COGIS - WELL Information

Scout Card             
 Related    Insp.
 MIT
GIS Doc   COA   Wellbore  Expanded OrdersOrders
Surface Location Data for API # 05-057-06466                               Status: SI         5/1/2019
Well Name/No: Judy #1-30 (click well name for production)
Operator: SANDRIDGE EXPLORATION & PRODUCTION LLC - 10598
Status Date: 5/1/2019 Federal or State Lease #:
FacilityID: 295293 LocationID: 324751
County: JACKSON #057 Location: NESE  30 7N80W 6 PM
Field: WILDCAT  - #99999 Elevation: 8,183 ft.
Planned Location       2164 FSL  790 FEL Lat/Long: 40.547044/-106.410175 Lat/Long Source: Field Measured
As Drilled Location      Footages Not Available Lat/Long: 40.547043/-106.41017 Lat/Long Source: Field Measured

Chemical Disclosure Registry
Job Date:         9/28/2018
Job End Date:  9/28/2018
Reported:   10/25/2018
 
Days to report:  27
 
Wellbore Data for Sidetrack #00                                                    Status: SI         5/1/2019
Spud Date: 6/15/2008 Spud Date is: ACTUAL
Wellbore Permit  
Permit #: Expiration Date: 4/4/2021 1:34:59 PM
Prop Depth/Form: 8190 Surface Mineral Owner Same:
Mineral Owner: FEE Surface Owner: FEE
Unit: Unit Number:
Formation and Spacing: Code: DKTA , Formation: DAKOTA , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: ENRD , Formation: ENTRADA , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: FRTR , Formation: FRONTIER , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: LKTA , Formation: LAKOTA , Order: , Unit Acreage: , Drill Unit:
Casing: String Type: CONDUCTOR , Hole Size: 24, Size: 16, Top: 0, Depth: 40, Weight:
Cement: Sacks: 50, Top: 0, Bottom: 40, Method Grade:
Casing: String Type: SURF , Hole Size: 12.25, Size: 9.625, Top: 0, Depth: 802, Weight: 36
Cement: Sacks: 450, Top: 0, Bottom: 802, Method Grade:
Casing: String Type: 1ST , Hole Size: 8.75, Size: 7, Top: 0, Depth: 8185, Weight: 26
Cement: Sacks: 820, Top: , Bottom: 8185, Method Grade:
Wellbore Completed
Completion Date: 6/30/2008
Measured TD: 8190 Measured PB depth: 8143
True Vertical TD: 8187 True Vertical PB depth: 8140
Log Types: QUAD-COMBO, GR DEN/NEU, ARRAY IND, SONIC (BHC) 8000-803, CBL, HVCL, MUD
Casing: String Type: CONDUCTOR , Hole Size: 24, Size: 16, Top: 0, Depth: 40, Weight:
Cement: Sacks: 0, Top: 0, Bottom: 40, Method Grade:
Casing: String Type: SURF , Hole Size: 12.25, Size: 9.625, Top: 0, Depth: 802, Weight: 36
Cement: Sacks: 450, Top: 0, Bottom: 802, Method Grade: VISU
Casing: String Type: 1ST , Hole Size: 8.75, Size: 7, Top: 0, Depth: 8185, Weight: 23
Cement: Sacks: 820, Top: 0, Bottom: 8185, Method Grade: CBL
Formation Log Top Log Bottom Cored DSTs
TERTIARY 0 N N
SUDDUTH COAL 2895 N N
SUSSEX 5072 N N
SHANNON 5450 N N
NIOBRARA 6766 N N
FRONTIER 7301 N N
MOWRY 7630 N N
DAKOTA 7730 N N
LAKOTA 7829
MORRISON 7904 N N
Completed information for formation DK-LK                                     Status: SI         5/1/2019
1st Production Date: 10/2/2017 Choke Size:
Status Date: 5/1/2019 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: DAKOTA-LAKOTA Status: SI
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 9/28/2018 Treatment End Date: 9/28/2018
Treatment summary: 36 bbls 15% NEFE HCL acid and 2603 bbls total crosslink water used and 131,900 lbs total 20/40 sand.
Total fluid used in treatment (bbls): 2603 Max pressure during treatment (psi): 4696
Total gas used in treatment (mcf): Fluid density (lbs/gal): 8.33
Type of gas: Number of staged intervals: 1
Total acid used in treatment (bbls): 36 Min frac gradient (psi/ft): 0.85
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 0
Produced water used in treatment (bbls): 2567 Disposition method for flowback:
Total proppant used (lbs): 131900 Green completions techniques utilized:
Reason green techniques not utilized: PIPELINE
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 9/12/2017 Treatment End Date: 9/14/2017
Treatment summary: SD tried an acid job but was only able to pump 55 gals of mutual solvents w/30 bbls of fresh water/KCl combo before we had equipment failure and stopped the job.
Total fluid used in treatment (bbls): 32 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): 10 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls):
Produced water used in treatment (bbls): 22 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: 11/8/2016 Treatment End Date: 11/8/2016
Treatment summary: 6,090 gal. Fresh water & 12,012 gal 15% HCL acid
Total fluid used in treatment (bbls): 431 Max pressure during treatment (psi): 4160
Total gas used in treatment (mcf): 0 Fluid density (lbs/gal): 8.6
