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0826031902000

Well Details

Well ID: 0826031902000
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Location: 00/02-19-082-03W6/0
Location Alias: 00/02-19-82-03 W6M
Location Alias 2: 00/02-19-082-03 W6/00
Country: Canada
Province: Alberta
Township: 082
Meridian: 6
Range: 03
Section: 19
County/Municipality: Municipal District of Fairview No. 136
Well Name: TUSKAB GAGE 2-19-82-3
Operator Name: Mojek Resources Inc.
License Number: 0317758
License Date: 2004-10-28
License Status: Issued
Spud Date: 2004-11-05
Final Drill Date: 2004-11-11
Well Total Depth: 1424.00 m
Surface Hole Latitude: 56.118671
Surface Hole Longitude: -118.456436

For data sources see[1][2]

Well History

Date Event
2004-10-28 Obtained License
2004-11-06 Surface Casing Operation Performed
2004-11-11 Finished Drilling
2004-11-11 Well Mode changed to Drilled and Cased
2004-11-12 Well Log Performed
2004-11-13 Production Casing Operation Performed
2004-11-14 Rig Released
2005-01-04 Perforation Treatment Performed - Jet Perforation
2005-01-04 Well Log Performed
2005-01-06 Perforation Treatment Performed - Fractured
2005-01-20 Well Began Production
2005-01-20 Well Fluid changed to Crude Oil
2005-01-20 Well Mode changed to Pumping
2008-05-28 Perforation Treatment Performed - Fractured
2009-07-15 Well Log Performed
2009-08-22 Well Began Injection
2009-08-22 Well Fluid changed to Water
2009-08-22 Well Type changed to Injection
2014-03-22 Perforation Treatment Performed - Fractured

For data sources see[3]


Perforation Treatments

Perforation Date Perforation Type Interval Top (m) Interval Base (m) Number of Shots
2005-01-04 Perforation 1075.00 1078.00 20
2005-01-04 Perforation 1072.50 1074.50 20
2005-01-06 Fracture 1072.50 1078.00 0
2008-05-28 Fracture 1072.50 1078.00 0
2014-03-22 Fracture 1072.50 1078.00 0

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 2014-03-22 2014-03-22 0 56 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 Not Available 100 75.8081 N/A
FRAC SAND. 20/40 WHITE (OTTAWA TYPE) Baker Hughes Crystalline Silica (Quartz) 14808-60-7 100 23.1371 N/A
Breaker N Baker Hughes Breaker Sodium persulphate 7775-27-1 100 0.034 N/A
ClaySurf-9L Baker Hughes Clay Control Cocamido propyl betaine 61789-40-0 100 0.2583 N/A
Complex polyamine salt 138879-94-4 100 0.2583 N/A
Non-hazardous Not Available 100 0.2583 N/A
CXB-2 Baker Hughes Crosslinker Methanol 67-56-1 100 0.2761 N/A
Non-hazardous Not Available 100 0.2761 N/A
Sodium borate 7775-19-1 100 0.2761 N/A
Sodium hydroxide 1310-73-2 100 0.2761 N/A
WG-15SLR Baker Hughes Gelling Agent Guar gum 9000-30-0 100 0.4861 N/A
Low toxicity base oils - Non-WHMIS Controlled Not Available 100 0.4861 N/A

For data sources see[5]

Water Sources

Water Diversion Start Date Water Diversion End Date Water Source Type Total Water Volume (m3)
2014-03-21 2014-03-22 Municipal Water 55

For data sources see[6]

Production Data

Period Total Production Hours Gas Quantity (m3) Oil Quantity (m3) Water Quantity (m3)
2005 7462 0.0 0.0 0.0
2006 8492 0.0 0.0 0.0
2007 7982 0.0 0.0 0.0
2008 8160 0.0 0.0 0.0
2009 4520 0.0 0.0 0.0
2010 0 0.0 0.0 0.0
2011 0 0.0 0.0 0.0
2012 0 0.0 0.0 0.0
2013 0 0.0 0.0 0.0
2014 0 0.0 0.0 0.0
2015 0 0.0 0.0 0.0
2016 0 0.0 0.0 0.0
2017 0 0.0 0.0 0.0
2018 0 0.0 0.0 0.0
2019 0 0.0 0.0 0.0
2020 0 0.0 0.0 0.0

For data sources see[7]

Occurences

Occurence Date Occurence Type Occurence Depth (m) Occurence Control Depth (m)
2014-03-29 No Incident Encountered 0.00 0.00

For data sources see[8]

References