Schlumberger Technology Corporation

Haldor Topse A/s

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Simon Ivar Andersen

Sharath Chandra Mahavadi

Farshid Mostowfi

Vincent Joseph Sieben

Yi-Qiao Song

Wael Abdallah

Mohammed Badri

Ravinath Kausik Kadayam Viswanathan

Shahnawaz Hossain Molla

Dominic Joseph Brady

Abdel Kharrat

Elizabeth Jennings Smythe

Shawn David Taylor

Yiqiao Tang

Isabelle Couillet

Olivier Porcherie

Geza Horvath Szabo

Evgeny Nikolaevich Dyshlyuk

Bastian Sauerer

Kamilla Fellah

Kenneth Chau

Kurt Schmidt

Gary Potten

Annette Leerskov

Peter Jakob Mune

Cailan Libby

Mohammed Al-Shakhs

Albina Rishatovna Mutina

Mohamed Ahmed Abdel Reheem Hamdy

Vincent Sieben

Ton VW Janssens

Pär LT Gabrielsson

Svend Erik Mikkelsen

Abdel M Kharrat

Methods may include emplacing a downhole tool within a wellbore, sampling a fluid downhole with the downhole tool; analyzing the fluid, and calculating an interfacial tension (IFT), wherein calculating the acid-base IFT contribution comprises measuring a concentration of a surface-active species directly. Apparatuses for measuring an interfacial tension (IFT) in a fluid downhole may be part of a downhole tool and may include a sampling head to sample the fluid; and a downhole fluid analysis module that includes a spectrometer capable of measuring a concentration of a surface-active species in the fluid, and a processor configured to determine the IFT of the fluid downhole based on the measured concentration of the surface-active species.

Method to predict downhole reservoir fluids interfacial tension

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

The current application discloses methods and systems to analyze on-site and in real-time or quasi real-time the composition of the well fluid before or during use or disposition. The method is based on capillary electrophoresis (CE) and does not require the addition of tracers into the well fluid or additive. Based on the significance of each additive on the well fluid properties, it can be decided to determine the concentration of all additives or only one or a limited number of the additives present in the fluid, and the concentrations can be adjusted as needed to reach the desired target concentration(s).

Simultaneous analysis of multiple components in well fluids

An optical sensor and corresponding method of operation can detect a phase transition and/or related property of a hydrocarbon-based analyte. The optical sensor includes an optical element with a metallic film coupled or integral thereto, with a sample chamber holds the hydrocarbon-based analyte such that the hydrocarbon-based analyte is disposed adjacent the metallic layer. The optical sensor further includes a light source configured to direct light through the optical element such that the light is reflected by the metallic layer under conditions of surface plasmon resonance. The optical sensor analyzes the reflected light to detect a phase transition and/or related property of a hydrocarbon-based analyte.

Optical sensors using surface plasmon resonance to determine at least one property relating to phase change of a hydrocarbon-based analyte

A method and apparatus for analyzing solubility of asphaltenes of a hydrocarbon fluid sample involves a sequence of operations including: i) performing microfluidic mixing operations that form a mixture that includes the hydrocarbon fluid sample, a solvent that dissolves asphaltenes and a precipitant that precipitates asphaltenes; ii) using microfluidic processes that result in precipitation of asphaltenes from the mixture resulting from i); iii) performing microfluidic filtering operations that remove precipitated asphaltenes resulting from ii) and passes permeate; and iv) performing optical spectroscopy on the permeate resulting from iii). The operations of i)-iv) can be repeated over iterations that vary the amount of solvent relative to the precipitant in the mixture. These iterations can cause varying fractional precipitation of asphaltenes in each given iteration.

Automated method and apparatus to characterize solubility of asphaltenes of a hydrocarbon fluid sample utilizing microfluidics

A method of fluid testing includes pressurizing a fluid testing system, disposed at a subterranean location under high pressure compared to a surface pressure, to achieve a desired pressure differential between the high pressure and an internal pressure of the fluid testing system. The fluid testing system includes a capillary electrophoresis system and one or more test fluid reservoirs. The method also includes directing test fluid from the one or more test fluid reservoirs into capillaries to condition the capillaries. The method further includes directing sample fluid into the capillaries for testing while at the subterranean location.

Capillary electrophoresis for subterranean applications

A method improves the capability for testing a fluid sample, e.g. testing a reservoir sample of hydrocarbon fluid. The methodology comprises positioning a capillary electrophoresis system within an enclosed chamber system. The enclosed chamber system preserves the desired downhole reservoir conditions during testing of the reservoir sample. In some applications, the reservoir sample is divided into a plurality of capillaries of the capillary electrophoresis system to enable testing of the reservoir sample with different types of detectors in one capillary electrophoresis system. The method can also be applied to depressurized reservoir samples.

Capillary electrophoresis for reservoir fluid analysis at wellsite and laboratory

In order to determine a volume thermal expansion coefficient of a liquid, a sample of the liquid is placed inside a cell of a calorimeter followed by an incremental increase of pressure inside the cell containing the liquid. After each pressure increase heat flow into the cell and volume of the liquid are measured. Based on results of the measurements of the heat flow and accounting for initially evaluated cell volume, the volume thermal expansion of the liquid is determined.

Method for determining a volume thermal expansion coefficient of a liquid

Growing community of inventors

Edmonton, Canada

Simon Ivar Andersen