Halliburton Energy Services, Inc.

Gas Research Institute

Halliburton Company

Halliburton Logging Services, Inc.

Shell International Exploration & Production B.v.

Harriburton Company

Thomas E Ritter

James Robert Birchak

Mark Anton Proett

John W Minear

James E Masino

Wei Han

Batakrishna Mandal

Bruce H Storm, Jr

Michael Thomas Pelletier

Diederik W Van Batenburg

William F Trainor

Kwang M Yoo

Wilson C Chin

Ali Mese

Daniel P Kusmer

Jeroen J Groenenboom

Pedro Zuiderwijk

Peter Van Der Sman

Ferdinand Van Der Bas

Roger Lynn Schultz

Vimal Vinod Shah

James W Stroud

Mack H Brown

Curtis M Vickery

Dan Kusmer

Robert Birchak

An example apparatus for generating acoustic waves is disclosed. The example apparatus includes a housing, and at least one plate having a moment arm, wherein each plate couples to the housing. The example apparatus for generating acoustic also includes at least one axial driver coupled to each moment arm, wherein each axial driver aligns with a longitudinal axis of the housing.

Apparatuses for generating acoustic waves

A method for generating acoustic waves, the method having the steps of: extending a tine from a support structure so that a proximal end of the tine is attached to the support structure and a distal end of the tine is uninhibited; positioning an oscillator so as to be supported by the support structure and to mechanically communicate with the tine; and oscillating the tine with the oscillator.

Acoustic stimulation method with axial driver actuating moment arms on tines

An apparatus for generating acoustic waves, the apparatus having: a support structure; two tines extending from the support structure so that proximal ends of the two tines are attached to the support structure so that distal ends of the two tines are positioned with standoffs relative to a dimension of the support structure and the distal ends of the two tines are uninhibited, wherein the two tines each comprise a moment arm; and an oscillator in mechanical communication with the two tines.

Acoustic stimulation tool with axial driver actuating moment arms on tines

A method and apparatus for in-situ characterization of downhole fluids in a wellbore using ultrasonic acoustic signals. Measurements of the speed of sound, attenuation of the signal, and acoustic back-scattering are used to provide qualitative and quantitative data as to the composition, nature of solid particulates, compressibility, bubble point, and the oil/water ratio of the fluid. The tool generally comprises three sets of acoustic transducers mounted perpendicular to the direction of the flow. These transducers are capable of operating at different frequencies so that the spectrum of the acoustic signal can be optimized. The apparatus is capable of operating downhole to provide real time information as to conditions in the well.

Acoustic sensor for fluid characterization

A downhole tool and method for determining the viscosity of a reservoir fluid, the tool including a passage having entry, intermediate and exit regions, in which the reservoir fluid flowing through the passage will have a lower Reynolds number in the intermediate region as compared to the entry region, the tool also including differential pressure gauge for measuring the differential pressure across the intermediate region, and either a velocity controller or fluid velocity meter, for either setting or measuring the fluid velocity.

Method and apparatus for determining fluid viscosity

A measurement device is provided that determines fluid properties from vibration frequencies of a sample cavity and a reference cavity. In one embodiment, the measurement device includes a sample flow tube, a reference flow tube, vibration sources and detectors mounted on the tubes, and a measurement module. The sample flow tube receives a flow of sample fluid for characterization. The reference flow tube is filled with a reference fluid having well-characterized properties. The measurement module employs the vibration sources to generate vibrations in both tubes. The measurement module combines the signals from the vibration detectors on the tubes to determine properties of the sample fluid, such as density, viscosity, compressibility, water fraction, and bubble size. The measurement module may further detect certain flow patterns such as slug flow, for example. To measure the sample fluid density, the measurement module determines the difference between resonance frequencies of the sample flow tube and the reference flow tube. The density can then be calculated according to a formula. Other fluid properties may be determined from the sample tube's resonance peak amplitude, peak width and/or peak shape. Variation of the density measurements may be used to detect and characterize multiple phase fluid flow. The use of a reference tube in the disclosed measurement device is expected to greatly enhance the accuracy and reliability of the measurement device over a range of temperatures, pressures, and shock accelerations such as those that may be found downhole in a well.

Downhole densitometer

A fluid property monitor includes a transducer assembly to impart multiple frequency energy to a conduit in one or more modes and to receive resonant frequency energy from the conduit. The resonant frequency energy is responsive to the imparted energy, the conduit and a fluid in the conduit. The fluid property monitor can also be defined as including: a frequency signal generator connected to cause multiple frequency energy to be transferred to a conduit having a fluid to be monitored; and a spectral analysis signal processor connected to receive and process electrical signals generated in response to vibrations propagated through the conduit and the fluid in the conduit in response to transferred multiple frequency energy. Particular implementations can be adapted as a densitometer, a coherent flow detector, and other particular fluid parameter detectors. A method of monitoring a fluid includes: imparting multiple frequency vibration-inducing energy to a conduit and fluid system; and sensing a plurality of frequency signals from the conduit and fluid system responsive to at least part of the imparted multiple frequency vibration-inducing energy. This method can also include determining at least one characteristic of the conduit and fluid system in response to the sensed plurality of frequency signals.

