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The AAPG/Datapages Combined Publications Database
AAPG Special Volumes
Abstract
By
Originally presented at the 1998 Hedberg (AAPG) Research Conference at Galveston, TX
Book/CD-ROM Title:
Edited by
reservoir
simulators has the potential to illuminate the processes by which hydrocarbons are
emplaced during secondary migration. The modeling of secondary migration in faults provide
insight into 1) possible bypassing
mechanisms
(i.e. why traps are underfilled) and 2) how
column heights and composition may change through time. Two- and three-phase analytical
and numerical models describing the relationship between secondary migration through fault
zones and the concurrent charging of reservoirs in juxtaposition with these faults are
presented. In these models the fault zone is assumed to behave as a porous medium with the
flow governed by Darcys Law.
The problem is illustrated in Figure 1. Oil and gas enter the bottom of the fault zone. At sufficiently high pressures all the gas would be in solution. The hydrocarbons migrate up through the fault zone due to buoyancy and when the pressure drops below the bubble point, a free gas phase is formed. As the hydrocarbons flow by sands juxtaposed against the fault zone the capillary pressure in the fault zone drives some of the oil and gas into the sands. The system modeled is isothermal, the geometry is fixed, and the porosity and permeability are constant.
Key results of the model are:
· Column height is a dynamic function of charge rate and not a static function of capillary-entry pressure as is often assumed,
· A fault can serve both as a migration pathway and as a seal,
· Hydrocarbons migrating along faults can backfill adjacent sands,
·
Under-filled structures may result where reservoir
sands pinch out away from the
fault and hydrocarbons cannot displace the perched water that develops down
dip,
· In three-phase (oil, water and gas) cases hydrocarbon column heights significantly larger than the steady state values can form as the sand charges and
· Given similar petrophysical fault properties with depth and isotropic permeability, deeper sands will fill sequentially before shallower sands.
The hydrocarbon column heights that result from this
process are controlled by the petrophysical properties of the fault zone, the flux of
fluids into the fault zone, and the geometry of the reservoir
. The degree of heterogeneity
and anisotropy of the fault zone can have a significant effect on whether given
reservoir
sands are charged or bypassed. At steady state, the capillary pressures in the fault zone
and the adjacent
reservoir
must be equal; the capillary pressures (which are a function of
the hydrocarbon saturations in the fault) at this interface are the most important
parameter in the determination the hydrocarbon column heights in an adjacent sand.
In summary, this work examines a physical model that
provides insight into the secondary migration of hydrocarbons through faults and the
subsequent charging of adjacent reservoir
sands. The key parameters that control
hydrocarbon column heights in the model are identified and observations are made about the
charging of these
reservoir
sands.
Figure 1. 3-Phase migration
schematic. Hydrocarbons enter the bottom of the fault zone and flow upwards due to
buoyancy. As they flow up the fault zone some of the hydrocarbons will be driven into the
sand by capillary forces. Po = oil phase pressure and Pb = bubble point pressure. At
pressures below the bubble point pressure, a discrete gas phase is present.