Capillary Pressure and Relative Permeability Behavior of the J1 and J2 Reservoirs at Bullwinkle

Capillary pressure and relative permeability behavior of unconsolidated sands are capillary pressure behavior of deepwater turbidites and described differences present in six facies. Honarpour et al. (1986) discussed several models for estimating relative permeability between end-point measurements and documented empirical exponents used by other workers to describe flow behavior associated with unconsolidated sands. Kikani and Smith (1996) stated that Corey's (1954) relative permeability model was used in reservoir simulation to mimic production behavior for the unconsolidated J-sands at Bullwinkle. In this chapter, capillary pressure and relative permeability behavior of unconsolidated sands of the J1 and J2 reservoirs at Bullwinkle are characterized and modeled. Mercury injection data, collected using whole-core samples, are used to evaluate in-situ fluid capillary behavior. End-point relative permeability and saturation data from whole core samples, constrain the movement of fluids at these end-points. Between these end-point values, Corey's (1954) two-phase model is used to simulate the relative permeability characteristics. Finally, core analysis, log-based petrophysical data (Comisky, 2002), and capillary data from another deepwater field are combined to define the hydraulic properties of six different Flow Units present in the J1 and J2 sands.