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COGIS - WELL SCOUT CARD
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 Surface Location
 API# 05-103-06331		Well Classification: ERIW Status: IJ - 5/1/2023
Well Name/No:HAGOOD M C #5
(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:IJStatus Date5/1/2023
FacilityID:229240LocationID:314679
County:RIO BLANCO #103Location:NWSE 15 2N103W 6
Field:RANGELY - #72370Elevation:5575 ft.
Planned Location:1979FSL  1981 FELLat/Long: 40.141215 / -108.940048Lat/Long Source: Calculated From Footages
As Drilled Location:Footages Not AvailableLat/Long: 40.141370 / -108.940110Lat/Long Source: Field Measured
 Wellbore And Formation Details -- select either a wellbore Or formation to expand.
 

Wellbore #00             Wellbore Classification: DSPW             Status: IJ - 5/1/2023             Measured TD: 6720 ft.    Vertical TD: 0 ft.

 Wellbore Data for Original WellboreWellbore Classification: DSPW        IJ - 5/1/2023
Wellbore Permit
Permit #:10001 Expiration Date:2/24/2000
Prop Depth/Form:
Surface Mineral Owner Same:Not available
Mineral Owner:FEDERALSurface Owner:Not available
Unit: Unit Number:D-052265-A
Formation And Spacing:Code: WEBR , Formation: WEBER , Order: 0 , Unit Acreage: 0, Drill Unit:
Wellbore Completed
Completion Date:3/1/1947
Measured TD:6720 ft.Measured PB depth:6640 ft.
True Vertical TD:0 ft.True Vertical PB depth:
Casing:String Type: CONDUCTOR, Hole Size: , Size: 13.625 in., Top: 0 ft., Depth: 96 ft., Weight: 36 , Citings Type: ACTUAL
Cement:Sacks: 80, Top: 0 ft., Bottom: 96 ft., Determination Method: CALC
Casing:String Type: SURF, Hole Size: , Size: 9.625 in., Top: 0 ft., Depth: 616 ft., Weight: 32.3 , Citings Type: ACTUAL
Cement:Sacks: 200, Top: 0 ft., Bottom: 616 ft., Determination Method: CALC
Casing:String Type: 1ST, Hole Size: , Size: 7 in., Top: 0 ft., Depth: 6415 ft., Weight: 23 , Citings Type: ACTUAL
Cement:Sacks: 900, Top: 3766 ft., Bottom: 6415 ft., Determination Method: CALC
Casing:String Type: OPEN HOLE, Hole Size: , Size: , Top: 6415 ft., Depth: 6720 ft., Weight: , Citings Type: ACTUAL
Cement:Sacks: , Top: , Bottom: , Determination Method:
FormationInterval TopLog BottomCoredDSTs
WEBER6410 ft.

Formation WEBR                     Formation Classification:  ERIW                     Status:  IJ - 5/1/2023                  Interval Top: 6415 ft.    Interval Bottom: 6640 ft.

