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0164131906020

Well Details

Well ID: 0164131906020
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Location: 02/06-19-016-13W4/0
Location Alias: 02/06-19-16-13 W4M
Location Alias 2: 02/06-19-016-13 W4/00
Country: Canada
Province: Alberta
Township: 016
Meridian: 4
Range: 13
Section: 19
County/Municipality: County of Newell
Well Name: TXNE 6C2 BANTRY 6-19-16-13
Operator Name: Torxen Energy Ltd.
License Number: 0243585
License Date: 2000-10-25
License Status: Issued
Spud Date: 2000-11-01
Final Drill Date: 2000-11-05
Well Total Depth: 1163.00 m
Surface Hole Latitude: 50.361441
Surface Hole Longitude: -111.790696

For data sources see[1][2]

Well History

Date Event
2000-10-25 Obtained License
2000-11-02 Direction Drilling Operation Performed - Deviate
2000-11-05 Finished Drilling
2000-11-05 Well Log Performed
2000-11-06 Production Casing Operation Performed
2000-11-06 Rig Released
2000-11-06 Well Log Performed
2000-11-06 Well Mode changed to Drilled and Cased
2001-01-24 Well Log Performed
2001-02-15 Perforation Treatment Performed - Jet Perforation
2001-05-08 Perforation Treatment Performed - Fractured
2003-06-01 Well Began Production
2003-06-01 Well Fluid changed to Gas
2003-06-01 Well Mode changed to Flowing
2018-09-27 Perforation Treatment Performed - Jet Perforation
2018-09-27 Well Log Performed
2018-11-17 Perforation Treatment Performed - Fractured

For data sources see[3]

Directional Drilling

Start Date Depth (m) Reason
2000-11-02 0.00 Deviate (5 - 79 degrees)

For data sources see[4]

Perforation Treatments

Perforation Date Perforation Type Interval Top (m) Interval Base (m) Number of Shots
2001-02-15 Perforation 718.00 721.00 7
2001-05-08 Fracture 718.00 721.00 0
2018-09-27 Perforation 1116.00 1120.00 16
2018-11-17 Fracture 1116.00 1120.00 0

For data sources see[5]

Fracking Activities

Fracking Jobs

Job Number Job Start Date Job End Date True Vertical Depth (ft) Total Water Volume (gal) Total Non-Water Volume (gal)
1 2018-11-17 2018-11-17 1,051 0 N/A

Fluid Composition Data

Job Number Trade Name Supplier Purpose Ingredient Name CAS Number Additive Percentage by Mass Job Percentage by Mass Mass Used (lb)
1 Water (Including Mix Water Supplied by Client)* 7732-18-5 100 79.9453 N/A
YF120Flex Schlumberger Quartz. Crystalline silica 14808-60-7 100 19.3889 N/A
YF120Flex Schlumberger Energizing Fluid 1.2.4 Trimethylbenzene (impurity) 95-63-6 100 0.0002 N/A
2-hydroxy-N.N.N-trimethylethanaminium chloride 67-48-1 100 0.1345 N/A
2-Propen-1-aminium. N.N-dimethyl-N-2-propen-1-yl-. chloride 26062-79-3 100 0.0021 N/A
Acetic acid 64-19-7 100 0.0008 N/A
Acetic acid. potassium salt 127-08-2 100 0.0001 N/A
Alcohol. C11-14. ethoxylated 78330-21-9 100 0.0092 N/A
Alcohols. C7-9-iso-. C8-rich. ethoxylated 78330-19-5 100 0.0142 N/A
Alcohols. C9-11-iso-. C10-rich. ethoxylated 78330-20-8 100 0.0132 N/A
Amines. dicoco alkylmethyl 61788-62-3 100 0 N/A
Benzenemethanaminium. N.N-dimethyl-N tetradecyl-. chloride 139-08-2 100 0.001 N/A
Benzenemethanaminium. N-hexadecylN.N dimethyl-.chloride 122-18-9 100 0.0002 N/A
benzododecinium chloride 139-07-1 100 0.0031 N/A
Diammonium peroxidisulphate 7727-54-0 100 0.0163 N/A
Dicoco dimethyl quaternary ammonium chloride 61789-77-3 100 0.0004 N/A
Ethoxylated propoxylated 4-nonylphenol-formaldehyde resin 30846-35-6 100 0.0153 N/A
Glycerol 56-81-5 100 0.0227 N/A
Guar gum 9000-30-0 100 0.1789 N/A
Methanol 67-56-1 100 0.1201 N/A
N-Coco. 1.3-diaminopropane di-acetate 61791-64-8 100 0.0019 N/A
Naphthalene (Impurity) 91-20-3 100 0.0003 N/A
Non-crystalline silica (impurity) 7631-86-9 100 0.0004 N/A
Oxirane. Methyl-. polymer with Oxirane 11/6/9003 100 0.0207 N/A
Poly(oxy-1.2-ethanediyl).a-hydro-w-hydroxy-
Ethane-1.2-diol. 		25322-68-3 100 0.0045 N/A
Polyethylene glycol monohexyl ether 31726-34-8 100 0.0048 N/A
Potassium borate 1332-77-0 100 0.0696 N/A
Potassium hydroxide 1310-58-3 100 0.0257 N/A
Potassium oleate 143-18-0 100 0.0002 N/A
Propan-2-ol 67-63-0 100 0.0009 N/A
Solvent naphtha (petroleum). heavy arom. 64742-94-5 100 0.0029 N/A

