Halliburton Energy Services, Inc.

Other

Robert S Atkinson

Christopher Michael Jones

Michael Thomas Pelletier

Wei Zhang

David L Perkins

Li Gao

Hua Xia

William Joseph Soltmann

Jing Shen

Mark Anton Proett

Dingding Chen

Darren George Gascooke

Lizheng Zhang

Nathan James Harder

Nestor Rodriguez

Stephen A Zannoni

Songhua Chen

Bin Dai

Anthony Herman Van Zuilekom

Robert J Murphy

Marian Morys

Gary Dean Althoff

Raj Pai

Tian He

Jimmy W Anders

Mahaly Randrianavony

Jim W Stoddard

A device and method is described to parallelize a pressure-volume-temperature ('PVT') analysis using gas chromatography and mass spectrometry techniques such that a portion of the pressure, temperature and volume analysis is performed separately from others. The resulting PVT data is then recombined statistically for a complete PVT analysis. The device may also obtain compositional data of the fluid to perform an equation of state analysis or reservoir simulations.

Device and method for parallel pressure-volume-temperature analysis using gas chromatography and mass spectrometry

A downhole formation fluid identification sensing module for measuring averaged gas molecular weight of wellbore formation fluid acquires simultaneous temperature, pressure, and density measurements. The sensing module includes two venturi-type gas sensors that both contain vibrating tubes. During operation, formation fluid flows through the vibrating tubes whereby resonant frequency measurements are acquired simultaneously with temperature and pressure measurements. Each measurement is then utilized to determine the gas molecular weight of the dry, wet or saturated formation fluid.

Thermal modulated vibrating sensing module for gas molecular weight detection

Methods and systems for monitoring material loss in a downhole environment arising from corrosion and/or erosion include placing a downhole sensor in a borehole. The resistance of the downhole sensor is measured using a four-probe resistance technique in which a power source is provided at two electrodes of the downhole sensor and voltage is measured at two voltage taps. A rise in voltage over time indicates loss of conductive material on the downhole sensor. The conductive material on the downhole sensor may be formed to provide discrete voltage increases for improving reliability of material loss and/or rate of material loss resistance measurements.

Method and device for downhole corrosion and erosion monitoring

A downhole formation fluid viscometer sensor and method therefor include a viscometer sensing package, a flexible diaphragm, a magnet and electric coil, and a signal pickup assembly. The viscometer sensor may also include a first cavity and a second cavity for mechanical and electric energy transfer. The magnet and electric coil may be driven by external alternating current to generate an electromagnetic force. Silicon oil may be used to fill the first cavity and/or a pressure balance hole may connect the first cavity to an external area. The diaphragm may be a titanium alloy and a ferromagnetic magnet may be attached to the diaphragm. The diaphragm preferably has a thickness from about 0.030 to about 0.040 inches and the magnet and electric coil can propel the diaphragm to vibrate at a frequency from 0 to 100 kHz. Formation fluid viscosity is determined using resonant frequency linewidth, with contributions from the sensor package intrinsic properties removed.

Downhole formation fluid viscometer sensor

An optical analysis tool includes an integrated computational element (ICE). The ICE includes a first hollow-core fiber. The first hollow-core fiber has a structure configured such that a spectrum of light guided by the first hollow-core fiber is related, over a wavelength range, to a characteristic of the sample.

Band-limited integrated computational elements based on hollow-core fiber

In some embodiments, an apparatus and a system, as well as a method and an article, may operate to terminate sampling of fluid into one of a set of fluid sampling chambers sharing a common inflow sampling line by operating a set of closure mechanisms. Further activity may include initiating sampling of the fluid into another one of the set of fluid sampling 5 chambers, wherein the fluid sampling chambers are configured to sample the fluid in the sampling line in a selected sequence, such that filling a prior fluid sampling chamber as part of the sequence enables sampling in the next fluid sampling chamber as part of the sequence, and wherein the closure mechanisms comprise individual check valves 10 and a common diversion valve or individual diversion valves. Additional apparatus, systems, and methods are disclosed.

Selectable size sampling apparatus, systems, and methods

A method of calibration transfer for a testing instrument includes: collecting a first sample; generating a standard response of a first instrument based, at least in part, on the first sample; and performing instrument standardization of a second instrument based, at least in part, on the standard response of the first instrument. Data corresponding to a second sample is then obtained using the second instrument and a component of the second sample is identified based, at least in part, on a calibration model.

