Abstract: The present disclosure relates to a method of calculating the radiogenic heat production (RHP) of a geophysical structure, wherein there is provided at least one geophysical parameter of the geophysical structure, the method including inverting the at least one geophysical parameter to estimate the RHP of the geophysical structure.

Abstract: A method is disclosed for the estimation of subsurface temperature distributions from a 3-dimensional heat conductivity model for a geological formation. The method may be characterized by the following steps: (a) obtaining measured data corresponding to a geological subsurface formation of interest including seismic survey data, in-well temperature, seafloor or surface heat flux measurements and laboratory-based measurements of core porosity, (b) estimating a relationship between seismic velocity and heat conductivity, wherein seismic velocity is linearly dependent on porosity and heat conductivity is exponentially or linearly dependent on porosity, and (c) calibrating the model to the measured in-well data and laboratory-based measurements of core porosity.

Abstract: The present disclosure relates to a method of calculating the radiogenic heat production (RHP) of a geophysical structure, wherein there is provided at least one geophysical parameter of the geophysical structure, the method including inverting the at least one geophysical parameter to estimate the RHP of the geophysical structure.

Abstract: A method of assessing a hydrocarbon source rock candidate uses seismic data for a region of the Earth. The data are analyzed to determine the presence, thickness and lateral extent of candidate source rock based on the knowledge of the seismic behavior of hydrocarbon source rocks. An estimate is provided of the organic content of the candidate source rock from acoustic impedance. An estimate of the hydrocarbon generation potential of the candidate source rock is then provided from the thickness and lateral extent of the candidate source rock and from the estimate of the organic content.

Abstract: A method of assessing a hydrocarbon source rock candidate uses seismic data for a region of the Earth. The data are analysed to determine the presence, thickness and lateral extent of candidate source rock based on the knowledge of the seismic behaviour of hydrocarbon source rocks. An estimate is provided of the organic content of the candidate source rock from acoustic impedance. An estimate of the hydrocarbon generation potential of the candidate source rock is then provided from the thickness and lateral extent of the candidate source rock and from the estimate of the organic content.

Abstract: A method of assessing a hydrocarbon source rock candidate uses seismic data for a region of the Earth. The data are analyzed to determine the presence, thickness and lateral extent of candidate source rock based on the knowledge of the seismic behavior of hydrocarbon source rocks. An estimate is provided of the organic content of the candidate source rock from acoustic impedance. An estimate of the hydrocarbon generation potential of the candidate source rock is then provided from the thickness and lateral extent of the candidate source rock and from the estimate of the organic content.

Abstract: A method is disclosed for the estimation of subsurface temperature distributions from a 3-dimensional heat conductivity model for a geological formation. The method may be characterized by the following steps: (a) obtaining measured data corresponding to a geological subsurface formation of interest including seismic survey data, in-well temperature, seafloor or surface heat flux measurements and laboratory-based measurements of core porosity, (b) estimating a relationship between seismic velocity and heat conductivity, wherein seismic velocity is linearly dependent on porosity and heat conductivity is exponentially or linearly dependent on porosity, and (c) calibrating the model to the measured in-well data and laboratory-based measurements of core porosity.

Abstract: A method and apparatus for estimating a rock physics model anisotropic parameter for a geological subsurface. A volume fraction of dry clay minerals present in the geological subsurface is determined. A total porosity of the geological subsurface is also determined. A value for the anisotropic parameter is determined using the volume fraction of dry clay minerals, the total porosity and empirically derived constants. The resultant anisotropy parameters can be used in rock physics models where, for example, estimates of the anisotropy parameters cannot be obtained from other sources.

Abstract: A method of assessing a hydrocarbon source rock candidate uses seismic data for a region of the Earth. The data are analysed to determine the presence, thickness and lateral extent of candidate source rock based on the knowledge of the seismic behaviour of hydrocarbon source rocks. An estimate is provided of the organic content of the candidate source rock from acoustic impedance. An estimate of the hydrocarbon generation potential of the candidate source rock is then provided from the thickness and lateral extent of the candidate source rock and from the estimate of the organic content.