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- Volume 30, Issue 4, 2012
First Break - Volume 30, Issue 4, 2012
Volume 30, Issue 4, 2012
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3D inversion of towed streamer EM data: a model study of the Harding field with comparison to CSEM
Authors M.S. Zhdanov, C. Anderson, M. Endo, L.H. Cox, M. Čuma, G.A. Wilson, N. Black and A.V. GribenkoMichael S. Zhdanov, Chris Anderson, Masashi Endo, Leif H. Cox, Martin Čuma, Glenn A. Wilson, Noel Black and Alexander V. Gribenko provide an early study of the challenges involved in validating offshore electromagnetic (EM) data acquired using a towed streamer receiver (currently under development) and compare the results with existing seabed-based marine controlled source electromagnetic (CSEM) technology.
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Integrated analysis of CSEM, seismic and well log data for prospect appraisal: a case study from West Africa.
Authors L. MacGregor, S. Bouchrara, J. Tomlinson, U. Strecker, J. Fan, X. Ran and G. YuLucy MacGregor, Slim Bouchrara, James Tomlinson, Uwe Strecker, Jianping Fan, Xuefeng Ran and Gang Yu argue that a significantly more robust interpretation of rock and fluid properties for a pre-drill prospect appraisal can be obtained from the resistivity information acquired by a controlled source electromagnetic (CSEM) survey if seismic and well information are incorporated. This is illustrated using a case study from offshore West Africa, where a CSEM dataset was acquired in 2009.
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Simultaneous joint inversion of 3D seismic and magnetotelluric data from the Walker Ridge
Authors E. Medina, A. Lovatini, F.G. Andreasi, S. Re and F. SnyderElena Medina, Andrea Lovatini, Federico Golfrè Andreasi, Simone Re and Fred Snyder present a case history from the Gulf of Mexico of multi-dimensional simultaneous joint inversion of wide-azimuth 3D seismic and marine magnetotelluric data to improve subsalt imaging.
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Exploration with the use of EM data in the Barents Sea: the potential and the challenges
Authors S. Fanavoll, S. Ellingsrud, P.T. Gabrielsen, R. Tharimela and D. RidyardStein Fanavoll, Svein Ellingsrud, Pål T. Gabrielsen, Raghava Tharimela and Dave Ridyard argue that latest marine EM technology developments, notably mapping deeper resistive structures could prove valuable in expeditng exploration of the potential opportunities offered by the Norwegian sector of the Barents Sea.
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Interpolating the gravity field using full tensor gradient measurements
By G. BarnesGary Barnes, champions the interpolative power of full tensor gradient (FTG) measurements and its key role in helping oil and gas explorations achieve a better representation of the anomaly field and a clearer picture of the subsurface.
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Depths to the bottom of magnetic sources and geothermal prospectivity in Southern Germany
Authors G. Gabriel, I. Dressel and D. VogelThe exploration effort for geothermal energy, for both district heating and electricity generation, is increasing rapidly in Germany. We have analysed recently compiled magnetic anomaly data to estimate depths to the bottom of magnetic sources (DBMS) as proxy information about the thermal conditions within the crust. The investigated area comprises the Bavarian Molasse Basin and parts of the Upper Rhine Graben. These two geological provinces are particularly important for geothermal exploration in Germany, because of their favourable transmissibilities and high geothermal gradients, respectively. We used geothermal constraints from a shallow borehole to optimize the window operator size and the wavenumber range in DBMS estimation. A window size of 200 km × 200 km is a good choice for this type of analysis, and an overlap between adjacent blocks of 180 km results in a smooth depth map and enables the identification of outliers. In southern Germany, the DBMS varies from 21 km north of Stuttgart to 36 km in the region south of Regensburg, with a mean depth of 26 km. Variations in the DBMS compare reasonably well with surface heat flow and very well with the temperature field at 3 km depth.
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Tectono-sedimentary features in 3D seismic data from the Moravian part of the Vienna Basin
Authors R. Prochác, M. Pereszlényi and B. SopkováBy the end of the 20th century, the geology of the Moravian part of the Vienna Basin was fairly well known from hydrocarbon exploration; nevertheless, recently acquired seismic data have provided important new information. Some of the most interesting geological features derived from 3D seismic interpretation are presented in this article. The main focus is on the Badenian deposits which comprise the most important sedimentary succession in terms of thickness, rock volume, tectonic evolution, and hydrocarbon accumulations. Examples from other Neogene stratigraphic stages are also presented. 3D seismic data analysis has contributed to a better understanding of the basin’s geological development in terms of the temporal and spatial relationships between tectonics, depositional environment, and sedimentation. The 3D data have enabled interpreters to identify new potential structural, stratigraphic, and combination hydrocarbon traps, some of which have been confirmed by wells.
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Velocity versus offset (VVO): a new tool for direct detection of gas in low-impedance sand reservoirs
Authors A. Supriyono, A. Priyono, W. Triyoso and L. PrasetyaA new direct hydrocarbon indicator is proposed using velocity information, called velocity variation with offset (VVO) or velocity variation with angle. Velocity is extracted from seismic data to predict hydrocarbon distribution in the reservoir. The theory is derived based on an equation for the dependence of velocity with direction in rocks with weak polar anisotropy. Fluid content in the reservoir affects the anisotropic properties of the rock and thereby alters the variation in interval velocity with offset. We have tested VVO over a low-impedance gas sand reservoir that gives rise to a class 3 AVO anomaly. The seismic data from a known gas field were processed with amplitude preservation and offset-based velocity analysis, and AVO and VVO attributes were generated. The VVO attributes are consistently in agreement with AVO responses around the gas discovery well and other bright amplitudes away from the well location. Thomsen’s anisotropy parameters ε and δ can also be derived from VVO analysis. They have anomalously large positive values at the locations with bright amplitudes.
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Volumes & issues
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Volume 42 (2024)
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Volume 41 (2023)
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Volume 40 (2022)
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Volume 39 (2021)
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Volume 38 (2020)
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Volume 37 (2019)
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Volume 36 (2018)
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Volume 35 (2017)
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Volume 34 (2016)
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Volume 33 (2015)
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Volume 32 (2014)
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Volume 31 (2013)
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Volume 30 (2012)
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Volume 29 (2011)
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Volume 28 (2010)
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Volume 27 (2009)
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Volume 26 (2008)
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Volume 25 (2007)
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Volume 24 (2006)
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Volume 23 (2005)
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Volume 22 (2004)
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Volume 21 (2003)
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Volume 20 (2002)
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Volume 19 (2001)
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Volume 18 (2000)
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Volume 17 (1999)
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Volume 16 (1998)
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Volume 15 (1997)
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Volume 14 (1996)
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Volume 13 (1995)
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Volume 12 (1994)
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Volume 11 (1993)
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Volume 10 (1992)
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Volume 9 (1991)
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Volume 8 (1990)
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Volume 7 (1989)
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Volume 6 (1988)
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Volume 5 (1987)
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Volume 4 (1986)
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Volume 3 (1985)
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Volume 2 (1984)
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Volume 1 (1983)