A computer-implemented method of hydrocarbon source rock characterization, comprising: a. receiving , at a computer processor, a seismic dataset representative of a subsurface volume of interest and a low frequency model of the subsurface volume of interest, wherein the seismic dataset contains frequencies in the range ~4-60 Hz and wherein the low frequency model contains frequencies in the range ~0-6 Hz; b. inverting , via the computer processor, the seismic dataset using the low frequency model to generate reservoir attributes; c. receiving , at the computer processor, maturity data from core measurements or basin modeling; and d. using the generated reservoir attributes and the maturity data, characterizing , via the computer processor, the hydrocarbon source rock based on the reservoir attributes and maturity data, wherein the characterizing includes: deriving a function AI = f(TOC, Ro), or deriving a function Ro = f(AI, TOC), or deriving a function Ro = f(Vp, TOC), wherein AI is acoustic impedance, TOC is Total Organic Content, Ro is vitrinite reflectance, and Vp is compressional velocity; and generating a 2-D or 3-D map of one or more of estimated TOC, source rock location, source rock thickness, and source rock maturity based on the derived function, and wherein: the seismic dataset is recorded seismic data from a seismic survey; and the method comprises designing well paths or designing drilling strategies or assessing hydrocarbon charge based on the generated 2-D or 3-D map. a. receiving , at a computer processor, a seismic dataset representative of a subsurface volume of interest and a low frequency model of the subsurface volume of interest, wherein the seismic dataset contains frequencies in the range ~4-60 Hz and wherein the low frequency model contains frequencies in the range ~0-6 Hz; b. inverting , via the computer processor, the seismic dataset using the low frequency model to generate reservoir attributes; c. receiving , at the computer processor, maturity data from core measurements or basin modeling; and d. using the generated reservoir attributes and the maturity data, characterizing , via the computer processor, the hydrocarbon source rock based on the reservoir attributes and maturity data, wherein the characterizing includes: deriving a function AI = f(TOC, Ro), or deriving a function Ro = f(AI, TOC), or deriving a function Ro = f(Vp, TOC), wherein AI is acoustic impedance, TOC is Total Organic Content, Ro is vitrinite reflectance, and Vp is compressional velocity; and generating a 2-D or 3-D map of one or more of estimated TOC, source rock location, source rock thickness, and source rock maturity based on the derived function, deriving a function AI = f(TOC, Ro), or deriving a function Ro = f(AI, TOC), or deriving a function Ro = f(Vp, TOC), wherein AI is acoustic impedance, TOC is Total Organic Content, Ro is vitrinite reflectance, and Vp is compressional velocity; and generating a 2-D or 3-D map of one or more of estimated TOC, source rock location, source rock thickness, and source rock maturity based on the derived function, and wherein: the seismic dataset is recorded seismic data from a seismic survey; and the method comprises designing well paths or designing drilling strategies or assessing hydrocarbon charge based on the generated 2-D or 3-D map. the seismic dataset is recorded seismic data from a seismic survey; and the method comprises designing well paths or designing drilling strategies or assessing hydrocarbon charge based on the generated 2-D or 3-D map. <EOS>