COGIS - WELL Information

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Surface Location Data for API # 05-123-10615                               Status: PR         4/1/2020
Well Name/No: STAMP #31-2C (click well name for production)
Operator: TOP OPERATING COMPANY - 39560
Status Date: 4/1/2020 Federal or State Lease #:
FacilityID: 242824 LocationID: 319067
County: WELD #123 Location: NENW  31 3N68W 6 PM
Field: WATTENBERG  - #90750 Elevation: 4,960 ft.
Planned Location       990 FNL  1980 FWL Lat/Long: 40.186365/-105.048078 Lat/Long Calculated From Footages
As Drilled Location      Footages Not Available Lat/Long: 40.18645/-105.04809 Lat/Long Source: Field Measured
Wellbore Data for Sidetrack #00                                                    Status: PR         4/1/2020
Spud Date: 5/17/1982 Spud Date is: ACTUAL
Wellbore Permit  
Permit #: 20090935 Expiration Date: 3/17/2010
Prop Depth/Form: 7400 Surface Mineral Owner Same: Y
Mineral Owner: FEE Surface Owner: FEE
Unit: Unit Number:
Formation and Spacing: Code: JSND , Formation: J SAND , Order: 232-23 , Unit Acreage: 320, Drill Unit: W/2
Formation and Spacing: Code: NB-CD , Formation: NIOBRARA-CODELL , Order: 407-87 , Unit Acreage: 80, Drill Unit: N/2NW/4
Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: , Depth: 239, Weight: 24
Cement: Sacks: 210, Top: 0, Bottom: 239, Determination Method:
Casing: String Type: 1ST , Hole Size: 7.875, Size: 4.5, Top: , Depth: 7433, Weight: 11.6
Cement: Sacks: 220, Top: 6795, Bottom: 7433, Determination Method:
Wellbore Completed
Completion Date: N/A
Measured TD: 7433 Measured PB depth: 7388
True Vertical TD: True Vertical PB depth:
Log Types: INDUCTION- SFL; DENSILOG; PROLOG
Log Types: CBL IES DENSITY
Casing: String Type: SURF , Hole Size: 12.25, Size: 8.625, Top: 0, Depth: 239, Weight: 24#
Cement: Sacks: 210, Top: 0, Bottom: 239, Determination Method: VISU
Casing: String Type: 1ST , Hole Size: 7.875, Size: 4.5, Top: 0, Depth: 7821, Weight: 11.6#
Cement: Sacks: 200, Top: 6790, Bottom: 7821, Determination Method: CBL
Additional Cement: String Type: S.C. 1.1 , Top: 6390, Depth: 6766, Bottom: 6770, Sacks: 160, Method: SQUEEZE
Formation Log Top Log Bottom Cored DSTs
NIOBRARA 6452 6781
FORT HAYS 6781 6801
CODELL 6801 6822
CARLILE 6824 N N
GREENHORN 6874 N N
BENTONITE 7065 N N
J SAND 7260 7360
SKULL CREEK 7358 N N
Completed information for formation CODL                                     Status: CM         4/30/2020
1st Production Date: 8/1/2010 Choke Size:
Status Date: 4/30/2020 Open Hole Completion:
Commingled: Y Production Method:
Formation Name: CODELL Status: CM
Formation Treatment Treatment Type:
Treatment Date: 6/22/2020 Treatment End Date: N/A
Treatment summary: The packer isolating the Codell formation was removed.
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:
Formation Treatment Treatment Type:
Treatment Date: 10/22/2019 Treatment End Date: N/A
Treatment summary: Packer set at 7243', below Codell perforations, isolating Codell perforations from production
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:
Formation Treatment
Treatment Date: 7/1/2009    
Treatment summary: FRAC'D CODL DOWN 4 1/2'' CSG @ 50 BPM 60,000 GAL WATER 0.5 & 1.0 PPG 20/40 SAND 91,700 GALS DYNAFLOW-2WR W/ 290,000 OF 20/40 SND & 10,000# SB EXCELL 20/40 RESIN COATED SAND.
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_H2O 7    
    BBLS_OIL 105    
    BTU_GAS 1000    
    CALC_BBLS_H2O 7    
    CALC_BBLS_OIL 105    
    CALC_GOR 1343    
    CALC_MCF_GAS 141    
    CASING_PRESS 1400    
    GRAVITY_OIL 46    
    MCF_GAS 141    
    TUBING_PRESS 1400    
    Perforation Data:
    Interval Bottom: 6822 Interval Top: 6806
    # of Holes: 64 Hole Size: 0.3
Completed information for formation JSND                                     Status: CM         4/30/2020
1st Production Date: 1/17/1983 Choke Size:
Status Date: 4/30/2020 Open Hole Completion:
Commingled: Production Method:
Formation Name: J SAND Status: CM
Formation Treatment Treatment Type:
Treatment Date: 6/22/2020 Treatment End Date: N/A
Treatment summary: Formation currently producing
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:
Formation Treatment Treatment Type: ACID JOB
Treatment Date: 7/29/2019 Treatment End Date: 9/4/2019
Treatment summary: Received 105.62bbls of 33% concentration Hydorcholoric acid, diluted to 200bbls at 20% 40bbls of full hydrochloric acid in pure strength, added 22 gallons of corrosion inhibitor and 1,000lbs of citirc acid in dry pellt form. Pumped 100 bbl of stimulation fluid into JSand perfs at 2.5bbls/minute, max psi 1500. Flushed tubing clean, shut in for night. Next morning pumped 100blls. of remaining stimulation fluid in the the JSand perfs at 2.5bbls/min.
Total fluid used in treatment (bbls): 200 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): 40 Min frac gradient (psi/ft):
Recycled water used in treatment (bbls): Total flowback volume recovered (bbls): 202
Produced water used in treatment (bbls): 160 Disposition method for flowback: DISPOSAL
Total proppant used (lbs): 0 Green completions techniques utilized:
Reason green techniques not utilized:
Formation Treatment
Treatment Date: 1/12/1983    
Treatment summary: 73 BBLS OF 2%KCL WATER, 12 BBLS 15% SPEARHEAD ACID, 24 BBLS OF 2% JKCLWATER, 25 BBLS TO FLUSHDOWN
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_H2O 1    
    BBLS_OIL 41    
    CALC_BBLS_H2O 2    
    CALC_BBLS_OIL 68    
    CALC_GOR 530000    
    CALC_MCF_GAS 265    
    CASING_PRESS 270    
    MCF_GAS 265    
    TUBING_PRESS 200    
    Perforation Data:
    Interval Bottom: 7286 Interval Top: 7260
    # of Holes: 32 Hole Size: 0.3