Saudi Arabian Oil Company

Exxonmobil Upstream Research Company

Jose Oliverio Alvarez

Sebastian Csutak

Max Deffenbaugh

Sunder Ramachandran

Damian Pablo San Roman Alerigi

Huseyin Rahmi Seren

Adrian Cesar Cavazos Sepulveda

Miguel Gonzalez

Christopher Powell

Gregory D Ham

Gregory Bernero

Sameeh Issa Batarseh

David J Jacobi

Michael Thomas Hecker

Ted Alan Long

Scott R Clingman

System and methods for analyzing a multiphase production fluid, calculating production fluid phase flow rates, and calculating an oil/gas and oil/gas/water volume fractions of the multiphase production fluid, are provided. Contemplated systems and method may utilize fluidic piping, a production fluid supply valve, a fluidic separation chamber, an inert gas exhaust valve, a separation chamber pressure sensor, a fluidic separation detector, and a fluidic supply and analysis unit.

Systems and methods for analyzing multiphase production fluids utilizing a vertically oriented fluidic separation chamber

A method of detecting an increase in gas content in a pipe. The method includes flowing fluid through the pipe. The method includes generating, by a network analyzer, microwaves data representing a complex scattering coefficient over a first spectrum of microwave frequencies that are emitted through a waveguide and a fluid within the pipe and determining a statistical profile of a complex scattering magnitude over a second spectrum of microwave frequencies. The method includes determining that an amount of gas within the pipe satisfies a threshold amount and causing a flow of fluids within the pipe to slow or stop until the amount of gas falls below a predetermined threshold value.

Real-time detection of gas kicks during drilling and gas cap gas intrusion during oil production

An apparatus, method, and system for monitoring wellbore deformation is disclosed. The apparatus includes an expandable annular cylindrical packer and a plurality of assemblies mounted on an exterior circumferential surface of the packer. The plurality of assemblies are configured to be pressed against a wellbore surface by the packer. Each of the assemblies includes at least one fiber-optic coil embedded in a sheet of deformable substrate, a tray-shaped receptacle formed from a low thermal conductivity material and attached along the rim to an edge of the sheet with a pressure tight-seal, and an optical coupler configured to couple the fiber-optic coil to a fiber-optic cable. The assemblies further include a pressure-tight compartment containing a high-pressure inert gas that is formed by the receptacle, the sheet, and the seal.

Distributed fiber sensing in a packer for permanent casing and formation deformation monitoring

System and methods for analyzing a multiphase production fluid include a fluidic supply and analysis unit configured to transition the fluidic separation chamber to a static state after a complete gaseous phase column and a complete oil phase column are formed within the fluidic separation chamber; communicate with the fluidic separation detector to measure the absolute or relative sizes of the complete gaseous phase column and the complete oil phase column; and calculate an oil/gas volume fraction as a function of the measured sizes of the gaseous phase and oil phase columns in the fluidic separation chamber.

Systems and methods for volume fraction analysis of production fluids utilizing a vertically oriented fluidic separation chamber

A system for monitoring a composition includes: an electromagnetic source that emits a beam; one or more evanescent field sensing element inside a tubular structure, arranged in series along a flow direction of the composition, and configured to be in direct contact with the composition; a waveguide that directs at least a portion of the beam to the evanescent field sensing element as an incident beam; and a detector configured to obtain a spectral distribution of the fingerprint beam. The evanescent field sensing element provides partial or total internal reflection of the incident beam at an interface between the evanescent field sensing element and the composition, and the incident beam interacts with the composition to form a fingerprint beam.

In-situ monitoring of chemical fingerprints in oilfield applications

Embodiments of the invention provide an untethered apparatus for measuring properties along a subterranean well. According to at least one embodiment, the untethered apparatus includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered apparatus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

Method and device for obtaining measurements of downhole properties in a subterranean well

A monitoring device monitors deformation of a casing installed in a wellbore and housing a production tubing, and includes: a packer installed within an annulus between the casing and the production tubing; a deformable substrate that is disposed at an outer side of the annulus and contacts an inner surface of the casing to deform along with casing deformation; a light source that is disposed on the deformable substrate and emits light towards an inside of the annulus; an imaging device that is disposed in the packer to be opposite to the light source across the annulus and detects the light emitted from the light source; and a processor that produces a signal from the detected light, processes the produced signal, and transmits the processed signal to a surface control device that monitors the deformation of the casing based on the signal.

