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Fault seal analysis: Methodology and case studies

Conference ·
OSTI ID:425399
; ;  [1]
  1. Earth Sciences Limited, Lincolnshire (United Kingdom)
Fault seal can arise from reservoir/non-reservoir juxtaposition or by development of fault rock of high entry-pressure. The methodology for evaluating these possibilities uses detailed seismic mapping and well analysis. A {open_quote}first-order{close_quote} seal analysis involves identifying reservoir juxtaposition areas over the fault surface, using the mapped horizons and a refined reservoir stratigraphy defined by isochores at the fault surface. The {open_quote}second-order{close_quote} phase of the analysis assesses whether the sand-sand contacts are likely to support a pressure difference. We define two lithology-dependent attributes {open_quote}Gouge Ratio{close_quote} and {open_quote}Smear Factor{close_quote}. Gouge Ratio is an estimate of the proportion of fine-grained material entrained into the fault gouge from the wall rocks. Smear Factor methods estimate the profile thickness of a ductile shale drawn along the fault zone during faulting. Both of these parameters vary over the fault surface implying that faults cannot simply be designated {open_quote}sealing{close_quote} or {open_quote}non-sealing{close_quote}. An important step in using these parameters is to calibrate them in areas where across-fault pressure differences are explicitly known from wells on both sides of a fault. Our calibration for a number of datasets shows remarkably consistent results despite their diverse settings (e.g. Brent Province, Niger Delta, Columbus Basin). For example, a Shale Gouge Ratio of c. 20% (volume of shale in the slipped interval) is a typical threshold between minimal across-fault pressure difference and significant seal.
OSTI ID:
425399
Report Number(s):
CONF-960527--
Country of Publication:
United States
Language:
English

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