Baker Hughes Corporation

Gabor Hursan

Songhua Chen

David J Jacobi

John Longo

Pedro Antonio Romero

Freddy Mendez

Mikhail N Gladkikh

See Hong Ong

Hyung Tae Kwak

Brian J LeCompte

Benito Eduardo Saavedra

Method and apparatus for estimating a kerogen (organic) porosity of an earth formation. The method may include using at least one processor to estimate a kerogen porosity using NMR signals indicative to an inorganic porosity and NMR signals indicative of a total porosity for a volume of interest in an earth formation. The apparatus may include an NMR tool configured to acquire NMR signals indicative to an inorganic porosity and NMR signals indicative of a total porosity for a volume of interest in an earth formation.

Kerogen porosity volume and pore size distribution using NMR

A method for evaluating an earth formation from a well bore, that includes: collecting at least one of geochemical data, petrophysical data and geomechanical data from a wellbore; and identifying depositional facies of the earth surrounding the wellbore. A computer program product and a system are provided.

Method for petrophysical evaluation of shale gas reservoirs

A method for estimating a property of a material, the method including: acquiring data using nuclear magnetic resonance (NMR) measurements, the measurements performed by varying at least one of a magnetic field gradient (G) and an inter-echo time (TE); organizing the data according to at least one of magnetic field gradients (G) and inter-echo times (TE) used in the NMR measurements; calculating a shift of apparent transverse relaxation time (T) and (longitudinal relaxation time T)/(apparent transverse relaxation time T) due to a variation of the product of G and TE; constructing a mathematical model of the NMR measurements from the shifts; and inverting the mathematical model to estimate the property.

Two dimensional T1/T2APP-T2APP processing of multi-gradient NMR data

A method for determining viscosity, &#x3b7;, of a fluid downhole, calls for performing a nuclear magnetic resonance (NMR) survey of the fluid; determining a longitudinal relaxation time, T, and an apparent transverse relaxation time, T, for the fluid; forming a ratio R of T/Tfor the fluid; and determining the viscosity, &#x3b7;, according to the ratio, R. A computer program product for implementing the method is provided.

Viscosity determination from logarithmic mean ratio of relaxation times

A method and apparatus for obtaining a parameter of interest relating to a region proximate a nuclear magnetic resonance (NMR) logging tool suitable for subterranean well logging is disclosed. The nuclei of the region are subjected to a pulsed NMR technique and are productive of NMR logging data, the nuclei of the region characteristically having a longitudinal relaxation time Tdistribution and an apparent transverse relaxation time Tdistribution. In response to the NMR logging data, an R distribution is defined as R=T/T, the Tand R distributions are processed as separate bins, along with the NMR logging data, according to a two-dimensional inversion model, and a signal intensity map of R versus Tis provided that is representative of the parameter of interest relating to the region. In response to a high-intensity signal on the map being within a first range of Tvalues and a first range of R values, the presence of a light hydrocarbon within the region is identified.

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The Woodlands, TX, United States of America

Gabor Hursan