 Completed Information for Formation WEBER
1st Production Date:3/17/1947Choke Size: 
Formation Name:WEBERCommingled:
Production Method:
Open Hole Completion:Yes
Formation Treatment
Treatment Type:
Treatment Date:7/20/2023Treatment End Date:N/A
Treatment Summary:Rigged up. Released PS1X packer and laid down injection tubing and PS1X packer. Cleaned out to top of Loc-set packer. Release and pull Loc-set packer. Drill out fiberglass tailpipe and clean out to PBTD at 6,640’. Run in hole and set 7” loc-set packer @ 6,249’. Perform successful preliminary pressure test to 1,250 psi. Run 7” PS1X packer and 2-7/8” DYB Fiberglass tubing. Successfully test tubing to 2,500 psi and casing to 1,300 psi. Witness MIT scheduled for 6/1/22.
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:12/30/2021Treatment End Date:N/A
Treatment Summary:Pulled the tubing and top packer, cleaning out to the bottom packer, run a new top packer and tubing, and stripping on a TM-40 spool instead of a full wellhead upgrade.
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:6/17/2021Treatment End Date:6/17/2021
Treatment Summary:PUMPED 4000 GALLONS (95.2 bbls) 15% HCL, WITH 6% CITRIC AND INHIBITOR AND 40 BBLS FRESH WATER. CONVERTED TO WATER INJECTION 03/15/1974
Total fluid used in treatment (bbls):135Max 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):95Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):40Disposition method For flowback:
Total proppant used (lbs):Green completions techniques utilized:--
Reason green techniques Not utilized: 
Formation Treatment
Treatment Type:ACID JOB
Treatment Date:2/2/2019Treatment End Date:2/2/2019
Treatment Summary:PUMPED 2000 GALLONS 15% HCL, WITH 110 GALLONS SOLVENT AND 104 BBLS FRESH WATER.
Total fluid used in treatment (bbls):154Max 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):48Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):104Disposition method For flowback:
Total proppant used (lbs):Green completions techniques utilized:--
Reason green techniques Not utilized: 
Formation Treatment
Treatment Type:ACID JOB
Treatment Date:12/5/2016Treatment End Date:12/5/2016
Treatment Summary:PUMPED 2000 GALLONS 15% HCL AND 110 GALLONS SOLVENT WITH 154 BBLS FRESH WATER
Total fluid used in treatment (bbls):204Max pressure during treatment (psi):2256
Total gas used in treatment (mcf):Fluid density (lbs/gal):
Type Of gas:Number Of staged intervals:
Total acid used in treatment (bbls):48Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):154Disposition method For flowback:
Total proppant used (lbs):Green completions techniques utilized:--
Reason green techniques Not utilized: 
Formation Treatment
Treatment Type:ACID JOB
Treatment Date:12/4/2014Treatment End Date:12/4/2014
Treatment Summary:PUMP 4000 GALLONS 15% HCL
Total fluid used in treatment (bbls):227Max 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):95Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):132Disposition method For flowback:
Total proppant used (lbs):Green completions techniques utilized:--
Reason green techniques Not utilized: 
Formation Treatment
Treatment Type:ACID JOB
Treatment Date:5/13/2014Treatment End Date:5/13/2014
Treatment Summary:ACID STIMULATION
Total fluid used in treatment (bbls):263Max 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):96Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):167Disposition method For flowback:
Total proppant used (lbs):Green completions techniques utilized:--
Reason green techniques Not utilized: 
Formation Treatment
Treatment Date:8/9/2011
Treatment Summary:ACID STIMULATION - PUMPED 4000 GALLONS OF 20% HCL THROUGH END OF TUBING 6250' AT STARTING PRESSURE OF 1000 PSI @ 3/4 BPM.
Formation Treatment
Treatment Date:3/11/2010
Treatment Summary:OH 6415-6720. ACID STIMULATION 3/11/2010 PUMPED 4000 GALLONS OF 20 PERCENT HCI THROUGH END 6590. AT STARTING PRESSURE OF 1829.
Tubing Size:2.875 in.Tubing Setting Depth:6286 ft.
Tubing Packer Depth:6156 ft.Tubing Multiple Packer:
Open Hole Top:6415 ft.Open Hole Bottom:6640 ft.
No Initial Test Data was found for formation WEBR.
Perforation Data:
Interval Top:6415 ft.# Of Holes:
Interval Bottom:6640 ft.Hole Size:
Primary Well Designation:
None      i
            All DesignationsDate
Reported PluggedN 
Out Of Service RepurposedN 
Out Of ServiceN 
Inactive ExceptionN 
Noticed InactiveN 
Defined InactiveN 
Low ProducingN 

BOE/MCFE/GOR Calculations
Production for Previous 12 Months
June 2023 - May 2024i
Total Oil Produced (Barrels)0
Total Gas Produced (MCF)590407
GOR
GOR DeterminationMCFE
Average BOE per Day278.482
Average MCFE per Day1615.182

 Federal Financial Assurance  i Y

 Tribal Well  i No