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https://hdl.handle.net/2440/77119
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Type: | Conference paper |
Title: | Overpressures in the Northern Malay Basin: Part 1 - Origin and Distribution |
Author: | Tingay, M. Morley, C. Laird, A. Limpornpipat, O. Krisadasima, K. Pabchanda, S. Macintyre, H. |
Citation: | Society of Petroleum Engineers - International Petroleum Technology Conference 2012 : IPTC 2012: pp.3278-3289 |
Publisher: | SPE |
Publisher Place: | CDROM |
Issue Date: | 2012 |
ISBN: | 9781618396594 |
Conference Name: | International Petroleum Technology Conference (2012 : Bangkok, Thailand) |
Statement of Responsibility: | Mark Tingay, Chris Morley, Andrew Laird, Orapan Limpornpipat, Kanjana Krisadasima, and Suwit Pabchanda, Hamish Macintyre |
Abstract: | 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 suggests that gas generation accounts for approximately 70-50% of the measured excess pore pressure in the region, with the remaining 30-50% being generated by coincident disequilibrium compaction. Thus, the data herein indicates 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 may be attempted using a calibrated empirical model after careful picking and smoothing of the velocity data. |
Description: | Document ID: 15345-MS |
Rights: | Copyright 2011. International Petroleum Technology Conference |
DOI: | 10.2523/15345-MS |
Published version: | http://dx.doi.org/10.2523/15345-ms |
Appears in Collections: | Aurora harvest 4 Australian School of Petroleum publications |
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