Deformation monitoring mechanism with multi-pixel angle-sensitive laser ranging

Systems and methods for analyzing multiphase production fluids utilizing a vertically oriented fluidic separation chamber comprising an optically transparent pipe

Systems and methods for volume fraction analysis of production fluids utilizing a vertically oriented fluidic separation chamber comprising an optically transparent pipe

A system for looking ahead of a drill bit includes a plane wave generator (PWG) tool deployed downhole inside a wellbore for formation evaluation and generation of reflection data, a power source providing electric power to the PWG tool for the formation evaluation and the generation of the reflection data, a surface control system receiving the reflection data from the PWG tool and generating image data of a subsurface rock formation based on the received reflection data, and a wireline that electrically couples the PWG tool to the power source and communicatively couples the PWG tool to the surface control system. The PWG tool includes a beam forming network (BFN) architecture and a plurality of antenna elements mounted to a base of the PWG tool to transmit and receive electromagnetic signals.

Method and apparatus for looking ahead of the drill bit

A system includes a housing configured to be secured to the casing string. The housing has a ring shape defining a central orifice for passage of the fluid and an interior surface facing the central orifice. A reflectometer is mounted on the interior surface and is configured to emit a microwave signal into the fluid in the central orifice, receive a reflected microwave signal from the central orifice, and determine a microwave reflection parameter. An acoustic transceiver is also mounted on the interior surface and is configured to emit an acoustic signal into the fluid in the central orifice, receive a reflected acoustic signal from the central orifice, and determine an acoustic reflection parameter. A processor is configured to determine the property of the fluid from the microwave reflection parameter and the acoustic reflection parameter.

Downhole apparatus to determine microwave and acoustic properties of circulating drill mud

The present disclosure describes methods and systems, including computer-implemented methods, computer program products, and computer systems, for measuring a water cut for hydrocarbon fluid in a production pipe. One method includes transmitting a microwave through a first waveguide attached to a production pipe, wherein the microwave is directed to the hydrocarbon fluid in the production pipe; and obtaining, measurement results based on reflection or propagation of the microwave, wherein the measurement results are used to determine a water cut of the hydrocarbon fluid.

Measuring a water cut of hydrocarbon fluid in a production pipe

An untethered apparatus for measuring properties along a subterranean well includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered apparatus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

Embodiments of the disclosure provide a method of determining the presence of a hydrocarbon in an aqueous medium used for secondary oil recovery. The method includes the step of introducing the aqueous medium into a subterranean hydrocarbon formation to displace hydrocarbons. The method includes the step of retrieving an aqueous sample from the aqueous medium introduced into the subterranean hydrocarbon formation. The method includes the step of cooling the aqueous sample such that the aqueous sample is in a solid state. The method includes the step of exposing the aqueous sample to an electromagnetic wave at a microwave frequency such that a scattering response is induced from the hydrocarbon included in the aqueous sample. The method includes the step of determining permittivity of the hydrocarbon based on the scattering response.

Method for measuring oil in water using multi-frequency microwave measurements

A pressure cell system includes a pressure cell configured to house a sample within inner walls of the pressure cell. An injectable medium is injected by an injection system of the pressure cell system into the pressure cell in a gap between the sample and the inner walls. The injectable medium in the pressure cell is heated by a heating element of the pressure cell system. A pressure inside the pressure cell is measured by a pressure gauge of the pressure cell system. A temperature in the pressure cell is measured by a temperature gauge of the pressure cell system. Microwave permittivity measurements of the sample are captured by a coaxial resonator system of the pressure cell system. The microwave permittivity measurements of the sample are captured at different combinations of temperatures and pressures. The microwave permittivity measurements include measurements of permittivity of gas under pressure at plural frequencies.

Growing community of inventors

Houston, TX, United States of America

Jose Oliverio Alvarez