COGIS - WELL Information

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Surface Location Data for API # 05-123-47264                               Status: PR         6/18/2019
Well Name/No: HENDU #23-10HZ (click well name for production)
Operator: KERR MCGEE OIL & GAS ONSHORE LP - 47120
Status Date: 6/18/2019 Federal or State Lease #:
FacilityID: 455788 LocationID: 305091
County: WELD #123 Location: NENE  23 2N66W 6 PM
Field: WATTENBERG  - #90750 Elevation: 5,099 ft.
Planned Location       293 FNL  479 FEL Lat/Long: 40.130221/-104.736592 Lat/Long Source: Field Measured
As Drilled Location      Footages Not Available Lat/Long: 40.130221/-104.736593 Lat/Long Source: Field Measured

Chemical Disclosure Registry
Job Date:         4/14/2019
Job End Date:  4/16/2019
Reported:   6/6/2019
 
Days to report:  51
 
Wellbore Data for Sidetrack #00                                                    Status: PR         6/18/2019
Spud Date: 9/5/2018 Spud Date is: ACTUAL
Wellbore Permit   HORIZONTAL
Permit #: Expiration Date: 6/28/2020 2:50:42 PM
Prop Depth/Form: 13074 Surface Mineral Owner Same:
Mineral Owner: FEE Surface Owner: FEE
Unit: Unit Number:
Formation and Spacing: Code: CODL , Formation: CODELL , Order: , Unit Acreage: 200, Drill Unit: GWA
Casing: String Type: CONDUCTOR , Hole Size: 26, Size: 16, Top: 0, Depth: 80, Weight: 36.94
Cement: Sacks: 64, Top: 0, Bottom: 80, Determination Method:
Casing: String Type: SURF , Hole Size: 13.5, Size: 9.625, Top: 0, Depth: 1500, Weight: 36
Cement: Sacks: 590, Top: 0, Bottom: 1500, Determination Method:
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 13064, Weight: 17
Cement: Sacks: 1532, Top: , Bottom: 13064, Determination Method:
Wellbore Completed
Completion Date: 11/2/2018
Measured TD: 13117 Measured PB depth: 13104
True Vertical TD: 7489 True Vertical PB depth: 7489
Top PZ Location:           Sec: 14 Twp: 2N 66W Footage: 662 S  276 E Depth
Bottom Hole Location:   Sec: 13 Twp: 2N 66W Footages: 595 FSL  486 FEL Depth
Log Types: CBL, MWD/LWD. (GR/RES in API 123-47263).
Casing: String Type: CONDUCTOR , Hole Size: 26, Size: 16, Top: 0, Depth: 101, Weight: 42
Cement: Sacks: 64, Top: 0, Bottom: 101, Determination Method: VISU
Casing: String Type: SURF , Hole Size: 13.5, Size: 9.625, Top: 0, Depth: 1847, Weight: 36
Cement: Sacks: 715, Top: 0, Bottom: 1847, Determination Method: VISU
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 13086, Weight: 17
Cement: Sacks: 1200, Top: 2020, Bottom: 13117, Determination Method: CBL
Formation Log Top Log Bottom Cored DSTs
FOX HILLS 1500
PARKMAN 4319
SUSSEX 4694
SHARON SPRINGS 7353
NIOBRARA 7443
FORT HAYS 7862
CODELL 7922
CARLILE 7995
Completed information for formation CARL                                     Status: CM         9/9/2019
1st Production Date: N/A Choke Size:
Status Date: 9/9/2019 Open Hole Completion: N
Commingled: Y Production Method:
Formation Name: CARLILE Status: CM
Formation Treatment Treatment Type: FRACTURE STIMULATION
Treatment Date: 9/9/2019 Treatment End Date: N/A
Treatment summary: 8019-8241
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:
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 CARL .
    Perforation Data:
    Interval Bottom: 8241 Interval Top: 8019
    # of Holes: 240 Hole Size: 0.44
Completed information for formation CODL                                     Status: CM         9/9/2019
1st Production Date: N/A Choke Size:
