Improving Recovery from Mature Oil Fields Producing from Upper Jurassic Carbonate Reservoirs, Northeastern Gulf of Mexico, U.S.A

Ernest A. Mancini¹, Thomas A. Blasingame², Rosalind Archer³, Brian J. Panetta¹, Juan Carlos Llinás¹, and Bennett L. Bearden⁴. (1) Center for Sedimentary Basin Studies and Department of Geological Sciences, University of Alabama, Box 870338, Tuscaloosa, AL 35487, phone: 205/348-4319, fax: 205/348-0818, emancini@wgs.geo.ua.edu, (2) Department of Petroleum Engineering, Texas A&M University, College Station, TX 77843, (3) Department of Engineering Science, University of Auckland, Private Bag 92019, Auckland, 1020, New Zealand, (4) Center for Sedimentary Basin Studies, The University of Alabama, Box 870338, Tuscaloosa, AL 35487-0338

Reservoir characterization, modeling and simulation were undertaken to improve production from mature oil fields producing from carbonate reservoirs that are associated with petroleum traps resulting from salt tectonics. These fields produce oil from Upper Jurassic (Oxfordian) carbonate shoal reservoirs. These reservoirs occur in vertically stacked, heterogeneous depositional and porosity cycles. The cycles consist of lime mudstone/wackestone at the base and ooid grainstone/packstone at the top. The lime mudstone and wackestone lithofacies have been interpreted as restricted bay and lagoon sediments, and the grainstone and packstone lithofacies have been described as shoreface and shoal deposits. Although the primary control on reservoir architecture is the depositional fabric, diagenesis is a significant factor in modifying reservoir quality. Porosity has been enhanced through dissolution and dolomitization. Porosity is chiefly interparticle, solution-enlarged interparticle, grain moldic, intercrystalline dolomite and vuggy pores. Dolostone pore systems and flow units have the highest reservoir potential. Petroleum trapping mechanisms include fault traps (footwall uplifts with closure to the south against major west-east trending normal faults), footwall uplift traps associated with minor south-north trending normal faults, and salt-cored anticlines with four-way dip closure. Potential barriers to flow are present as a result of petrophysical differences among and within the cycles as well as the presence of normal faulting. Reservoir performance analysis and simulation indicate that both unitized and non-unitized fields have oil remaining to be recovered. A field-scale reservoir management strategy that includes the drilling of infill wells in structurally high areas and perforating existing wells in stratigraphically higher porosity zones is recommended for sustaining production from these fields.

Improving Recovery of Carbonate Reservoirs
2005 AAPG International Conference and Exhibition (September 11-14, 2005) Technical Program