Type of gas: Number of staged intervals: 7
Total acid used in treatment (bbls): 286 Min frac gradient (psi/ft): 0.73
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls): 0
Produced water used in treatment (bbls): 145 Disposition method for flowback:
Total proppant used (lbs): 0 Green completions techniques utilized:
Reason green techniques not utilized:
Tubing Size: 3.5 Tubing Setting Depth: 7664
Tubing Packer Depth: 7650 Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
No Initial Test Data was found for formation DK-LK .
    Perforation Data:
    Interval Bottom: 7902 Interval Top: 7730
    # of Holes: 472 Hole Size: 0.58
Completed information for formation DKTA                                     Status: CM         10/23/2017
1st Production Date: 10/2/2017 Choke Size:
Status Date: 10/23/2017 Open Hole Completion: N
Commingled: Y Production Method:
Formation Name: DAKOTA Status: CM
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 9/12/2017 Treatment End Date: 9/14/2017
Treatment summary: SD tried an acid job but was only able to pump 55 gals of mutual solvents w/30 bbls of fresh water/KCl combo before we had equipment failure and stopped the job.
Total fluid used in treatment (bbls): 32 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): 10 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls):
Produced water used in treatment (bbls): 22 Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized: True
Reason green techniques not utilized:
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 11/8/2016 Treatment End Date: 11/8/2016
Treatment summary: 2375 gal fresh water & 4,662 gal 15% HCL acid
Total fluid used in treatment (bbls): 168 Max pressure during treatment (psi): 4160
Total gas used in treatment (mcf): 0 Fluid density (lbs/gal): 8.6
Type of gas: Number of staged intervals: 3
Total acid used in treatment (bbls): 111 Min frac gradient (psi/ft): 0.73
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls): 0
Produced water used in treatment (bbls): 57 Disposition method for flowback:
Total proppant used (lbs): 0 Green completions techniques utilized:
Reason green techniques not utilized:
Tubing Size: 3.5 Tubing Setting Depth: 7701
Tubing Packer Depth: 7687 Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
No Initial Test Data was found for formation DKTA .
    Perforation Data:
    Interval Bottom: 7776 Interval Top: 7730
    # of Holes: 184 Hole Size: 0.58
Completed information for formation LKTA                                     Status: CM         10/23/2017
1st Production Date: 10/2/2017 Choke Size:
Status Date: 10/23/2017 Open Hole Completion: N
Commingled: Y Production Method:
Formation Name: LAKOTA Status: CM
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 9/14/2017 Treatment End Date: 9/14/2017
Treatment summary: SD tried an acid job but was only able to pump 55 gals of mutual solvents w/30 bbls of fresh water/KCl combo before we had equipment failure and stopped the job.
Total fluid used in treatment (bbls): 32 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): 10 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls):
Produced water used in treatment (bbls): 22 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: 11/8/2016 Treatment End Date: 11/8/2016
Treatment summary: 3715 gal fresh water & 7327 gal 15% HCL acid
Total fluid used in treatment (bbls): 263 Max pressure during treatment (psi): 4160
Total gas used in treatment (mcf): 0 Fluid density (lbs/gal): 8.6
Type of gas: Number of staged intervals: 4
Total acid used in treatment (bbls): 174 Min frac gradient (psi/ft): 0.73
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls): 0
Produced water used in treatment (bbls): 89 Disposition method for flowback:
Total proppant used (lbs): 0 Green completions techniques utilized:
Reason green techniques not utilized:
Tubing Size: 3.5 Tubing Setting Depth: 7701
Tubing Packer Depth: 7687 Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
No Initial Test Data was found for formation LKTA .
    Perforation Data:
    Interval Bottom: 7902 Interval Top: 7830
    # of Holes: 288 Hole Size: 0.58
Completed information for formation N-COM                                     Status: WO         5/16/2019
1st Production Date: 9/1/2016 Choke Size:
Status Date: 5/16/2019 Open Hole Completion:
Commingled: Production Method:
Formation Name: NOT COMPLETED Status: WO
Tubing Size: Tubing Setting Depth:
Tubing Packer Depth: Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
No Initial Test Data was found for formation N-COM .
No Perforation Data was found for formation N-COM .