.26 BBLS) 15% HCL WMUTUAL SOLVENT AND 35 BBLS POTABLE 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:	9/18/2020	Treatment End Date:	9/18/2020
Treatment Summary:	PUMPED 2000 GALLONS (47.6 BBLS) 15% HCL W/6% CITRIC ACID AND 60 BBLS POTABLE WATER
Total fluid used in treatment (bbls):	107	Max pressure during treatment (psi):	220
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):	60	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:	9/7/2018	Treatment End Date:	9/7/2018
Treatment Summary:	Pumped 2000 gallons 15% HCL with 110 gallons solvent, with 95 bbls fresh water. Starting at 0.7 bpm 1800 psi.
Total fluid used in treatment (bbls):	145	Max pressure during treatment (psi):	2450
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):	95	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:	12/4/2016	Treatment End Date:	12/4/2016
Treatment Summary:	PUMPED 47.6 BBLS 15% HCL WITH 110 GALLONS MUSOL SOLVENT, FLUSH WITH 130 BBLS FRESH WATER
Total fluid used in treatment (bbls):	180	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):	48	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	130	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:
Treatment Date:	9/11/2014	Treatment End Date:	N/A
Treatment Summary:	RAN LINER FROM SURFACE TO 6544' PERFORATED LINER IN 10 RUNS 6448-6313, 6306-6286, 6280-6192, 6484-6085, 6075-5987, 5974-5958, 5952-5900, 5893-5820, 5802-5762, AND 5753-5684'.
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:

Tubing Size:	2.875 in.	Tubing Setting Depth:	5661 ft.
Tubing Packer Depth:	5592 ft.	Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
No Initial Test Data was found for formation WEBR.

Perforation Data:
Interval Top:	5684 ft.	# Of Holes:	528
Interval Bottom:	6448 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

December 2023 - November 2024	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	224132
GOR
GOR Determination	MCFE
Average BOE per Day	105.632
Average MCFE per Day	612.671

Federal Financial Assurance

Tribal Well