COGIS - WELL Information

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Surface Location Data for API # 05-121-11045                               Status: PR         1/31/2018
Well Name/No: SALEN #14-35 (click well name for production)
Operator: GRAND MESA OPERATING CO - 35080
Status Date: 1/31/2018 2:00:24 PM Federal or State Lease #:
FacilityID: 438155 LocationID: 438156
County: WASHINGTON #121 Location: SESW  35 5S54W 6 PM
Field: WILDCAT  - #99999 Elevation: 5,160 ft.
Planned Location       792 FSL  2214 FWL Lat/Long: 39.56829/-103.39836 Lat/Long Source: Field Measured
As Drilled Location      Footages Not Available Lat/Long: 39.56829/-103.39835 Lat/Long Source: Field Measured
Wellbore Data for Sidetrack #00                                                    Status: PR         1/31/2018
Spud Date: 9/8/2014 Spud Date is: ACTUAL
Wellbore Permit   DIRECTIONAL
Permit #: Expiration Date: 7/17/2016 4:27:01 PM
Prop Depth/Form: 9009 Surface Mineral Owner Same:
Mineral Owner: FEE Surface Owner: FEE
Unit: Unit Number:
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: LGKC , Formation: LANSING-KANSAS CITY , 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: WFCMP , Formation: WOLFCAMP , Order: , Unit Acreage: , Drill Unit:
Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 350, Weight: 24
Cement: Sacks: 122, Top: 0, Bottom: 350, Method Grade:
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 9000, Weight: 17
Cement: Sacks: 1109, Top: 6000, Bottom: 9000, Method Grade:
Wellbore Completed
Completion Date: 9/29/2014
Measured TD: 8310 Measured PB depth: 8213
True Vertical TD: 8299 True Vertical PB depth: 0
Top PZ Location:           Sec: 35 Twp: 5S 54W Footage: 611 FSL  2021 FWL Depth
Bottom Hole Location:   Sec: 35 Twp: 5S 54W Footages: 611 FSL  2021 FWL Depth
Log Types: Triple Combo, CBL
Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 360, Weight: 24
Cement: Sacks: 175, Top: 0, Bottom: 360, Method Grade: VISU
Casing: String Type: 1ST , Hole Size: 7.875, Size: 5.5, Top: 0, Depth: 8304, Weight: 17
Cement: Sacks: 1219, Top: 0, Bottom: 8304, Method Grade: CBL
Formation Log Top Log Bottom Cored DSTs
WOLFCAMP 6181
LANSING-KANSAS CITY 6875
MARMATON 7160
CHEROKEE 7377
ATOKA 7686
MORROW 7853
MISSISSIPPIAN 7996
SPERGEN 8032
Completed information for formation CHRK                                     Status: AB         1/31/2018
1st Production Date: 10/30/2014 Choke Size:
Status Date: 1/31/2018 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: CHEROKEE Status: AB
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 3/9/2015 Treatment End Date: 3/11/2015
Treatment summary: Cherokee previously reported producing. Performed a new stimulation -Acidized with 4,000 gallons of 20% gel acid and displaced with 179 bbls of KCL water
Total fluid used in treatment (bbls): 274 Max pressure during treatment (psi): 2860
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 95 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls):
Produced water used in treatment (bbls): 179 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: 10/10/2014 Treatment End Date: 10/14/2014
Treatment summary: Acidized with 500 gallons of 7.5% acetic acid with additives and 45 bbls of KCI water Acideized with 500 gallons of 15% HCI with additives and 49 bbls of 2% KCI water
Total fluid used in treatment (bbls): 118 Max pressure during treatment (psi): 1700
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): Total flowback volume recovered (bbls): 155
Produced water used in treatment (bbls): 94 Disposition method for flowback: DISPOSAL
Total proppant used (lbs): Green completions techniques utilized: False
Reason green techniques not utilized: PIPELINE
Tubing Size: Tubing Setting Depth:
Tubing Packer Depth: Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
    Initial Test Data:
Test Date: N/A Test Method:
Hours Tested: Gas Type:
Gas Disposal:
Test Type Measure
    BBLS_OIL 407    
    BTU_GAS 1481    
    CALC_BBLS_OIL 407    
    CALC_GOR 47    
    CALC_MCF_GAS 19    
    GRAVITY_OIL 39    
    MCF_GAS 19    
    TUBING_PRESS 72    
    Perforation Data:
    Interval Bottom: 7429 Interval Top: 7426
    # of Holes: 18 Hole Size: 0.48
Completed information for formation LGKC                                     Status: AB         1/31/2018
1st Production Date: 5/1/2017 Choke Size:
Status Date: 1/31/2018 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: LANSING-KANSAS CITY Status: AB
Formation Treatment Treatment Type:
Treatment Date: 5/16/2017 Treatment End Date: N/A
Treatment summary: Perforated only
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 LGKC .
    Perforation Data:
    Interval Bottom: 6888 Interval Top: 6882
    # of Holes: 36 Hole Size: 0.45
Completed information for formation LKCMCK                                     Status: CM         5/4/2017
1st Production Date: N/A Choke Size:
Status Date: 5/4/2017 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: LANSING-KANSAS CITY-MARMATON-CHEROKEE Status: CM
Formation Treatment Treatment Type:
Treatment Date: 5/4/2017 Treatment End Date: N/A
Treatment summary: Submitting testing info only...
