Abstract: A method for fluid identification (water, oil, gas or CO2) and saturation estimation in subsurface rock formations using the prestack inverted seismic data by calculating the target fluid saturation (Sfl)(114) in a reservoir given the magnitude obtained from the P- to S-wave velocity ratio (Vp/Vs) (103), and acoustic impedance (AI) (102) extracted from the seismic data inversion, comprising the following steps: a) obtaining wireline log data within a zone of interest in a nearby well (101) and determining the suitable cementation and mineralogy factors by calibrating the background water-bearing sand trend with the reference 0% (or 0 fraction) Sfl curve onto the acoustic impedance-Vp/Vs ratio plane (110), b) calibrating Sfl computed from the acoustic impedance-Vp/Vs ratio curves with Sfl obtained from a conventional method by iterating P-wave velocity (Vpfl) and density (?fl) of the target fluid (111), c) obtaining inverted seismic data in the form of Acoustic Impedance (AI) (102) and Vp/Vs ratio (103) cubes,

Abstract: A method for fluid identification and saturation estimation in subsurface rock formations using the Controlled Source Electromagnetic (CSEM) data and Seismic Data by calculating the fluid saturation (Sfl) in a reservoir given the resistivity obtained from CSEM data, and acoustic impedance obtained from the seismic data, comprising the following steps: a) obtaining wireline data within a zone of interest in a nearby well and determining the resistivity of water by calibrating the background resistivity trend with a reference Sfl curve, b) obtaining inverted CSEM survey data from a subsurface zone of interest, c) obtaining inverted seismic data in the form of Acoustic Impedance (AI), d) bringing both the inverted CSEM and acoustic impedance data to a same domain; time or depth, f) calculating fluid saturation using a rock physics model inputting the resistivity of water along with inverted CSEM and acoustic impedance data, resulting in a Sfl profile.

Abstract: A method for fluid identification (water, oil, gas or CO2) and saturation estimation in subsurface rock formations using the prestack inverted Seismic by calculating the target fluid saturation (Sfl) (114) in a reservoir given the magnitude obtained from the P- to S-wave velocity ratio (Vp/Vs) (103), and acoustic impedance (AI) (102) extracted from the seismic data inversion, comprising the following steps: a) obtaining wireline log data within a zone of interest in a nearby well (101) and determining the suitable cementation and mineralogy factors by calibrating the background water-bearing sand trend with the reference 0% (or 0 fraction) Sfl curve onto the acoustic impedance-Vp/Vs ratio plane (110), b) calibrating Sfl computed from the acoustic impedance-Vp/Vs ratio curves with Sfl obtained from a conventional method by iterating P-wave velocity (Vpf) and density (?fl) of the target fluid (111), c) obtaining inverted seismic data in the form of Acoustic Impedance (AI) (102) and Vp/Vs ratio (103) cubes, and

Abstract: A method for shale volume (Vsh) estimation in subsurface rock formations using the prestack inverted Seismic by calculating the Vsh in a reservoir given the magnitude obtained from the P- to S-wave velocity ratio (Vp/Vs), and acoustic impedance (AI) extracted from the seismic data inversion, comprising the following steps: a) obtaining wireline log data within a zone of interest in a nearby well and determining the suitable cementation and mineralogy factors by calibrating the background water-bearing sand trend containing zero percent shale volume with the reference zero percent shale volume curve onto the acoustic impedance-Vp/Vs ratio plane, b) calibrating Vsh computed from the acoustic impedance-Vp/Vs ratio curves with Vsh obtained from a conventional method by iterating the P-wave velocity (Vpsh) and density (?sh) of shale, c) obtaining inverted seismic data in the form of Acoustic Impedance (AI) and Vp/Vs ratio cubes, and d) calculating the shale volume using the calibrated rock physics model inputting

Abstract: The invention describes a procedure for determining the subsurface total organic content (TOC) from data obtained in the well by at least three well-logging tools measuring corresponding parameters. Three tools, namely sonic, density and deep resistivity are selected. The time interval signals from the sonic tool are converted to the P-wave velocity. The product of signals obtained from the sonic and density tools (P-wave velocity×Bulk density=Acoustic Impedance (AI)) responds in the same direction to a variation of the volume of water and organic matter (OM) volume of the rocks, whereas the third tool (Deep Resistivity) reacts very differently in response to a change of one or other of these same components, in a three-pole diagram, with rock matrix, OM and water as the three components onto an Acoustic Impedance vs resistivity ratio function plane. The resistivity ratio function is the square root of the ratio between the water resistivity and the measured formation resistivity.

Abstract: The invention describes a procedure for determining the shale brittleness index from data obtained in the well by at least three well-logging tools measuring corresponding parameters. Three tools, namely sonic, density and deep resistivity, are selected. The time interval signals from the sonic tool are converted to the P-wave velocity. The product of signals obtained from the sonic and density tools (P-wave velocity×Bulk density=Acoustic impedance (AI)) responds in the same direction to a variation of the volume of water and organic matter (OM) volume of the rocks, whereas the third tool (Deep Resistivity) reacts very differently in response to a change of one or other of these same components, in a three-pole diagram, with rock matrix, OM and water as the three components onto an Acoustic Impedance vs resistivity ratio function plane. The resistivity ratio function is the square root of the ratio between the water resistivity and the measured formation resistivity.

Abstract: A method for fluid identification and saturation estimation in subsurface rock formations using the Controlled Source Electromagnetic (CSEM) data and Seismic Data by calculating the fluid saturation (Sfl) in a reservoir given the resistivity obtained from CSEM data, and acoustic impedance obtained from the seismic data, comprising the following steps: a) obtaining wireline data within a zone of interest in a nearby well and determining the resistivity of water by calibrating the background resistivity trend with a reference Sfl curve, b) obtaining inverted CSEM survey data from a subsurface zone of interest, c) obtaining inverted seismic data in the form of Acoustic Impedance (AI), d) bringing both the inverted CSEM and acoustic impedance data to a same domain; time or depth, f) calculating fluid saturation using a rock physics model inputting the resistivity of water along with inverted CSEM and acoustic impedance data, resulting in a Sfl profile.