Status Date: 9/9/2019 Open Hole Completion: N
Commingled: Y Production Method:
Formation Name: CODELL Status: CM
Formation Treatment Treatment Type: FRACTURE STIMULATION
Treatment Date: 9/9/2019 Treatment End Date: N/A
Treatment summary: 8241-9012, 9418-12681
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:
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 CODL .
    Perforation Data:
    Interval Bottom: 12681 Interval Top: 8241
    # of Holes: 240 Hole Size: 0.44
Completed information for formation FTHYS                                     Status: CM         9/9/2019
1st Production Date: N/A Choke Size:
Status Date: 9/9/2019 Open Hole Completion: N
Commingled: Y Production Method:
Formation Name: FORT HAYS Status: CM
Formation Treatment Treatment Type: FRACTURE STIMULATION
Treatment Date: 9/9/2019 Treatment End Date: N/A
Treatment summary: 9258-9418
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:
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 FTHYS .
    Perforation Data:
    Interval Bottom: 9418 Interval Top: 9258
    # of Holes: 240 Hole Size: 0.44
Completed information for formation NBRR                                     Status: CM         9/9/2019
1st Production Date: N/A Choke Size:
Status Date: 9/9/2019 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: NIOBRARA Status: CM
Formation Treatment Treatment Type: FRACTURE STIMULATION
Treatment Date: 9/9/2019 Treatment End Date: N/A
Treatment summary: 9012-9258
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:
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 NBRR .
    Perforation Data:
    Interval Bottom: 9258 Interval Top: 9012
    # of Holes: 240 Hole Size: 0.44
Completed information for formation NFCC                                     Status: PR         6/18/2019
1st Production Date: 5/3/2019 Choke Size:
Status Date: 6/18/2019 Open Hole Completion: N
Commingled: Y Production Method:
Formation Name: NIOBRARA-FORT HAYS-CODELL-CARLILE Status: PR
Formation Treatment Treatment Type: FRACTURE STIMULATION
Treatment Date: 4/14/2019 Treatment End Date: 4/16/2019
Treatment summary: PERF AND FRAC FROM 8019-12681. 21 BBL 15% HCL ACID, 24 BBL 7.5% HCL ACID, 1,756 BBL PUMP DOWN, 52,361 BBL SLICKWATER, 54,162 TOTAL FLUID, 1,572,820# 40/70 OTTAWA/ST. PETERS, 1,572,820# TOTAL SAND.
Total fluid used in treatment (bbls): 54162 Max pressure during treatment (psi): 7189
Total gas used in treatment (mcf): 0 Fluid density (lbs/gal): 8.3
Type of gas: Number of staged intervals: 12
Total acid used in treatment (bbls): 45 Min frac gradient (psi/ft): 0.81
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls): 7995
Produced water used in treatment (bbls): 54117 Disposition method for flowback: DISPOSAL
Total proppant used (lbs): 1572820 Green completions techniques utilized: True
Reason green techniques not utilized:
Tubing Size: 2.375 Tubing Setting Depth: 7653
Tubing Packer Depth: Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
    Initial Test Data:
Test Date: 6/18/2019 Test Method: Flowing
Hours Tested: 24 Gas Type: WET
Gas Disposal: SOLD
Test Type Measure
    BBLS_H2O 43    
    BBLS_OIL 104    
    BTU_GAS 1266    
    CALC_BBLS_H2O 43    
    CALC_BBLS_OIL 104    
    CALC_GOR 1721    
    CALC_MCF_GAS 179    
    CASING_PRESS 2500    
    GRAVITY_OIL 48    
    MCF_GAS 179    
    TUBING_PRESS 1500    
    Perforation Data:
    Interval Bottom: 12681 Interval Top: 8019
    # of Holes: 240 Hole Size: 0.44