Vibrational forced mode fluid property monitor and method

A transducer configuration for use in acoustically imaging a target region behind an acoustically reflective layer includes a sonde having a geometrical center and constructed and arranged to support a plurality of transducers. The system includes a first transducer disposed within the sonde at a first distance from the geometrical center for generating a first acoustic pulse and for receiving a first acoustic signal. The acoustic signal comprises a first reflection from the reflective surface, a first set of fluid multiples arising from reflections between the reflective layer and a surface of the first transducer, and a first signal associated with the target area. The system also includes a second transducer disposed within the sonde at a second distance from the geometrical center for generating a second acoustic pulse and for receiving a second acoustic signal. The second acoustic comprises a second reflection from the reflective surface, a second set of fluid multiples arising from reflections between the reflective layer and a surface of the second transducer and a second signal associated with the target area. A mechanism for receiving and processing signals received by the first and second transducers at time intervals which occur between receipt of the first and second sets of fluid multiples, respectively, wherein signal values at time intervals between receipt of fluid multiples provide acoustic waveforms associated with the target region. Each target region, therefore, has a time interval on at least one of the two waveforms which is free of fluid multiples.

System and method for providing dual distance transducers to image

A sonic or acoustic tool is disclosed which includes a transmitter with reduced transmitter spawned noise. The transmitters are either monopole or dipole depending on the orientation of ports in a chamber divided by a piston driven by an actuator. The transmitter size is limited only by the diameter of the tools itself because the transmitters are oriented within the tool parallel to the axis of the tool.

Dipole/monopole acoustic transmitter, methods for making and using same

A transducer configuration of an acoustic sensing tool for determining the consistency of a first medium disposed between a layer having a greater acoustic reflectivity than the first medium and a second medium, the sensing tool including a rotating head, wherein the tool comprises first, second and third transducer pairs in a spaced apart configuration, each pair comprising a transmitting transducer for transmitting an acoustic radiation signal in an insonified zone, and receiving transducer having a receiving radiation pattern in a insonified zone, wherein the space between the transmitting and receiving transducers in each pair is constructed and arranged to allow the transmitting and receiving insonified zones to intersect behind but not in the acoustically reflective layer to null reverberation energy therefrom. The tool also includes a centerline of radiation from each transmitting transducer that propagates and refracts through the reflective layer such that all transmitting centerlines intersect in an intersection near voxel, wherein the intersection voxel is interrogated by all three transducer pairs substantially simultaneously at nearly a single azimuthal head position, such that any occlusion is interrogated from three different directions, thereby facilitating determination of occlusion surface orientation.

Transducer configuration having a multiple viewing position feature

A transducer configuration disposed within a wellbore sonde for acoustically imaging a target region behind an acoustically reflective layer includes a transmitting transducer for producing a transmitted acoustic beamspread pattern defined by a insonified zone having a width approximately equal to a width of the transmitting transducer and a transmitting main lobe beyond the transmitting collimated zone. The transducer configuration also includes a receiving transducer disposed adjacent the transmitting transducer. The receiving transducer includes an acoustic signal reception pattern defined by a insonified zone having a width approximately equal to a width of the receiving transducer and a receiving main lobe beyond the receiving insonified zone. A beamspread angle defines an amplitude contour forming an outer periphery of the transmitting and receiving main lobes. Intersection of the transmitting and receiving main lobes behind but not within an acoustically reflective layer allows the transducer configuration to null reverberation energy from the acoustically reflective material and enhance acoustic energy received from the less reflective material disposed behind the highly reflective material.

Sensor configuration for nulling reverberations to image behind

A system for acoustically imaging a target region behind an acoustically reflective layer includes a transducer configuration for acquiring acoustic image data from the reflective layer and target region, wherein the reflective layer and target region are divided into voxels circumferentially disposed about a central point. The system includes a mechanism for processing the data comprising a transmitting transducer for transmitting a first acoustic pulse, a receiving transducer for detecting a first arrival of a first acoustic reflection signal associated with the first acoustic pulse, and a mechanism for suppressing multiple reflected signals from the acoustic reflection signal associated with the first acoustic pulse, wherein the suppressing mechanism facilitates the acquisition of image data from the target region. The system may also include a mechanism which filters and compresses acoustic data downhole, transmits data uphole and which reassembles data uphole for conversion into an image on standard computer display equipment.

System and method for processing acoustic signals to image behind

An apparatus for logging a borehole comprises a non-rotating component and a rotating component that is flexibly attached to the non-rotating component and includes a logging head. The rotating component is centralized independently from the non-rotating component such that the rotating component remains centralized as it rotates, regardless of whether the non-rotating component is centralized. The logging head includes at least one signaling device, a hydrostatic pressure balancing system, a sealed, variable-volume fluid reservoir in fluid communication with said transducer, and a motor housed in said logging head for rotating the rotating component. The apparatus can further include a second non-rotating component suspended below the rotating component.

Growing community of inventors

Katy, TX, United States of America

Thomas E Ritter