Schlumberger Technology Corporation

Saudi Arabian Oil Company

Shawn David Taylor

Ravinath Kausik Kadayam Viswanathan

Ahmed Hammami

Yi-Qiao Song

Gary John Tustin

Sharath Chandra Mahavadi

Yiqiao Tang

Kamilla Fellah

Dmitry Eskin

Hussein Alboudwarej

Gary Potten

Shouxiang Mark Ma

Christopher Harrison

Robert L Kleinberg

Matthew T Sullivan

Wael Abdallah

Farshid Mostowfi

Anthony R H Goodwin

Charles Flaum

Shahnawaz Hossain Molla

Elizabeth Jennings Smythe

Shin Utsuzawa

Austin Boyd

Vincent Joseph Sieben

Paul Ryan Craddock

John Ratulowski

Shunsuke Fukagawa

Simon Ivar Andersen

Scott Jacobs

Geza Horvath Szabo

Robert Allen Badry

Christian Straley

John Meier

Terry Sopkow

MaryEllen Loan

Olivier Faivre

Joao Felix

Dingzheng Yang

Dmitri Eskin

Systems and methods for monitoring a crude oil blending process use nuclear magnetic resonance (NMR) sensors which investigate properties of a plurality of crude oil streams that are mixed together to form a crude oil blend. An NMR sensor is also used to investigate the properties of the crude oil blend. The investigated properties may include viscosity. Resulting determinations may be used to control the input streams so that the output stream meets desired criteria. Additional sensors such as spectroscopy sensors, viscometers, and densitometers may be used in conjunction with the NMR sensors.

Methods and systems for crude oil blending with quality and composition monitoring and control

Methods and systems are provided that combine NMR and IR spectroscopy measurements on a rock sample to determine data representing at least one property of the rock sample. In one embodiment, cuttings can be split into first and second lots. Results of an NMR measurement performed on the first lot of cuttings without cleaning can be analyzed to determine pore volume of the cuttings. Results of an IR spectroscopy measurement performed on the second lot of cuttings after solvent cleaning can be analyzed to determine matrix density of the cuttings. Porosity can be determined from the pore volume and matrix density of the cuttings. In another embodiment, combined NMR and IR spectroscopy measurements can be performed on an unprepared rock sample (without solvent cleaning) to characterize properties of kerogen in the rock sample and porosity. In another aspect, a method is provided that employs multi-nucleic NMR measurements to determine porosity.

Methods and systems for characterizing properties of reservoir rock

Nuclear magnetic resonance (NMR) relaxation and/or diffusion measurements are used to deduce fluid compositional information such as a chain-length distribution, which may then be used to predict the true boiling points (TBP) of a sample of a complex hydrocarbon fluid mixture, such as a crude oil. The NMR measurements may be considered a fast and portable proxy measurement in estimating fluid TBP distributions in lieu of distillation methods, or the simulated distillation by gas chromatography.

Method for determining the true boiling points of complex hydrocarbon fluids using nuclear magnetic resonance

In one possible implementation, a computer-readable tangible medium includes instructions that direct a processor to access one or more wellbore properties and a plurality of well fluid properties. Instructions are also present that direct the processor to access a distance between a proposed location of an inlet to a multiphase production logging tool and an emulsion generation location in a wellbore. Further instructions instruct the processor to predict a drop size distribution of emulsified water in the well fluid at the proposed location of the inlet to the multiphase production logging tool. Additional instructions instruct the processor to compute an estimated error in water holdup detected by the multiphase production logging tool based on the drop size distribution, and recommend deployment of a pulsed neutron logging tool in the wellbore when the estimated error in the water holdup is above a preset threshold.

Predicting water holdup measurement accuracy of multiphase production logging tools

Methods may include emplacing an emulsion into an annular region of a Taylor-Couette (TC) device; flowing the emulsion through the annular region created by a first annular surface and a second annular surface; contacting one or more shear sensors disposed on a surface of the annular region with the flowing emulsion, wherein contact with the one or more shear sensors generates a signal that scales with shear stress exerted by the flowing emulsion, and determining one or more of wall shear stress from the signal obtained from the one or more shear sensors. Methods may also include determining the apparent viscosity of the fluid composition from the stress measured on the wall of the TC device.

Method of operating a Taylor-Couette device equipped with a wall shear stress sensor to study emulsion stability and fluid flow in turbulence

A method for determining an asphaltene onset condition of a crude oil is provided. The method includes receiving a crude oil within a downhole tool inside a well and taking a first measurement of an optical property of the received crude oil. The method also includes lowering the pressure or temperature of the crude oil after taking the first measurement of the optical property to cause aggregation of asphaltenes in the crude oil, and then separating aggregated asphaltenes from the crude oil. Further, the method includes taking a second measurement of the optical property of the crude oil within the downhole tool after separating aggregated asphaltenes from the crude oil and determining an asphaltene onset condition of the crude oil through comparison of the first and second measurements of the optical property. Additional methods, systems, and devices are also disclosed.

Method and apparatus for measuring asphaltene onset conditions and yields of crude oils

A reservoir sampling apparatus comprising at least one probe adapted to provide a fluid flow path between a formation and the inner of the apparatus with a heating projector adapted to project heat into the formation surrounding the probe and a controller to maintain the temperature in the formation below a threshold value.

Downhole sampling

A reservoir sampling apparatus () is described having at least one probe () adapted to provide a fluid flow path between a formation and the inner of the apparatus with the flow path being sealed from direct flow of fluids from the borehole annulus with a heating projector () adapted to project heat into the formation surrounding the probe and a controller () to maintain the temperature in the formation below a threshold value.

Downhole sampling apparatus and method for using same

Methods and apparatus for the characterization of formation fluids are disclosed. A downhole tool disposed in a borehole penetrating a subterranean formation obtains a NMR measurement, effects a change in a characteristic of the formation fluid, and obtains another NMR measurement subsequent to the change. Alternatively, the downhole tool effects a radial gradient of a characteristic of the formation and obtains NMR measurements at two or more selected radial distances from the wellbore wall. A parameter representative of the subterranean formation or the formation fluid is further determined from the NMR measurements.

Methods and apparatus for monitoring a property of a formation fluid

A method for generating and characterizing an emulsion. The method provides a Couette device having first and second cylindrical members that define an annulus between them. The second cylindrical member is rotatably driven with respect to the first cylindrical member. Two or more substances each in a non-emulsified state are injected into the annulus. The Couette device is operated in a first mode to generate an emulsion from the two or more substances. The Couette device is also operated in a second mode to measure various attributes of the emulsion.

Method for operating a couette device to create and study emulsions

Apparatus and methods are described for isolating or manipulating a portion of a sample at non-ambient temperatures and pressures. One apparatus embodiment of the invention comprises a primary sample containment vessel defining a primary chamber, the vessel having a primary sample inlet and outlet; a secondary sample collection container defining a collection chamber fluidly connected to the primary containment vessel; and a sample probe comprising a distal end able to isolate a secondary sample in the primary chamber and transfer it to the collection chamber, the probe fluidly connected to the primary chamber via a seal allowing at least the distal end to be moved in 3-dimensions within the primary chamber. This abstract complies with rules requiring an abstract. It should not be used to limit the scope or meaning of the claims. 37 CFR 1.72(b).

Apparatus and methods for sample handling and rheology analysis

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Edmonton, Canada

Shawn David Taylor