Patents by Inventor Mark A. Proett
Mark A. Proett has filed for patents to protect the following inventions. This listing includes patent applications that are pending as well as patents that have already been granted by the United States Patent and Trademark Office (USPTO).
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Publication number: 20050216196Abstract: Methods and systems are described for estimating of the level of contamination of downhole fluid using physical property measurements, and mathematical modeling of contamination functions and fluid property mixing laws. The proposed approaches enable computation of estimates of the pumping time needed to achieve a certain contamination threshold level.Type: ApplicationFiled: December 23, 2004Publication date: September 29, 2005Inventors: Ridvan Akkurt, Mark Proett
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Patent number: 6932167Abstract: A compression scheme for reducing the amount of data that must be transmitted uplink from a formation test while drilling apparatus. Periodic samples are taken within the formation test apparatus and prior to transmitting data uplink, the samples are analyzed to generate curve fit parameters that define a curve that most closely fits the sampled data. A minimal set a data points, time variables, and curve fit parameters are transmitted to the surface where the transmitted data is used to reconstruct the formation pressure test curve. A quality of fit value is also transmitted with the minimal data set as an indication of the quality of the fit between the reconstructed data and the actually sampled data points.Type: GrantFiled: May 19, 2003Date of Patent: August 23, 2005Assignee: Halliburton Energy Services, Inc.Inventors: Mark A. Proett, Preston N. Weintraub, Christopher A. Golla, Svetozar D. Simeonov
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Patent number: 6912904Abstract: A measurement device is provided that determines fluid properties from vibration frequencies of a sample cavity. In one embodiment, the measurement device includes a sample flow tube, vibration source and detector mounted on the tube, and a measurement module. The sample flow tube receives a flow of sample fluid for characterization. The measurement module employs the vibration sources to generate vibrations in the tube. The measurement module combines the signals from the vibration detector on the tube 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 resonant frequency of the sample flow tube. The density can then be calculated according to a formula that compensates for the temperature and pressure of the system.Type: GrantFiled: December 5, 2003Date of Patent: July 5, 2005Assignee: Halliburton Energy Services, Inc.Inventors: Bruce H. Storm, Jr., James Masino, Mark A. Proett, Michael T. Pelletier
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Publication number: 20050116709Abstract: System and methods for estimating properties of a geologic formation are disclosed. A preferred embodiment includes a method for estimating properties of a geologic formation, comprising the steps of: measuring a property of the formation in two or more directions along a path in the formation; obtaining directional property values for at least one spatial unit along the path in the formation based on the property measurements; and providing an anisotropy estimate of the formation from the obtained directional property values.Type: ApplicationFiled: October 1, 2004Publication date: June 2, 2005Inventors: Mark Proett, James Fogal, Wilson Chin, Prabhakar Aadireddy
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Patent number: 6843118Abstract: The present invention is directed to methods and apparatus for using a formation tester to perform a pretest, in a formation having low permeability, by intermittently collecting a portion of fluid at a constant drawdown rate. The drawdown pressure is monitored until a maximum differential pressure is reached between the formation and the tester. Then the piston is stopped until the differential pressure increases to a set value, at which time the piston is restarted. The controlled intermittent operation of the piston continues until a set pretest volume is reached. The modulated drawdown allows for an accurate collection of pressure versus time data that is then used to calculate the formation pressure and permeability. The present invention also finds applicability in logging-while-drilling and measurement-while drilling applications where power conservation is critical.Type: GrantFiled: March 8, 2002Date of Patent: January 18, 2005Assignee: Halliburton Energy Services, Inc.Inventors: Preston N. Weintraub, Pedro R. Segura, Mark A. Proett
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Publication number: 20040254732Abstract: A method for determining the composition of a fluid by using measured properties of the fluid. One embodiment of the method of the current invention generally comprises: selecting a fluid property that has a response to fluid composition that is linear, or can be approximated as linear; measuring the selected fluid property at a series of specific time intervals; and plotting the measured property as a function of the selected property. In effect, plotting the measured property as a function of fluid composition in an arbitrary set of units. This allows for a in-situ qualitative evaluation of fluid composition by measuring a fluid property that has a known linear relationship to fluid composition. Another embodiment of the present invention further comprises, establishing the endpoints of contamination and plotting the measured properties through these endpoints. Once the endpoints have been established a quantitative evaluation of the fluid composition can be performed.Type: ApplicationFiled: June 7, 2004Publication date: December 16, 2004Applicant: Halliburton Energy Services, Inc.Inventors: Bruce H. Storm, Mark A. Proett, Michael T. Pelletier
