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| Province: Manitoba | | Province: Manitoba | ||
|- | |- | ||
− | | Division: [[Division No. | + | | Division: [[Division No. 6,_Manitoba|Division No. 6]] |
|- | |- | ||
− | | Subdivision: [[Pipestone,_Division No. | + | | Subdivision: [[Pipestone,_Division No. 6,_Manitoba|Pipestone]] |
|- | |- | ||
| Operator Name: [[Tundra Oil & Gas Limited]] | | Operator Name: [[Tundra Oil & Gas Limited]] |
Well ID: 102.06-14-009-28W1 | Loading map...
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Well Name: Cromer Unit No. 2 and 3 COM | |
Country: Canada | |
Province: Manitoba | |
Division: Division No. 6 | |
Subdivision: Pipestone | |
Operator Name: Tundra Oil & Gas Limited | |
License Status: Capable Of Oil Production | |
Spud Date: 1995-08-11 | |
License Date: 1995-08-03 | |
Well Total Depth: 860 | |
Latitude: 49.74484922 | |
Longitude: -101.1805466 |
For data sources see[1]
Spud Date | Contractor | Rig Number |
---|---|---|
1995-08-11 | Viper Drilling Ltd. | D036 |
For data sources see[2]
Perforation Date | Perforation Type | Interval Top (m) | Interval Base (m) | Number of Shots | Shot Volume (m3) | Last Modified |
---|---|---|---|---|---|---|
1995-08-17 | JET PERFORATION | 778.5 | 781 | 13 | N/A | 1996-01-30 |
842.5 | 844 | 0 | N/A | 2002-04-17 |
For data sources see[3]
Start Date | Treatment Type | Treatment Fluid | Treatment Amount | Additive Type | Agent Type | Agent Amount |
---|---|---|---|---|---|---|
1995-08-18 | ACID JOB | 15% MDA | 500 | N/A | ||
1995-08-18 | ACID JOB | 15% HCL | 500 | N/A | ||
1997-08-19 | SCALE INHIB SQUEEZE | NALCO 4988 | 208 | N/A | ||
1998-11-26 | SCALE INHIB SQUEEZE | NALCO 4988 | 208 | N/A | ||
1999-12-13 | SCALE INHIB SQUEEZE | NALCO 4988 | 208 | N/A | ||
2000-10-19 | SCALE INHIB SQUEEZE | NALCO | 208 | N/A | ||
2004-11-05 | SCALE INHIB SQUEEZE | 206W | 208 | N/A | ||
2005-12-20 | SCALE INHIB SQUEEZE | 206W Scale Inhibit | 208 | N/A | ||
2007-06-21 | SCALE INHIB SQUEEZE | 206W Scale Inhibit | 208 | N/A |
For data sources see[4]
For data sources see[5]
Period | Operator | H2O Quantity (m3) | H20 Waste Production Days | Gas Quantity (m3) | Gas Waste Production Days | CO2 Quantity (m3) | SSW Quantity (m3) |
---|---|---|---|---|---|---|---|
1995 | Tundra Oil & Gas Partnership | 106.80 | 124 | 0.00 | 0 | 0.00 | 0.00 |
1996 | Tundra Oil & Gas Partnership | 348.10 | 347 | 0.00 | 0 | 0.00 | 0.00 |
1997 | Tundra Oil & Gas Partnership | 280.90 | 357 | 0.00 | 0 | 0.00 | 0.00 |
1998 | Tundra Oil & Gas Partnership | 298.20 | 359 | 0.00 | 0 | 0.00 | 0.00 |
1999 | Tundra Oil & Gas Partnership | 347.20 | 338 | 0.00 | 0 | 0.00 | 0.00 |
2000 | Tundra Oil & Gas Partnership | 563.00 | 350 | 0.00 | 0 | 0.00 | 0.00 |
2001 | Tundra Oil & Gas Partnership | 549.10 | 365 | 0.00 | 0 | 0.00 | 0.00 |
2002 | Tundra Oil & Gas Partnership | 469.70 | 364 | 0.00 | 0 | 0.00 | 0.00 |
2003 | Tundra Oil & Gas Partnership | 553.10 | 365 | 0.00 | 0 | 0.00 | 0.00 |
2004 | Tundra Oil & Gas Partnership | 505.20 | 363 | 0.00 | 0 | 0.00 | 0.00 |
2005 | Tundra Oil & Gas Partnership | 536.00 | 358 | 0.00 | 0 | 0.00 | 0.00 |
2006 | Tundra Oil & Gas Partnership | 711.70 | 360 | 0.00 | 0 | 0.00 | 0.00 |
2007 | Tundra Oil & Gas Partnership | 845.70 | 363 | 0.00 | 0 | 0.00 | 0.00 |
2008 | Tundra Oil & Gas Partnership | 700.70 | 357 | 0.00 | 0 | 0.00 | 0.00 |
2009 | Tundra Oil & Gas Partnership | 590.00 | 359 | 0.00 | 0 | 0.00 | 0.00 |
2014 | Tundra Oil & Gas Limited | 1,084.00 | 332 | 0.00 | 0 | 0.00 | 0.00 |
2015 | Tundra Oil & Gas Limited | 2,009.00 | 363 | 0.00 | 0 | 0.00 | 0.00 |
2016 | Tundra Oil & Gas Limited | 1,728.00 | 342 | 0.00 | 0 | 0.00 | 0.00 |
2017 | Tundra Oil & Gas Limited | 9,658.90 | 301 | 0.00 | 0 | 0.00 | 0.00 |
2018 | Tundra Oil & Gas Limited | 8,567.90 | 329 | 0.00 | 0 | 0.00 | 0.00 |
2019 | Tundra Oil & Gas Limited | 2,320.20 | 89 | 0.00 | 0 | 0.00 | 0.00 |
For data sources see[5]