--> ABSTRACT: Origin and Distribution of Overpressure in the Northern Malay Basin, by Tingay, Mark; Morley, Chris K.; Laird, Andrew; Limpornpipat, Orapan; Krisadasima, Kanjana; Macintyre, Hamish; Pabchanda, Suwit; #90155 (2012)

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Origin and Distribution of Overpressure in the Northern Malay Basin

Tingay, Mark¹; Morley, Chris K.²; Laird, Andrew²; Limpornpipat, Orapan²; Krisadasima, Kanjana²; Macintyre, Hamish²; Pabchanda, Suwit³
¹Australian School of Petroleum, Univ Adelaide, Adelaide, SA, Australia.
²PTT Exploration and Production Public Company Limited, Bangkok, Thailand.
³PTTEP International Limited, Bangkok, Thailand.

Pore pressure data and sonic velocity-vertical effective stress plots from 31 wells reveal that overpressures in the northern Malay Basin are primarily generated by fluid expansion and located basin-wide within the 2A, 2B and 2C source rock formations. Overpressure magnitude increases towards the basin-centre, with maximum pore pressure gradients of >19.0 MPa/km observed in the southeast of the study area. The overpressures are predominately associated with gas, with gas sampled in over 83% of overpressure measurements. The association of overpressures with gas, combined with a regional geology that largely precludes other fluid expansion overpressure mechanisms, provides the first convincing in-situ evidence for basin-wide gas generation overpressure. Overpressure magnitude analysis indicates that gas generation accounts for approximately 46-67% of the measured excess pore pressure in the region, with the remaining 33-54% being generated by coincident disequilibrium compaction. Thus, the data herein suggests that gas generation, if acting in isolation, produces a maximum pressure gradient of 15.2 MPa/km (0.672 psi/ft), and not lithostatic magnitudes as is often hypothesized. The gas generation overpressures in this study are not associated with a significant porosity anomaly and thus represent a major drilling hazard, with traditional pore pressure prediction techniques underestimating pressure gradients by 2.3±1.5 MPa/km (0.102±0.066 psi/ft). However, pore pressure prediction is possible using a modified approach after careful smoothing and picking of velocity data.


AAPG Search and Discovery Article #90155©2012 AAPG International Conference & Exhibition, Singapore, 16-19 September 2012