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Publication number: 20040230378Abstract: Methods for operating multi-probed formation testers to determine a fluid density gradient in the formation. The probes of the multi-probed formation tester are connected to a pressure gauge through a flowline that establishes a differential height between the probes. In some embodiments, a gradient of the fluid density in the flowline is determined as a function of the gradient of fluid density in the wellbore. The flowline fluid density gradient is then used to determine a formation fluid density gradient as a function of the flowline fluid density gradient.Type: ApplicationFiled: May 3, 2004Publication date: November 18, 2004Applicant: Halliburton Energy Services, Inc.Inventors: Mark A. Proett, Gregory N. Gilbert, David E. Ball
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Patent number: 6807857Abstract: The current invention provides a process and apparatus for determining the density of a flowing fluid without requiring knowledge of the fluid's Theological properties. The process of the current invention is capable of providing continuous “real time” analysis of fluid density. The apparatus of the current invention comprises at least two pressure assessment zones fitted with fluid pressure sensing points. Pressure sensing devices connected to the pressure sensing points provide the data necessary to enable the calculation of fluid density.Type: GrantFiled: June 5, 2002Date of Patent: October 26, 2004Assignee: Halliburton Energy Services, Inc.Inventors: Bruce H. Storm, Jr., Mark A. Proett
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Patent number: 6799117Abstract: Systems and methods for estimating properties of fluid samples pumped from a formation through a well are described. Based upon input properties, an artificial neural network (ANN) may predict a plurality of data points, and each data point may correspond to a predicted time sample of the property of the fluid sample. Properties predicted by the ANN include sample quality or pumping pressure differential.Type: GrantFiled: May 28, 2003Date of Patent: September 28, 2004Assignee: Halliburton Energy Services, Inc.Inventors: Mark A. Proett, Jianghui Wu, James M. Fogal, Madan Mohan Manohar
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Publication number: 20040173351Abstract: Systems and methods for downhole formation testing. The invention is based on the use of one or more elongated sealing pads capable of sealing off and collecting or injecting fluids from elongated portions along the surface of a borehole. The, modified probe pads of a device-made in accordance with the invention increase the flow area by collecting fluids from an extended portion along the surface of a borehole, which is likely to straddle one or more layers in laminated or fractured formations. A tester device using the elongated sealing pads is capable of fast deployment and withdrawal to speed up the measurement cycles. Various designs and arrangements for use with a fluid tester, which may be part of a modular fluid tool, are disclosed in accordance with different embodiments.Type: ApplicationFiled: March 7, 2003Publication date: September 9, 2004Inventors: Philip Edmund Fox, Michael E. Shade, Gregory N. Gilbert, Mark A. Proett
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Publication number: 20040123645Abstract: A measurement device is provided that determines fluid properties from vibration frequencies of a sample cavity. In one embodiment, the measurement device includes a sample flow tube, vibration source and detector mounted on the tube, and a measurement module. The sample flow tube receives a flow of sample fluid for characterization. The measurement module employs the vibration sources to generate vibrations in the tube. The measurement module combines the signals from the vibration detector on the tube 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 resonant frequency of the sample flow tube. The density can then be calculated according to a formula that compensates for the temperature and pressure of the system.Type: ApplicationFiled: December 5, 2003Publication date: July 1, 2004Inventors: Bruce H. Storm, James Masino, Mark A. Proett, Michael T. Pelletier
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Patent number: 6755079Abstract: 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.Type: GrantFiled: March 27, 2000Date of Patent: June 29, 2004Assignee: Halliburton Energy Services, Inc.Inventors: Mark A. Proett, Michael T. Pelletier, Wei Han, Bruce H. Storm, Jr., Roger L. Schultz, Thomas E. Ritter
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Patent number: 6748328Abstract: A method for determining the composition of a fluid by using measured properties of the fluid. One embodiment of the method of the current invention generally comprises: selecting a fluid property that has a response to fluid composition that is linear, or can be approximated as linear; measuring the selected fluid property at a series of specific time intervals; and plotting the measured property as a function of the selected property. In effect, plotting the measured property as a function of fluid composition in an arbitrary set of units. This allows for a in-situ qualitative evaluation of fluid composition by measuring a fluid property that has a known linear relationship to fluid composition. Another embodiment of the present invention further comprises, establishing the endpoints of contamination and plotting the measured properties through these endpoints. Once the endpoints have been established a quantitative evaluation of the fluid composition can be performed.Type: GrantFiled: June 10, 2002Date of Patent: June 8, 2004Assignee: Halliburton Energy Services, Inc.Inventors: Bruce H. Storm, Jr., Mark A. Proett, Michael T. Pelletier
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Patent number: 6729398Abstract: Methods and apparatus are provided which permit well testing operations to be performed downhole in a subterranean well. In various described methods, fluids flowed from a formation during a test may be disposed of downhole by injecting the fluids into the formation from which they were produced, or by injecting the fluids into another formation. In several of the embodiments of the invention, apparatus utilized in the methods permit convenient retrieval of samples of the formation fluids and provide enhanced data acquisition for monitoring of the test and for evaluation of the formation fluids.Type: GrantFiled: October 11, 2002Date of Patent: May 4, 2004Assignee: Halliburton Energy Services, Inc.Inventors: Paul D. Ringgenberg, Mark A. Proett, Michael T. Pelletier, Michael L. Hinz, Gregory N. Gilbert, Harold W. Nivens, Mehdi Azari
