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Displacement pressure estimation from sedimentary facies and well logs (view source)
Revision as of 19:56, 28 July 2014
, 19:56, 28 July 2014→Example: Ardjuna basin, Indonesia
Each of these facies has a distinct range of displacement pressures. [[:file:evaluating-top-and-fault-seal_fig10-49.png|Figure 1]] shows the range of seal capacities for the different facies. Shelfal carbonates and delta-front shales are excellent seals, with displacement pressures > 1000 psia (air-mercury) and capable of trapping approximately 1000–10,000 ft of oil. Delta-plain shales are relatively poor seals, with displacement pressures of 80–90 psia (air-mercury<sup>o</sup> and capable of trapping only 90–100 ft of oil.
Each of these facies has a distinct range of displacement pressures. [[:file:evaluating-top-and-fault-seal_fig10-49.png|Figure 1]] shows the range of seal capacities for the different facies. Shelfal carbonates and delta-front shales are excellent seals, with displacement pressures > 1000 psia (air-mercury) and capable of trapping approximately 1000–10,000 ft of oil. Delta-plain shales are relatively poor seals, with displacement pressures of 80–90 psia (air-mercury<sup>o</sup> and capable of trapping only 90–100 ft of oil.
These values place an upper limit on the amount of hydrocarbon that can be trapped. Other factors, however, limit the sealing potential of these seals. Seal risk was defined by combining P<sub>d</sub> with qualitative assessments of ductility, fracturing, thickness, and lateral continuity.<ref name=ch10r87 />
These values place an upper limit on the amount of hydrocarbon that can be trapped. Other factors, however, limit the sealing potential of these seals. Seal risk was defined by combining P<sub>d</sub> with qualitative assessments of [[ductility]], fracturing, thickness, and lateral continuity.<ref name=ch10r87 />
==Example: onshore African basin==
==Example: onshore African basin==