white rose oilfield development application - Husky Energy

4.2.2.6 Deferred DevelopmentsThree deferred developments will be considered as the results of South Avalon Pool developmentdrilling, production and injection are evaluated. They are:• North Avalon oil;• West Avalon oil; and• White Rose gas resources.It is expected that the North Avalon reservoir will be of generally poorer quality than the South Avalonpool and, as a result, recovery factors for this area will also be lower. Preliminary assessments indicatethat recovery factors could be in the order of 18 to 30 percent, with oil reserves ranging from 5.4 to8.3 m 3 . At least two to three production wells would be required to recover the oil in this area ifreasonable production rates and recoveries can be achieved.The West Avalon pool is also expected to have a poorer quality reservoir than the South Avalon pool,with an expected recovery factor ranging from 18 to 31 percent. The southeastern end of the WestAvalon pool has the best potential for economic oil production, as it is closer to the South Avalon corearea and most likely to have better reservoir quality, although faulting may be more severe. This areahas yet to be drilled to determine reservoir quality and fluid contacts. If current estimates are confirmed,then recoverable oil reserves in this portion of the pool would be between 7.0 and 11.1 million m 3 .In order for oil recoveries to be maximized in the White Rose oilfield, reservoir pressures must bemaintained and smearing of the oil leg into the gas cap should be avoided. As a result, depletion of thegas resource should not commence until exploitation of the oil resource is well advanced.Drilling and depletion of the oil legs, along with gas conservation monitoring, will provide valuableinformation as to the reservoir quality and compartmentalization. During the oil production phase, allgas, other than that used for fuel gas, will be conserved in the North Avalon pool gas cap.Development of the above gas for production would likely require approximately 10 additional wells,with associated glory holes and subsea systems. From a facilities perspective, it may be possible toupgrade the FPSO to handle the additional gas volumes, but this would likely require it to be broughtinto harbour for modification. Earliest timing for beginning gas development for sales is at least fiveyears after First Oil, assuming that a regional gas gathering and export system is put in place. Futureconditions for White Rose gas development are outlined in Section 1.2.3 of this summary document.White Rose DA Project Summary • January 2001 Page 53