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Patent number: 6688176Abstract: A measurement device is provided that determines fluid properties from vibration frequencies of a sample cavity. In one embodiment, the measurement device includes a sample flow tube, vibration source and detector mounted on the tube, and a measurement module. The sample flow tube receives a flow of sample fluid for characterization. The measurement module employs the vibration sources to generate vibrations in the tube. The measurement module combines the signals from the vibration detector on the tube 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 resonant frequency of the sample flow tube. The density can then be calculated according to a formula that compensates for the temperature and pressure of the system.Type: GrantFiled: October 29, 2001Date of Patent: February 10, 2004Assignee: Halliburton Energy Services, Inc.Inventors: Bruce H. Storm, Jr., James Masino, Mark A. Proett, Michael T. Pelletier
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Publication number: 20030226395Abstract: The current invention provides a process and apparatus for determining the density of a flowing fluid without requiring knowledge of the fluid's Theological properties. The process of the current invention is capable of providing continuous “real time” analysis of fluid density. The apparatus of the current invention comprises at least two pressure assessment zones fitted with fluid pressure sensing points. Pressure sensing devices connected to the pressure sensing points provide the data necessary to enable the calculation of fluid density.Type: ApplicationFiled: June 5, 2002Publication date: December 11, 2003Inventors: Bruce H. Storm, Mark A. Proett
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Publication number: 20030229448Abstract: A method for determining the composition of a fluid by using measured properties of the fluid. One embodiment of the method of the current invention generally comprises: selecting a fluid property that has a response to fluid composition that is linear, or can be approximated as linear; measuring the selected fluid property at a series of specific time intervals; and plotting the measured property as a function of the selected property. In effect, plotting the measured property as a function of fluid composition in an arbitrary set of units. This allows for a in-situ qualitative evaluation of fluid composition by measuring a fluid property that has a known linear relationship to fluid composition. Another embodiment of the present invention further comprises, establishing the endpoints of contamination and plotting the measured properties through these endpoints. Once the endpoints have been established a quantitative evaluation of the fluid composition can be performed.Type: ApplicationFiled: June 10, 2002Publication date: December 11, 2003Applicant: Halliburton Energy Services, Inc.Inventors: Bruce H. Storm, Mark A. Proett, Michael T. Pelletier
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Publication number: 20030214879Abstract: A compression scheme for reducing the amount of data that must be transmitted uplink from a formation test while drilling apparatus. Periodic samples are taken within the formation test apparatus and prior to transmitting data uplink, the samples are analyzed to generate curve fit parameters that define a curve that most closely fits the sampled data. A minimal set a data points, time variables, and curve fit parameters are transmitted to the surface where the transmitted data is used to reconstruct the formation pressure test curve. A quality of fit value is also transmitted with the minimal data set as an indication of the quality of the fit between the reconstructed data and the actually sampled data points.Type: ApplicationFiled: May 19, 2003Publication date: November 20, 2003Applicant: Halliburton Energy Services, Inc.Inventors: Mark A. Proett, Preston N. Weintraub, Christopher A. Golla, Svetozar D. Simeonov
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Patent number: 6619394Abstract: A process and apparatus for treating a wellbore, comprising subjecting a substantially same portion of the wellbore to vibratory waves produced by a plurality of vibratory wave generators. The vibratory waves may have about the same frequency or a plurality of frequencies, and the frequencies may partially overlap, not overlap, or be modulated across a range. Additionally, the frequencies may be modulated in an oval, hoop, and flexural modes. The vibratory waves may be produced by firing the vibratory wave generators simultaneously or in sequence. Combinations of a vibrating pipe, piston pulser, or valve may be used as vibratory wave generators. In a preferred embodiment, the thickness and change of thickness of a mudcake on the interior surface of a wellbore are measured to evaluate the effectiveness of the wellbore treatment.Type: GrantFiled: December 7, 2000Date of Patent: September 16, 2003Assignee: Halliburton Energy Services, Inc.Inventors: Mohamed Y. Soliman, Ali I. Mese, Clark E. Robison, James R. Birchak, Paul F. Rodney, Wei Han, Vimal V. Shah, Eugene J. Linyaev, Mark A. Proett
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Publication number: 20030167834Abstract: The present invention is directed to methods and apparatus for using a formation tester to perform a pretest, in a formation having low permeability, by intermittently collecting a portion of fluid at a constant drawdown rate. The drawdown pressure is monitored until a maximum differential pressure is reached between the formation and the tester. Then the piston is stopped until the differential pressure increases to a set value, at which time the piston is restarted. The controlled intermittent operation of the piston continues until a set pretest volume is reached. The modulated drawdown allows for an accurate collection of pressure versus time data that is then used to calculate the formation pressure and permeability. The present invention also finds applicability in logging-while-drilling and measurement-while drilling applications where power conservation is critical.Type: ApplicationFiled: March 8, 2002Publication date: September 11, 2003Inventors: Preston N. Weintraub, Pedro R. Segura, Mark A. Proett