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: 7494
Tubing Packer Depth: Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
    Initial Test Data:
Test Date: 5/4/2017 Test Method: Pumping
Hours Tested: 24 Gas Type: WET
Gas Disposal: FLARED
Test Type Measure
    BBLS_H2O 358    
    BTU_GAS 1251    
    CALC_BBLS_H2O 358    
    CALC_MCF_GAS 1    
    CASING_PRESS 13    
    MCF_GAS 1    
    TUBING_PRESS 60    
    Perforation Data:
    Interval Bottom: 7429 Interval Top: 6882
    # of Holes: 120 Hole Size:
Completed information for formation MRTN                                     Status: PR         1/31/2018
1st Production Date: 10/31/2014 Choke Size:
Status Date: 1/31/2018 Open Hole Completion: N
Commingled: N Production Method:
Formation Name: MARMATON Status: PR
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 1/12/2018 Treatment End Date: 1/31/2018
Treatment summary: Acidized with 500gals 7.5% MCA with 2% KCL flush
Total fluid used in treatment (bbls): 58 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): 12 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): 0 Total flowback volume recovered (bbls): 0
Produced water used in treatment (bbls): 46 Disposition method for flowback:
Total proppant used (lbs): Green completions techniques utilized: True
Reason green techniques not utilized:
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 3/12/2015 Treatment End Date: 3/20/2015
Treatment summary: Marmaton previously reported producing Performed new stimulation - Acidized with 4,000 gallons of 20% gelled HCL and displaced with 186 bbls of 2% KCl Added perfs 7160-7165 Acidized with 1250 gallons of 15% HCL and flushed with 83 bbls of 2% KCl
Total fluid used in treatment (bbls): 394 Max pressure during treatment (psi): 2240
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 125 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 367
Produced water used in treatment (bbls): 269 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: 10/16/2014 Treatment End Date: 10/14/2014
Treatment summary: Acidize with 22 bbls of 15% HCL with additives and 51 bbls of 2% KCI water
Total fluid used in treatment (bbls): 73 Max pressure during treatment (psi): 1000
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 22 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 113
Produced water used in treatment (bbls): 51 Disposition method for flowback: RECYCLE
Total proppant used (lbs): Green completions techniques utilized: True
Reason green techniques not utilized:
Tubing Size: 2.875 Tubing Setting Depth: 7384
Tubing Packer Depth: Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
    Initial Test Data:
Test Date: 1/31/2018 Test Method: Pumping
Hours Tested: 24 Gas Type:
Gas Disposal:
Test Type Measure
    BBLS_H2O 128    
    BBLS_OIL 20    
    BTU_GAS 1481    
    CALC_BBLS_H2O 128    
    CALC_BBLS_OIL 20    
    CALC_GOR 47    
    CALC_MCF_GAS 19    
    GRAVITY_OIL 39    
    MCF_GAS 19    
    TUBING_PRESS 75    
    Perforation Data:
    Interval Bottom: 7416 Interval Top: 7160
    # of Holes: 90 Hole Size: 0.41
Completed information for formation MT-CRK                                     Status: CM         3/21/2015
1st Production Date: N/A Choke Size:
Status Date: 3/21/2015 Open Hole Completion:
Commingled: Production Method:
Formation Name: MARMATON-CHEROKEE Status: CM
Tubing Size: 2.875 Tubing Setting Depth: 7490
Tubing Packer Depth: Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
    Initial Test Data:
Test Date: 3/21/2015 Test Method: Pumping
Hours Tested: 24 Gas Type: DRY
Gas Disposal: FLARED
Test Type Measure
    BBLS_H2O 258    
    BBLS_OIL 55    
    BTU_GAS 1618    
    CALC_BBLS_H2O 258    
    CALC_BBLS_OIL 55    
    CALC_GOR 382    
    CALC_MCF_GAS 21    
    CASING_PRESS 40    
    GRAVITY_OIL 39    
    MCF_GAS 21    
    TUBING_PRESS 40    
    Perforation Data:
    Interval Bottom: 7429 Interval Top: 7160
    # of Holes: 84 Hole Size:
Completed information for formation SPGN                                     Status: AB         10/10/2014
1st Production Date: N/A Choke Size:
Status Date: 10/10/2014 Open Hole Completion: N
Commingled: Production Method:
Formation Name: SPERGEN Status: AB
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 10/5/2014 Treatment End Date: 10/7/2014
Treatment summary: Simpson is also included in this formation but not a combo choice available. Perf'd 8,114' - 8,124' & 8,072' - 8,080' Acidized with 30 bbls of 7.5% HCL with inhibitors loading hole Switched to 63 bbls of 2% KCI water flush
Total fluid used in treatment (bbls): 93 Max pressure during treatment (psi): 2600
Total gas used in treatment (mcf): Fluid density (lbs/gal):
Type of gas: Number of staged intervals:
Total acid used in treatment (bbls): 30 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 163
Produced water used in treatment (bbls): 63 Disposition method for flowback: RECYCLE
Total proppant used (lbs): Green completions techniques utilized: True
Reason green techniques not utilized:
Tubing Size: 2.875 Tubing Setting Depth: 8067
Tubing Packer Depth: 8051 Tubing Multiple Packer:
Open Hole Top: Open Hole Bottom:
No Initial Test Data was found for formation SPGN .
    Perforation Data:
    Interval Bottom: 8124 Interval Top: 8072
    # of Holes: 108 Hole Size: 0.48