Schlumberger Technology Corporation

Services Petroliers Schlumberger

Albina Mutina

Yi-Qiao Song

Martin D Hurlimann

Lalitha Venkataramanan

Ravinath Kausik Kadayam Viswanathan

Tarek M Habashy

Andrew Emil Pomerantz

Nicholas J Heaton

Henry N Bachman

Lin Liang

Yiqiao Tang

Vivek Anand

David Furse Allen

Mikhail Stukan

Vasileios-Marios Gkortsas

Raphael Altman

Noyan Evirgen

Khaled Hadj-Sassi

Scott DiPasquale

Diogenes Molina

Henry Nathaniel Bachman

A method can include accessing a measurement model in memory of a downhole tool; determining an optimal parameter set using a processor of the downhole tool and the measurement model; and performing at least one measurement using at least one sensor of the downhole tool operated according to the optimal parameter set.

Adaptive downhole acquisition system

Methods and systems are provided for characterizing fluids in a subterranean formation traversed by a borehole, where NMR data is measured by a downhole NMR tool that is conveyed in the borehole that traverses the formation. The NMR data is processed to derive T1-T2 maps at different depths of the formation. The T1-T2 maps at different depths of the formation can be processed to generate a cluster map of different fluids that are present in the formation, wherein the cluster map is a two-dimensional array of grid points in the T1-T2 domain with each grid point being assigned or classified to a specific fluid. The cluster map of different fluids that are present in the formation can be used to characterize properties of the formation, such as fluid volumes for the different fluids at one or a number of depths.

Methods for determining fluid volumes from NMR T1-T2 log data

A method, computer program product, and computing system for receiving downhole logging data for a porous media. A pore size distribution index may be estimated based upon, at least in part, nuclear magnetic resonance data (NMR) from the downhole logging data of the porous media. A relative permeability and capillary pressure curve may be generated with a feasible region of solutions based upon, at least in part, the pore size distribution index.

System and method for reducing a feasible region of solutions in a relative permeability and capillary pressure curve

Downhole properties of a geological formation may be determined using nuclear magnetic resonance (NMR) measurements obtained by a moving tool. To do so, an interpretation of the NMR data obtained by the moving data may take into account a moving model, characterization, or calibration of the downhole NMR tool. Additionally or alternatively, a partial interpretation mask may exclude interpretation of certain areas of data (e.g., T1-T2 data points or diffusion-T2 data points) that are expected to be less likely to describe downhole materials of interest.

Fast measurement and interpretation of downhole multi-dimensional measurement

The present disclosure relates to a method that includes generating a first pulse at a first position along a geological formation with a plurality of antennae, wherein the first pulse comprises a Can-Purcell-Meiboom-Gill (CPMG) sequence, and wherein each antenna of the plurality of antennae is configured to generate NMR data via transmitting and receiving pulses into the geological formation.

Techniques for NMR logging with antenna arrays

Various implementations directed to determining a phase behavior of a reservoir fluid are provided. In one implementation, a method may include receiving a plurality of predetermined pore size data, a plurality of predetermined bulk fluid data, and a plurality of predetermined kerogen data that are based on historical data for a plurality of hydrocarbon reservoirs. The method may also include creating a library of a plurality of simulated phase behavior data for the predetermined pore size data, the predetermined bulk fluid data, and the predetermined kerogen data. The method may further include determining a phase behavior of a reservoir fluid disposed in an actual hydrocarbon reservoir using the library.

Determining phase behavior of a reservoir fluid

Methods for analyzing a formation samples using nuclear magnetic resonance (NMR) are described herein. One method includes performing an NMR measurement of the formation sample to obtain NMR data. The NMR measurement detects NMR signals with echo times of less than or equal to 100 microseconds. The NMR data is analyzed to determine a measure of organic hydrogen content of the formation sample, such as (i) total organic hydrogen content, (ii) kerogen content, (iii) bitumen content, and/or (iv) oil content.

Method of analyzing formation samples using NMR measurements with an echo time being 100 microseconds or less

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Albina Mutina