COGIS - WELL Information

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Surface Location Data for API # 05-073-06736                               Status: PR         4/27/2018
Well Name/No: Rogue #10-25 (click well name for production)
Operator: MURFIN DRILLING COMPANY INC - 61650
Status Date: 4/27/2018 Federal or State Lease #:
FacilityID: 453404 LocationID: 453405
County: LINCOLN #073 Location: NWSE  25 9S56W 6 PM
Field: WILDCAT  - #99999 Elevation: Unknown ft.
Planned Location       2299 FSL  1647 FEL Lat/Long: 39.23592/-103.60887 Lat/Long Source: Field Measured
As Drilled Location      Footages Not Available Lat/Long: 39.23592/-103.60886 Lat/Long Source: Field Measured
Wellbore Data for Sidetrack #00                                                    Status: PR         4/27/2018
Spud Date: 1/18/2018 Spud Date is: ACTUAL
Wellbore Permit   VERTICAL
Permit #: Expiration Date: 12/16/2019 9:25:22 PM
Prop Depth/Form: 8400 Surface Mineral Owner Same:
Mineral Owner: FEE Surface Owner: FEE
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:
Casing: String Type: CONDUCTOR , Hole Size: 26, Size: 16, Top: 0, Depth: 125, Weight: 39.945lbs
Cement: Sacks: 12, Top: 0, Bottom: 125, Method Grade:
Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 430, Weight: 24
Cement: Sacks: 280, Top: 0, Bottom: 430, Method Grade:
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8400, Weight: 17
Cement: Sacks: 410, Top: 4200, Bottom: 8400, Method Grade:
Wellbore Completed
Completion Date: 2/9/2018
Measured TD: 8187 Measured PB depth: 7652
True Vertical TD: True Vertical PB depth:
Log Types: Induction, Micro, Neutron Density, Sonic, Caliper
Casing: String Type: CONDUCTOR , Hole Size: 26, Size: 16, Top: 0, Depth: 124, Weight: 36
Cement: Sacks: 8, Top: 0, Bottom: 124, Method Grade: VISU
Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 475, Weight: 24
Cement: Sacks: 325, Top: 0, Bottom: 475, Method Grade: VISU
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 7697, Weight: 17
Cement: Sacks: 325, Top: 5001, Bottom: 7697, Method Grade: CBL
Additional Cement: String Type: 1ST , Top: 0, Depth: 5001, Bottom: 5001, Sacks: 240, Method Grade: DV TOOL
Formation Log Top Log Bottom Cored DSTs
NIOBRARA 3551 N
D SAND 4350 N
J SAND 4396 N
LANSING 6821 Y
MARMATON 7203 Y
FORT SCOTT 7266 Y
MORROW 7755 N
MISSISSIPPIAN 7997 N
ARBUCKLE 8100 N
Completed information for formation FRSC                                     Status: AB         3/26/2018
1st Production Date: N/A Choke Size:
Status Date: 3/26/2018 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: FORT SCOTT Status: AB
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 3/20/2018 Treatment End Date: 3/20/2018
Treatment summary: 7326 -7332 perforations: Trt w/ 1000 gal 15% MCA, staged up to 900#, started feeding 1/4 BPM @ 400#, max rate 1/2 BPM, ISIP 100#. 7308 - 7318 perforations: Tested natural, no stimulation. 7272 - 7276 perforations: Treated w/ 800 gal 15% MCA, 0.1% surf., 3% solv., 500# max, max rate 1/2 BPM @ 0#.
Total fluid used in treatment (bbls): 129 Max pressure during treatment (psi): 900
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 43 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls): 0
Produced water used in treatment (bbls): 86 Disposition method for flowback:
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: 3/21/2018 Test Method: swab
Hours Tested: 3 Gas Type:
Gas Disposal:
Test Type Measure
    BBLS_H2O 52    
    BBLS_OIL 2    
    CALC_BBLS_H2O 416    
    CALC_BBLS_OIL 18    
    GRAVITY_OIL 36    
    Perforation Data:
    Interval Bottom: 7332 Interval Top: 7272
    # of Holes: 80 Hole Size: 0.52
Completed information for formation LNSNG                                     Status: PR         4/27/2018
1st Production Date: 4/25/2018 Choke Size:
Status Date: 4/27/2018 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: LANSING Status: PR
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 3/29/2018 Treatment End Date: 3/29/2018
Treatment summary: Exline formation treat w/ 800 gal 15% MCA, 0.1% surf., 3% solv. Max press 500#, max rate feeding @ 1.25 BPM on vac, ISIP: vac
Total fluid used in treatment (bbls): 62 Max pressure during treatment (psi): 500
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 19 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls): 0
Produced water used in treatment (bbls): 43 Disposition method for flowback:
Total proppant used (lbs): Green completions techniques utilized: False
Reason green techniques not utilized: PIPELINE
Tubing Size: 2.875 Tubing Setting Depth: 7176
Tubing Packer Depth: Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
    Initial Test Data:
Test Date: 4/27/2018 Test Method: Pumping
Hours Tested: 24 Gas Type: DRY
Gas Disposal: FLARED
Test Type Measure
    BBLS_H2O 40    
    BBLS_OIL 115    
    BTU_GAS 1385    
    CALC_BBLS_H2O 40    
    CALC_BBLS_OIL 115    
    CALC_GOR 217    
    CALC_MCF_GAS 25    
    CASING_PRESS 170    
    GRAVITY_OIL 36    
    MCF_GAS 25    
    TUBING_PRESS 200    
    Perforation Data:
    Interval Bottom: 7132 Interval Top: 7127
    # of Holes: 20 Hole Size: 0.52
Completed information for formation MRTN                                     Status: TA         4/2/2018
1st Production Date: N/A Choke Size:
Status Date: 4/2/2018 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: MARMATON Status: TA
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 3/27/2018 Treatment End Date: 3/27/2018
Treatment summary: Treat w/ 1,000 gal 15% MCA, 0.1% surf, 3% solv, max press 1200#, broke back to 0.4 BPM @ 450#, increased rate to 0.5 @ 800#, ISIP 800#, in 30 min had 250#.
Total fluid used in treatment (bbls): 67 Max pressure during treatment (psi): 1200
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 24 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls): 0
Produced water used in treatment (bbls): 43 Disposition method for flowback:
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: 3/29/2018 Test Method: swab
Hours Tested: 1 Gas Type:
Gas Disposal:
Test Type Measure
    BBLS_H2O 9    
    BBLS_OIL 4    
    CALC_BBLS_H2O 216    
    CALC_BBLS_OIL 50    
    GRAVITY_OIL 35    
    Perforation Data:
    Interval Bottom: 7222 Interval Top: 7214
    # of Holes: 32 Hole Size: 0.52
Completed information for formation N-COM                                     Status: DG         2/26/2018
1st Production Date: 1/1/2018 Choke Size:
Status Date: 2/26/2018 Open Hole Completion:
Commingled: Production Method:
Formation Name: NOT COMPLETED Status: DG
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 .