--> Levantine Basin Petroleum Systems: A Regional 2-D Basin Modeling Study, Marlow, Lisa; Wattrus, Nigel; Swenson, John; Kendall, Christopher; Kornpihl, Kristijan (Duplo), #90100 (2009)

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Levantine Basin Petroleum Systems: A Regional 2-D Basin Modeling Study

Marlow, Lisa1
 Wattrus, Nigel1
 Swenson, John1
 Kendall, Christopher2
Kornpihl, Kristijan (Duplo)3

1Geology, University of Minnesota, Duluth, MN.
2
Geology,
University of South Carolina, Columbia, SC.
3
IES-Schlumberger,
Houston, TX.

The Levantine Basin has proven hydrocarbons, yet much of it remains a frontier petroleum basin. Regional 2-D petroleum systems modeling of the basin suggests potential source rocks are well inside the generation window. Five potential source rock intervals (Triassic-Paleocene) have been identified based on regional analogs and seismic and well interpretations. Tectonics followed the general progression associated with the opening and closing of the Tethys: rift-extension, passive margin, and compression. Stratal thickness, up to 15 km thick, consists of mixed siliciclastic-carbonate-evaporite facies. Within the stratal package, there are potential reservoir and seal rocks. The tectonostratigraphic history was conducive to trap formation; the model suggests oil and gas accumulations are both spatially and temporally in structural and stratigraphic traps throughout the basin.

Kerogen in the older source rocks are fully transformed whereas the younger source rocks are partially mature. The source rocks are preferentially mature basinward. Modeling suggests ample charge to the system from the source rock. While primary migration trend is vertical there is also lateral migration in carrier beds that may have led to accumulation at the basin margin.

The basin has many hydrocarbon shows in the few existing wells located on the modern continental slope although none have commercial significance. However, recently Noble Energy had a significant natural gas discovery (3 TCF or more) from a sub-Messinian salt structure of Early Miocene age. The Tamar well reached a depth of 4,900 meters and it is one of the few wells drilled in the deeper part of the basin (~1700m. water depth).

Due to the frontier character of the study a thorough risk analysis of the uncertainty within the input parameters was performed rather than a classic approach with multiple-scenario simulation runs based on a master model. A Monte Carlo Simulation workflow was performed in which the uncertainty ranges for the initial “best-guess” parameters were set and quantified. The “Monte Carlo Workflow” is straightforward: uncertainty distributions are created for the key parameters. A set of random input parameters are drawn from these distributions and a simulation run with this parameter set is performed. This procedure is repeated and the results are collected. Output parameters are assembled, visualized, and analyzed with statistical tools such as histograms.

AAPG Search and Discover Article #90100©2009 AAPG International Conference and Exhibition 15-18 November 2009, Rio de Janeiro, Brazil