809-2 Challenges When Predicting Reservoir Quality in the Sub-Salt K2 Field, Green Canyon, Gulf of Mexico

See more from this Division: Gulf Coast Association of Geological Societies
See more from this Session: Sedimentology and Stratigraphy

Tuesday, 7 October 2008: 3:30 PM
George R. Brown Convention Center, 310CF

Todd J. Greene1, B.E. O'Neill2, R.E. Drumheller2, T. Butaud2 and A. Rodriguez2, (1)Geological & Environmental Sciences, CSU Chico, Chico, CA
(2)Anadarko Petroleum Corporation, The Woodlands, TX
Accurately modeling reservoir quality in Miocene deep-water reservoirs in the K2 Field, Green Canyon, Gulf of Mexico, presents many challenges for planning primary and secondary oil recovery. An overlying thick salt canopy prevents adequate seismic imaging at reservoir levels, structural complexities make correlating sand packages difficult, and well-spacing is sufficiently large that correlating intra-reservoir surfaces is problematic. Borrowing from successful methodologies developed for seismically better-imaged deep-water reservoirs in the eastern Gulf of Mexico, we utilize well log, core, and pressure data to calibrate petrophysical properties to individual depositional facies towards the ultimate purpose of predicting reservoir quality in areas which lack core and/or well control.

First, based on detailed sedimentologic descriptions for the cored intervals, grain size analyses, whole core x-ray scans, well log patterns, and correlations, we identified four main reservoir facies within two principal Miocene intervals: channel-bypass, thick-bedded amalgamated sheets (axial and marginal), and thin-bedded layered sheets. Second, to distribute facies within time-correlative packages, we use depositional models based on Gulf of Mexico shallow-seismic analogs of distributary channel complexes. While the lower Miocene interval characteristics are more akin to confined, proximal portions of a frontal splay, the middle Miocene interval contains characteristics of the more unconfined medial portions.

Thirdly, using whole core data, we examine a wide range of petrophysical attributes to recognize unique combinations of petrophysical properties for each key reservoir facies. This provides valuable insight for choosing log-based curves used for identifying facies within uncored wells.

To date, pressure transient analysis of production data from the two main intervals are consistent with our facies interpretations. The more sheet-like interval shows few barriers while the more channelized interval suggests a higher degree of complexity.

The resulting improved facies classification scheme provides a more useful basis for routine reservoir modeling and field management.

See more from this Division: Gulf Coast Association of Geological Societies
See more from this Session: Sedimentology and Stratigraphy