COGIS - WELL Information

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Surface Location Data for API # 05-073-06584                               Status: TA         1/1/2019
Well Name/No: STATE #10S-56W-14-44 (click well name for production)
Operator: WIEPKING-FULLERTON ENERGY LLC - 96340
Status Date: 1/1/2019 Federal or State Lease #: 9369.7
FacilityID: 436493 LocationID: 436496
County: LINCOLN #073 Location: SESE  14 10S56W 6 PM
Field: GREAT PLAINS  - #32756 Elevation: 5,325 ft.
Planned Location       660 FSL  660 FEL Lat/Long: 39.17338/-103.62423 Lat/Long Source: Field Measured
As Drilled Location      Footages Not Available Lat/Long: 39.17338/-103.62423 Lat/Long Source: Field Measured
Wellbore Data for Sidetrack #00                                                    Status: TA         1/1/2019
Spud Date: 3/28/2014 Spud Date is: ACTUAL
Wellbore Permit  
Permit #: Expiration Date: 11/7/2020 4:32:22 PM
Prop Depth/Form: 8320 Surface Mineral Owner Same:
Mineral Owner: STATE Surface Owner: STATE
Unit: Unit Number:
Formation and Spacing: Code: CRTC , Formation: CRETACEOUS , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: MSSP , Formation: MISSISSIPPIAN , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: PENN , Formation: PENNSYLVANIAN , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: PRMN , Formation: PERMIAN , Order: , Unit Acreage: , Drill Unit:
Casing: String Type: SURF , Hole Size: 12.25, Size: 9.625, Top: 0, Depth: 531, Weight: 36
Cement: Sacks: 175, Top: 0, Bottom: 531, Method Grade:
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8309, Weight: 17
Cement: Sacks: 432, Top: 3314, Bottom: 8309, Method Grade:
Wellbore Completed
Completion Date: 5/6/2014
Measured TD: 8320 Measured PB depth: 8264
True Vertical TD: True Vertical PB depth:
Log Types: CBL, Triple combo
Casing: String Type: SURF , Hole Size: 12.25, Size: 9.625, Top: 0, Depth: 531, Weight: 36
Cement: Sacks: 175, Top: 0, Bottom: 531, Method Grade: CALC
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8309, Weight: 17
Cement: Sacks: 432, Top: 3314, Bottom: 8309, Method Grade: CBL
Formation Log Top Log Bottom Cored DSTs
NIOBRARA 3313
DAKOTA 4291
CEDAR HILLS 5514
STONE CORRAL 5713
WOLFCAMP 5882
LANSING 6798
MARMATON 7122
CHEROKEE 7240 Y
ATOKA 7428
MORROW 7722
SPERGEN 7950
Completed information for formation CHRK                                     Status: AB         2/20/2019
1st Production Date: 5/13/2014 Choke Size:
Status Date: 2/20/2019 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: CHEROKEE Status: AB
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 12/5/2018 Treatment End Date: 12/10/2018
Treatment summary: 12/5/18 Perforate 7244-7260', swab well 12/6/18 Acidize w/38 gallons acid and 43 bbls flush 12/10/18 Swab 1 hour, recover 17 bbls all water, set CIBP @7220' w/2 sks cement
Total fluid used in treatment (bbls): 44 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): 1 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls):
Produced water used in treatment (bbls): 43 Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized:
Reason green techniques not utilized:
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 5/13/2014 Treatment End Date: 5/14/2014
Treatment summary: 5/13 - Treat with 19 Bbls 15% HCL, displace with 68 Bbls 2% KCL. 5/13 - Treat with 19 Bbls 15% HCL, diplace with 68 Bbls 2% KCL.
Total fluid used in treatment (bbls): 174 Max pressure during treatment (psi): 1320
Total gas used in treatment (mcf): 0 Fluid density (lbs/gal): 8.4
Type of gas: Number of staged intervals: 0
Total acid used in treatment (bbls): 38 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls): 154
Produced water used in treatment (bbls): 136 Disposition method for flowback: DISPOSAL
Total proppant used (lbs): 0 Green completions techniques utilized: False
Reason green techniques not utilized:
Tubing Size: Tubing Setting Depth:
Tubing Packer Depth: Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
    Initial Test Data:
Test Date: 12/10/2018 Test Method: Swab
Hours Tested: 1 Gas Type:
Gas Disposal:
Test Type Measure
    BBLS_H2O 17    
    BBLS_OIL 26    
    BTU_GAS 1450    
    CALC_BBLS_H2O 408    
    CALC_BBLS_OIL 156    
    CALC_GOR 600    
    CALC_MCF_GAS 84    
    GRAVITY_OIL 36    
    MCF_GAS 14    
    Perforation Data:
    Interval Bottom: 7260 Interval Top: 7244
    # of Holes: 64 Hole Size: 0.25
Completed information for formation LNSNG                                     Status: AB         12/12/2018
1st Production Date: 12/11/2018 Choke Size:
Status Date: 12/12/2018 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: LANSING Status: AB
Formation Treatment Treatment Type:
Treatment Date: 12/10/2018 Treatment End Date: 12/5/2018
Treatment summary: 12/10/18 Perforate 7086-7092', swab well, recover 12 bbls water 12/11/18 Swab well, recover 16 bbls water 12/12/18 Set CIBP @7050'
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):
Produced water used in treatment (bbls): Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized:
Reason green techniques not utilized:
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 LNSNG .
    Perforation Data:
    Interval Bottom: 7092 Interval Top: 7086
    # of Holes: 24 Hole Size: 0.25
Completed information for formation LSNGA                                     Status: TA         1/1/2019
1st Production Date: 12/12/2018 Choke Size:
Status Date: 1/1/2019 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: LANSING A Status: TA
Formation Treatment Treatment Type:
Treatment Date: 12/12/2018 Treatment End Date: 12/13/2018
Treatment summary: 12/12/18 Perforate 6982-6988', swab 5 hours, recover 95 bbls water 12/13/18 Swab 1 hour, recover 30 bbls water 12/14/18 Shut in
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):
Produced water used in treatment (bbls): Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized:
Reason green techniques not utilized:
Tubing Size: Tubing Setting Depth:
Tubing Packer Depth: Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
    Initial Test Data:
Test Date: 12/13/2018 Test Method: Swab
Hours Tested: 1 Gas Type:
Gas Disposal:
Test Type Measure
    BBLS_H2O 30    
    CALC_BBLS_H2O 720    
    Perforation Data:
    Interval Bottom: 6988 Interval Top: 6982
    # of Holes: 24 Hole Size: 0.25