Schlumberger Technology Corporation

Saudi Arabian Oil Company

Chevron U.s.a. Inc.

Chengbing Liu

Shouxiang Mark Ma

Wael Abdallah

Ping Zhang

Dzevat Omeragic

Qiming Li

Jan Smits

Jian Yang

Helene Claire Climent

Salah Mohammed Al-Ofi

Andrea Valori

Libo Yang

Lawrence Chou

Stephen Newton

Yanqing Zeng

Marie Van Steene

Methods and systems are provided for characterizing formation water salinity of subsurface formation using multifrequency permittivity data over a range of frequencies below 1 MHz. The multifrequency permittivity data is processed to determine salinity of formation water contained in the subsurface formation. Other useful formation properties (such as formation water saturation) can be determined based on the formation water salinity.

Determination of formation water salinity using downhole low frequency electromagnetic measurements and permittivity dispersions based thereon

Methods and systems are provided that employ a combination of dielectric dispersion measurement(s) and Nuclear Magnetic Resonance (NMR) measurement(s) to determine data that characterizes tortuosity of rock and data that characterizes tortuosity of fluid phases in the rock independently from one another.

Methods and systems to determine tortuosity of rock and fluids in porous media

Methods and systems are provided for clay detection, clay typing, and clay volume quantification using electromagnetic measurements on a porous media sample at a low frequency less than 5000 Hz. The electromagnetic measurements are used to determine and store permittivity data that characterizes permittivity of the porous media sample at the low frequency less than 5000 Hz. The low frequency electromagnetic measurements can be performed in a laboratory, at a wellsite or other surface location. The low frequency electromagnetic measurements are nondestructive, and the results indicate that the methods and systems are highly sensitive to the existence of clays.

Clay detection and quantification using low frequency electromagnetic measurements

Methods and systems are provided for clay detection, clay typing, and clay volume quantification using downhole electromagnetic measurements conducted by a downhole logging tool on a formation at a low frequency less than 5000 Hz. The downhole electromagnetic measurements are used to determine permittivity data that characterizes permittivity of the formation at the low frequency less than 5000 Hz. The downhole low frequency electromagnetic measurements are nondestructive, and the results indicate it is with high sensitivity to the existence of clays.

Clay detection and quantification using downhole low frequency electromagnetic measurements

An array electromagnetic tool is run in a borehole, and resulting signals are processed to provide at least one of real and imaginary conductivity components, &#x3c3;and &#x3c3;. The at least one of real and imaginary conductivity components is compared to a corresponding representative conductivity component of a plurality of different clay groups and a determination of clay type in the formation is made therefrom.

Formation clay typing from electromagnetic measurements

A system and a method are provided for determining a viscosity of a fluid in a rock formation. The method includes determining a Stoneley mobility using a Stoneley wave measurement in a rock formation containing a fluid; determining a wireline formation tester (WFT) downhole fluid analysis (DFA) mobility by using a wireline formation tester in the rock formation; and determining a viscosity of the fluid based on the Stoneley mobility and the wireline formation tester (WFT) downhole fluid analysis (DFA) mobility.

System and method for determining fluid viscosity of a fluid in a rock formation

A computer system and computer implemented method for automatically identifying a hydrocarbon (such as kerogen, gas, oil) rich zone in a well bore includes obtaining well log data comprising neutron data, density data, radioactivity data, and resistivity data representative of physical characteristics of a formation surrounding the well bore and computing an apparent neutron porosity and an apparent density porosity based on the neutron data and density data. A normalized neutron-density separation is computed based on the computed apparent neutron porosity and the computed apparent density porosity and a baseline of the formation is determined for each data type. Using the computed normalized neutron-density separation, the radioactivity data, the resistivity data, and the determined baselines, the presence or absence of a hydrocarbon rich zone is determined. A quality index may further be derived from the data.

System and method for sweet zone identification in shale gas reservoirs

A system and computer-implemented method for characterizing hydrocarbon gas net pay zones in a subterranean reservoir including determining a sweet zone indicator from well log data, determining rock properties from well log data, and identifying one or more classes of net pay zones from the sweet zone indicator and rock properties. The sweet zone indicator may be determined by computing neutron-density separation and using the neutron-density separation and the well log data. The rock properties determined from the well log data may include total water saturation, adsorbed gas saturation, total gas content, porosity, propensity for hydraulic fracturing, uncertainty level of the total water saturation, uncertainty level of the total gas content, and baselines for the porosity and total gas content. Using the sweet zone indicator and rock properties, one or more classes of net pay zones can be identified.

System and method for hydrocarbon gas pay zone characterization in a subterranean reservoir

Various technologies for removing shoulder-bed effects from measurements of an earth formation made in a wellbore. In one implementation, a methodology for removing the shoulder-bed effects includes receiving the measurements and constructing a layered model of the earth formation. Each layer has a set of parameters corresponding to one or more types of the received measurements ascribed to each layer such that the set of parameters define a parameter space for the layered model. The methodology may further include dividing the parameter space into subspaces based on relationships among the parameters, selecting from the subspaces one or more starting points, minimizing a cost function using the one or more starting points to generate one or more candidate solutions having the shoulder-bed effects removed and selecting a final solution from the one or more candidate solutions.

Shoulder bed effects removal

A method is described for characterizing a subsurface formation with a logging instrument disposed in a borehole penetrating the formation. The logging instrument is equipped with at least a transmitter system and a receiver system. The method entails positioning the logging instrument within the borehole so that the transmitter system and receiver system are disposed in the vicinity of a formation boundary of interest and measuring the azimuthal orientation of the logging instrument. Electromagnetic energy is transmitted into the formation using the transmitter system and signals associated with the transmitted electromagnetic energy are measured using the receiver system. The method further entails determining the relative azimuth of the formation boundary, composing a symmetrized directional measurement using the measured signals and the determined relative boundary azimuth, and determining the relative dip of the formation boundary using the composed directional measurement.

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Katy, TX, United States of America

Chengbing Liu