Methods of calibration transfer for a testing instrument

A downhole sensor package for detecting one or more thermophysical properties of a downhole fluid, comprising a sensor housing having a fluid input port and a fluid output port; an inner flow tube located within and axially defined with the sensor package housing; an outer flow annulus defined between the inner flow tube and the sensor housing, wherein the inner flow tube is in fluid communication with the outer flow annulus; and a vibration source and a vibration detector engaging the inner flow tube; and methods for using the same are disclosed.

Downhole sensor for formation fluid property measurement

Various embodiments include systems and methods to provide selectable variable gain to signals in measurements using incident radiation. The selectable variable gain may be used to normalize signals modulated in measurements using incident radiation. The selectable variable gain may be attained using a number of different techniques or various combinations of these techniques. These techniques may include modulating a modulator having modulating elements in which at least one modulating element acts on incident radiation differently from another modulating element of the modulator, modulating the use of electronic components in electronic circuitry of a detector, modulating a source of radiation or combinations thereof. Additional apparatus, systems, and methods are disclosed.

Variable modulation of radiation and components

Described herein are devices, systems, and methods for analyzing multi-phase fluid flow profile and flow field distribution by utilizing heating wires and thermal sensing arrays to detect transient thermal response and generate a dynamic temperature profile. The thermal sensing arrays include a plurality of thermal sensors disposed linearly along the length of the array. The multi-point dynamic temperature profile is used to determine fluid rate, velocity, flow patterns, and flow field distribution.

Multi-phase fluid flow profile measurement

Disclosed are robust packaging systems and methods for optical elements used in optical light pipes. One optical light pipe includes a housing having opposing first and second ends and a body that extends therebetween, an optical element arranged within the housing, and a reflective coating applied about an outer surface of the optical element.

Packaging systems and methods for optical light pipes

Downhole fluid sensing device is disclosed for determining heat capacity of a formation fluid produced by a sampled subterranean well, the sensor package having an annulus shaped, elongate body defining a cylindrical fluid sampling space, the sensor package and the sampling space having a common longitudinal center axis. The elongate sensor package body has a fluid entrance port that provides well fluid ingress into the fluid sampling space and a fluid exit port that provides well fluid egress out of the fluid sampling space. A heat source is coupled to the elongate sensor package body and located along a portion of the fluid path, and the heat source inputs heat into sampled well fluid. Finally, temperature sensing devices (located between the fluid entrance port and fluid exit port measure heat conducted to the sampled well fluid, wherein each of the temperature sensing devices is radially spaced from the heat source.

Identification of heat capacity properties of formation fluid

A downhole well fluid sensing device is disclosed for determining thermal conductivity of a formation fluid produced by a sampled subterranean well, the sensor package having an annulus shaped, elongate body defining a cylindrical fluid sampling space, the elongate body and the sampling space having a common longitudinal center axis. The elongate body has a fluid entrance port that provides well fluid ingress into the fluid sampling space and a fluid exit port that provides well fluid egress out of the fluid sampling space. A heat source is coupled to the elongate body and located along a portion of the fluid path, and the heat source inputs heat into sampled well fluid. Finally, temperature sensing devices located between the fluid entrance port and fluid exit port measure heat conducted to the sampled well fluid, wherein each of the temperature sensing devices is radially spaced from the heat source.

Identification of thermal conductivity properties of formation fluid

An optical element devices and method are described herein. An example optical device may include an optical element. The optical element may have an optical path material to allow a light to pass therethrough. The optical path material may have a first end portion with a first end surface, a second end portion with a second end surface, and a middle portion between the first and second end portions with an interior and an exterior surface. A coating may be disposed along the exterior surface and diffused into the optical path material. The coating may minimize leakage of the light from the interior through the exterior surface.

Protective coating for optical elements

A method and apparatus for aligning optical components within an optical sensor. A mask with an elongate slot formed therethrough is placed optically between an optical emitter and an optical detector of the sensor. The mask is rotated 180 degrees while the detector output is measured. As the mask is rotated, the output varies. The longitudinal position of the slot that corresponds with the maximum detector output is indicative of the transverse direction that the optical emitter must be moved relative to the optical detector for optimal alignment. A controller may operate a first actuator for translating the optical emitter with respect to the optical detector and a second actuator for rotating the mask, thereby automating the alignment process.

Growing community of inventors

Richmond, TX, United States of America

Robert S Atkinson