For data sources see[6]

Water Sources

Water Diversion Start Date Water Diversion End Date Water Source Type Total Water Volume (m3)
2018-09-19 2018-09-19 Central Water Distribution Facility 40

For data sources see[7]

Production Data

Period Total Production Hours Gas Quantity (m3) Oil Quantity (m3) Water Quantity (m3)
2003 5099 0.0 0.0 0.0
2004 8782 0.0 0.0 0.0
2005 8745 0.0 0.0 0.0
2006 8759 0.0 0.0 0.0
2007 8759 0.0 0.0 0.0
2008 8759 0.0 0.0 0.0
2009 8759 0.0 0.0 0.0
2010 8743 0.0 0.0 0.0
2011 8759 0.0 0.0 0.0
2012 8783 0.0 0.0 0.0
2013 8759 0.0 0.0 0.0
2014 8759 0.0 0.0 0.0
2015 8754 0.0 0.0 0.0
2016 8759 0.0 0.0 0.0
2017 8591 0.0 0.0 0.0
2018 8744 0.0 0.0 0.0
2019 8735 0.0 0.0 0.0
2020 2183 0.0 0.0 0.0

For data sources see[8]

Occurences

Occurence Date Occurence Type Occurence Depth (m) Occurence Control Depth (m)
2018-11-22 No Incident Encountered 0.00 0.00
2018-09-27 No Incident Encountered 0.00 0.00

For data sources see[9]

References

  1. ↑ "General Well Data File - Licensing Data". Alberta Energy Regulator. 2020-04-22. Retrieved 2020-05-07. 
  2. ↑ "General Well Data File - Drilling Data". Alberta Energy Regulator. 2020-04-22. Retrieved 2020-05-07. 
  3. ↑ "General Well Data File". Alberta Energy Regulator. 2020-04-22. Retrieved 2020-04-29. 
  4. ↑ "General Well Data File - Tour-Direction Drilling Data". Alberta Energy Regulator. 2020-04-22. Retrieved 2020-05-07. 
  5. ↑ "General Well Data File - Tour-Perforation/Treatment Data". Alberta Energy Regulator. 2020-04-22. Retrieved 2020-05-07. 
  6. ↑ "Hydraulic Fracturing Water Use Data (Annual)". Alberta Energy Regulator. 2020-05-05. Retrieved 2020-05-10. 
  7. ↑ "Hydraulic Fracturing Water Source Data (Annual)". Alberta Energy Regulator. 2018-12-31. Retrieved 2019-05-10. 
  8. ↑ "Well Production Data - All Alberta". Alberta Energy Regulator. 2020-04-25. Retrieved 2020-05-07. 
  9. ↑ "General Well Data File - Tour-Occurence Data". Alberta Energy Regulator. 2020-04-22. Retrieved 2020-05-07. 
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