COGIS - WELL Information

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Surface Location Data for API # 05-073-06361                               Status: PR         2/24/2017
Well Name/No: Steamboat Hansen #8-10 (click well name for production)
Operator: NIGHTHAWK PRODUCTION LLC - 10399
Status Date: 2/24/2017 12:54:28 PM Federal or State Lease #:
FacilityID: 300214 LocationID: 309655
County: LINCOLN #073 Location: SENE  10 6S54W 6 PM
Field: ARIKAREE CREEK  - #2914 Elevation: 5,221 ft.
Planned Location       2522 FNL  983 FEL Lat/Long: 39.5435/-103.41979 Lat/Long Source: Field Measured
As Drilled Location      Footages Not Available Lat/Long: 39.54349/-103.41979 Lat/Long Source: Field Measured
Wellbore Data for Sidetrack #00                                                    Status: PR         2/24/2017
Spud Date: 10/2/2012 Spud Date is: ACTUAL
Wellbore Permit  
Permit #: Expiration Date: 8/26/2014 2:29:09 PM
Prop Depth/Form: 8400 Surface Mineral Owner Same: N
Mineral Owner: FEE Surface Owner: FEE
Unit: Unit Number:
Formation and Spacing: Code: ABCK , Formation: ARBUCKLE , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: ATOK , Formation: ATOKA , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: CHRK , Formation: CHEROKEE , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: KEYES , Formation: KEYES , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: LNSNG , Formation: LANSING , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: MRRW , Formation: MORROW , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: MRTN , Formation: MARMATON , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: MSSP , Formation: MISSISSIPPIAN , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: SPGN , Formation: SPERGEN , Order: , Unit Acreage: , Drill Unit:
Formation and Spacing: Code: WRSW , Formation: WARSAW , Order: , Unit Acreage: , Drill Unit:
Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 300, Weight: 24
Cement: Sacks: 197, Top: 0, Bottom: 300, Method Grade:
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8400, Weight: 17
Cement: Sacks: 574, Top: 3649, Bottom: 8400, Method Grade:
Casing: String Type: 2ND , Hole Size: 7.875, Size: 5.5, Top: , Depth: 8400, Weight: 17
Cement: Sacks: 522, Top: 2500, Bottom: 8400, Method Grade:
Wellbore Completed
Completion Date: 10/23/2012
Measured TD: 8500 Measured PB depth: 8380
True Vertical TD: True Vertical PB depth:
Log Types: TRIPLE COMBO/NEUTRON/DENSITY/INDUCTION/SONIC/CBL
Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 309, Weight:
Cement: Sacks: 130, Top: 0, Bottom: 309, Method Grade: CALC
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8484, Weight:
Cement: Sacks: 657, Top: 3560, Bottom: 8500, Method Grade: CBL
Formation Log Top Log Bottom Cored DSTs
DAKOTA 4614
LANSING 6903
MARMATON 7232
CHEROKEE 7398
ATOKA 7546
MORROW 7803
KEYES 7900
SPERGEN 8075
WARSAW 8125
ARBUCKLE 8169
Completed information for formation SPGN                                     Status: PR         2/24/2017
1st Production Date: 11/8/2012 Choke Size:
Status Date: 2/24/2017 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: SPERGEN Status: PR
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 2/15/2017 Treatment End Date: 2/20/2017
Treatment summary: Pumped 6000 gallons of 2% KCl with 88.5 bbls of additives and 140 bio balls.
Total fluid used in treatment (bbls): 231 Max pressure during treatment (psi): 1630
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 88 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): 143 Total flowback volume recovered (bbls): 289
Produced water used in treatment (bbls): Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized: True
Reason green techniques not utilized: PIPELINE
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 6/6/2016 Treatment End Date: 6/10/2016
Treatment summary: Acidization only Treated well with 172 bbls (7224 gallons) of stimulation fluid Dropped 140 bio diversion balls Displaced with 33 bbls of KCl flush/displacement.
Total fluid used in treatment (bbls): 205 Max pressure during treatment (psi): 1500
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 42 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 179
Produced water used in treatment (bbls): 163 Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized: False
Reason green techniques not utilized: PIPELINE
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 2/5/2016 Treatment End Date: 2/9/2016
Treatment summary: Acidize only Treated well with 6,000gallons (140 bbls) 2% KCI with 1,000 gallons of acetone, 750 gallons of ethanol, with anti-sludge & iron control. Dropped 140 bio diversion balls Displaced with 34 bbls of flush water
Total fluid used in treatment (bbls): 180 Max pressure during treatment (psi): 1720
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 42 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 111
Produced water used in treatment (bbls): 138 Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized:
Reason green techniques not utilized: PIPELINE
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 7/14/2015 Treatment End Date: 7/15/2015
Treatment summary: Acidize only Treat well with 4,970 gallons (119 bbls) of 2% KCL with acetone , ethanol, RAS-92 (anti-sludge) along with iron control & scale inhibitor. 150 bio balls and displaced with 40 bbls 2% KCL water
Total fluid used in treatment (bbls): 202 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): 43 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): 159 Total flowback volume recovered (bbls): 181
Produced water used in treatment (bbls): Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized:
Reason green techniques not utilized: PIPELINE
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 3/20/2015 Treatment End Date: 3/24/2015
Treatment summary: Re-acidized well only Acidized with 151 bbls of acetone & ethynol solvents and 150 bio balls- displaced with 20 bbls of 2% KCL
Total fluid used in treatment (bbls): 171 Max pressure during treatment (psi): 1680
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 151 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 187
Produced water used in treatment (bbls): 20 Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized:
Reason green techniques not utilized:
Formation Treatment Treatment Type:
Treatment Date: 9/27/2013 Treatment End Date: N/A
Treatment summary: No treatment completed on this formation.
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: 2.875 Tubing Setting Depth: 8172
Tubing Packer Depth: 7965 Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
    Initial Test Data:
Test Date: 2/22/2017 Test Method: Pump
Hours Tested: 24 Gas Type: WET
Gas Disposal: FLARED
Test Type Measure
    BBLS_H2O 215    
    BBLS_OIL 109    
    BTU_GAS 803    
    CALC_BBLS_H2O 215    
    CALC_BBLS_OIL 109    
    CALC_GOR 183    
    CALC_MCF_GAS 20    
    CASING_PRESS 36    
    GRAVITY_OIL 36    
    MCF_GAS 20    
    TUBING_PRESS 55    
    Perforation Data:
    Interval Bottom: 8065 Interval Top: 8018
    # of Holes: 153 Hole Size: 0.52