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0284213113020

Well Details

Well ID: 0284213113020
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Location: 02/13-31-028-21W4/0
Location Alias: 02/13-31-28-21 W4M
Location Alias 2: 02/13-31-028-21 W4/00
Country: Canada
Province: Alberta
Township: 028
Meridian: 4
Range: 21
Section: 31
County/Municipality: Kneehill County
Well Name: ECA ECOG WAYNE 13-31-28-21
Operator Name: Lynx Energy ULC
License Number: 0412570
License Date: 2009-09-24
License Status: Issued
Spud Date: 2010-02-07
Final Drill Date: 2010-02-14
Well Total Depth: 1487.00 m
Surface Hole Latitude: 51.441839
Surface Hole Longitude: -112.953358

For data sources see[1][2]

Well History

Date Event
2009-09-24 Obtained License
2010-02-08 Surface Casing Operation Performed
2010-02-14 Finished Drilling
2010-02-14 Well Log Performed
2010-02-14 Well Mode changed to Drilled and Cased
2010-02-15 Production Casing Operation Performed
2010-02-15 Rig Released
2010-03-03 Perforation Treatment Performed - Jet Perforation
2010-03-03 Well Log Performed
2010-03-24 Perforation Treatment Performed - Jet Perforation
2010-03-24 Well Log Performed
2010-04-05 Perforation Treatment Performed - Jet Perforation
2010-04-05 Well Log Performed
2010-07-29 Well Began Production
2010-07-29 Well Fluid changed to Gas
2010-07-29 Well Mode changed to Flowing
2013-01-18 Perforation Treatment Performed - Jet Perforation
2013-01-18 Well Log Performed
2013-02-03 Perforation Treatment Performed - Fractured
2013-02-19 Well Fluid changed to Gas
2013-02-19 Well Mode changed to Flowing
2014-09-27 Perforation Treatment Performed - Jet Perforation
2014-10-10 Perforation Treatment Performed - Fractured
2014-11-25 Well Fluid changed to Gas
2014-11-25 Well Mode changed to Suspended
2014-11-26 Well Fluid changed to Gas
2014-11-26 Well Mode changed to Flowing

For data sources see[3]


Perforation Treatments

Perforation Date Perforation Type Interval Top (m) Interval Base (m) Number of Shots
2010-03-03 Perforation 1449.00 1451.00 17
2014-10-10 Fracture 617.50 620.50 0
2014-10-10 Fracture 591.00 594.00 0
2014-10-10 Fracture 561.00 562.00 0
2014-10-10 Fracture 512.50 514.50 0
2010-03-24 Perforation 1400.00 1402.00 17
2010-04-05 Perforation 1241.00 1243.00 17
2013-01-18 Perforation 1239.00 1241.00 17
2013-02-03 Fracture 1239.00 1243.00 0
2014-09-27 Perforation 617.50 620.50 13
2014-09-27 Perforation 591.00 594.00 13
2014-09-27 Perforation 561.00 562.00 13
2014-09-27 Perforation 512.50 514.50 13

For data sources see[4]

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 2013-02-03 2013-02-03 0 0 N/A
2 2014-10-10 2014-10-10 0 31 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 Fresh Water 7732-18-5 100 46.6793 N/A
Nitrogen 7727-37-9 100 18.5714 N/A
Proppant Trican Crystalline silica. quartz 14808-60-7 100 33.4858 N/A
FCB-1 Trican Breaker Severely refined mineral oil Not Available 100 0.0815 N/A
CC-7 Trican Clay Control 1.6-hexanediamine. dihydrochloride 6055-52-3 100 0.1013 N/A
Water 7732-18-5 100 0.1013 N/A
FC-1S Trican Friction Reducer Isopropanol 67-63-0 100 0.7932 N/A
Non hazardous Not Available 100 0.7932 N/A
Quaternary ammonium compound 7948 100 0.7932 N/A
FC-2 Trican Surfactant Organic salt 7947 100 0.2873 N/A
Water 7732-18-5 100 0.2873 N/A
2 Water 7732-18-5 100 59.995 N/A
20/40 Peaskie Sand (Domestic) Calfrac Crystalline silica (Quartz) 14808-60-7 100 23.6718 N/A
DWP-903 Calfrac Breaker 1.2-Ethanediol 107-21-1 100 0.1373 N/A
Cellulase 9012-54-8 100 0.789 N/A
Non-Hazardous Ingredients Trade Secret 100 0.1236 N/A
DWP-107 Calfrac Buffer Non-Hazardous Ingredients Trade Secret 100 0.1098 N/A
Organic acid 8454 100 0.1098 N/A
Nitrogen Calfrac Energizing Fluid Nitrogen 7727-37-9 100 18.3684 N/A
DWP-621 Calfrac Friction Reducer Non-Hazardous Ingredients Trade Secret 100 0.1843 N/A
DWP-101 Calfrac Gelling Agent Guar gum 9000-30-0 100 0.428 N/A
Non-Hazardous Ingredients Trade Secret 100 0.4257 N/A
DWP-922 Calfrac Surfactant Alkyl Phenyl Ehoxylate 8459 100 0.2589 N/A
Inorganic acid 8459 100 0.2589 N/A
Methanol 67-56-1 100 0.2747 N/A
Non-Hazardous Ingredients Trade Secret 100 0.2747 N/A
Phosphate esthers of Alkyl Phenyl Ethoxylate 8459 100 0.2589 N/A

For data sources see[5]

Water Sources

Water Diversion Start Date Water Diversion End Date Water Source Type Total Water Volume (m3)
2013-02-03 2013-02-03 Municipal Water 60
2014-10-10 2014-10-10 Municipal Water 42
2014-10-10 2014-10-10 Municipal Water 16

For data sources see[6]

Production Data

Period Total Production Hours Gas Quantity (m3) Oil Quantity (m3) Water Quantity (m3)
2010 3744 0.0 0.0 0.0
2011 8756 0.0 0.0 0.0
2012 8760 0.0 0.0 0.0
2013 8143 0.0 0.0 0.0
2014 8681 0.0 0.0 0.0
2015 8619 0.0 0.0 0.0
2016 8402 0.0 0.0 0.0
2017 8688 0.0 0.0 0.0
2018 8751 0.0 0.0 0.0
2019 8759 0.0 0.0 0.0
2020 2183 0.0 0.0 0.0

For data sources see[7]

Occurences

Occurence Date Occurence Type Occurence Depth (m) Occurence Control Depth (m)
2013-02-12 No Incident Encountered 0.00 0.00
2014-11-05 No Incident Encountered 0.00 0.00

For data sources see[8]

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