Schlumberger Technology Corporation

Thomas J Neville

Terizhandur S Ramakrishnan

Cosan Ayan

Fikri John Kuchuk

Andrew John Carnegie

Raghu Ramamoorthy

Yi-Qiao Song

Ravinath Kausik Kadayam Viswanathan

Pabitra N Sen

Denis Heliot

Roger Griffiths

Jaideva C Goswami

Ollivier Faivre

Geoff Weller

Gabriela Leu

Ashok Srivastava

Nicholas Drenzek

Sherif Farag

Huijun Hou

Measuring a parameter characteristic of a formation in an oil well with a device configured to generate a sensing field within a volume of the formation and cause a flow through the volume in the presence of the sensing field. The device also comprises sensors responsive to changes in the volume, which indicate existent amounts of fluid, such as hydrocarbon and water saturations and irreducible hydrocarbon and water saturations. Measurements may be made before the flow affects the measuring volume and after onset of the flow through the measuring volume.

Formation treatment evaluation

Systems and methods for magic angle spinning nuclear magnetic resonance analysis of samples from unconventional reservoirs are described. Fast and inexpensive methods are described that can provide reliable information on TOC content, type, and maturity (via the relative abundances of different hydrocarbons, for example) without the need for more extensive sample preparation or destruction. If care is taken during sample recovery and storage, NMR can also yield an estimate of gas-in-place, including detailed typing (e.g. methane vs. ethane). The described MAS NMR analysis is used to determine various properties of unconventional reservoirs, including gas and oil shales, which are useful in evaluating their worth and producibility.

NMR analysis of unconventional reservoir rock samples

An apparatus and method of measuring a parameter characteristic of a rock formation in an oil well is provided with a device for generating a sensing field within a volume of the rock formation and a device for causing a flow through the volume in the presence of the sensing field, further including sensors responsive to changes in the volume, wherein a sensor response is indicative of the amounts of fluid, particularly hydrocarbon and water saturations and irreducible hydrocarbon and water saturations. Measurements can be made before the flow affects the measuring volume and after onset of the flow through the measuring volume.

Tool and method for determining formation parameter

In general, in one aspect, the invention relates to a method for evaluating a volcanic reservoir formation having volcanic rock forming elements and a borehole penetrating the volcanic reservoir formation. The method includes controlling chlorine concentration in an environment of the borehole and a tool operation to enable neutron capture spectroscopy measurements of the volcanic rock forming elements, obtaining neutron capture spectroscopy data relating to the volcanic rock forming elements from borehole logging tools, determining a lithology of the volcanic reservoir formation based on at least the neutron capture spectroscopy data, and generating an evaluation of the volcanic reservoir formation based on at least the lithology.

Evaluating a reservoir formation

This invention relates to petroleum reservoir characterization. It uses a novel system and method to generate a system of reservoir models, and then use a series of simulation techniques to simulate the models. The models are refined through each simulation and comparison step by comparing the results of the simulation with the known data from the reservoir. The invention can be applied to different reservoirs which have different known properties. Simulation techniques such as EM test forward calculation, stochastic reservoir modeling, streamline forward calculation are all candidates of simulation methods disclosed in the invention.

System and method for evaluating petroleum reservoir using forward modeling

A method of determining the porosity and fluid saturation for a given volume of an underground formation through which a borehole is drilled, the method comprising: measuring, from within the borehole, parameters relating to characteristics of the underground formation; determining volumetric values for resistivity, hydrogen index, density and neutron capture cross-section for the given volume from the measured parameters, each volumetric value including a contribution from formation matrix, water, oil and gas; determining, from the volumetric values, the volumes of rock matrix, pore water, oil and gas, and the salinity of the pore water; and determining the porosity and fluid saturation of the volume of the formation from the determined volumes and salinity.

Determination of porosity and fluid saturation of underground formations

A method and apparatus are useful for decomposing a complex distribution of data by modeling the complex distribution as a sum of discrete simple distributions, and processing the simple distributions independently. The independent processing enables the complex distribution to be reconstructed without the simple distributions that are concluded to be spurious. The simple distributions preferably include one or more statistical distributions that are subject to being characterized by a reduced data set for efficient communication and reconstruction of the complex distribution. The modeling and processing steps preferably employ one or more evolutionary algorithms.

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Beijing, China

Thomas J Neville