Teruhiko Hagiwara

US Patent:

6337568, Jan 8, 2002

Filed:

Apr 7, 2000

Appl. No.:

09/545353

Inventors:

Tarek A. Tutunji - Houston TX 77082
Teruhiko Hagiwara - Houston TX 77025
Peter Ian Day - Houston TX 77030

International Classification:

G01V 300

US Classification:

324303, 324300

Abstract:

An interpretation method and system for NMR echo-train data in thinly laminated sequences. The invention uses geological information obtained at higher vertical resolution, such as using Electric Micro Imaging, to enhance the vertical resolution of echo-train data, and thus avoids log interpretations in which the hydrocarbon potential of the formation can be misread because low resolution logs tend to provide an average description of the formation. Such averaging is especially problematic in thinly laminated sequences that consist of highly permeable and porous sand layers and less permeable silt or essentially impermeable shale layers. In a preferred embodiment, using the additional high-resolution formation information one can estimate the typical T -spectra of lithological laminae, and significantly enhance the permeability estimate in the laminated sequences. In another aspect the system and method of the preferred embodiment use neural network(s) to further enhance the resolution of a particular log measurement. The method and system are applicable to any temporal data from other logging tools, such as the thermal neutron decay log and others.

US Patent:

6366088, Apr 2, 2002

Filed:

Dec 3, 1999

Appl. No.:

09/454959

Inventors:

Teruhiko Hagiwara - Houston TX

Assignee:

Halliburton Energy Services, Inc. - Houston TX

International Classification:

G01V 300

US Classification:

324303, 324338, 324300

Abstract:

A method for enhancing measurement resolution is disclosed. In one embodiment, the method includes (1) obtaining multiple measurement samples at each of multiple positions along a borehole; (2) extracting reference index samples from the set of measurement samples; (3) determining a difference between each of the reference index samples and corresponding modeled index samples; and (4) updating a set of enhanced index samples based on the difference. The index samples are preferably chosen to be representative of the measurement samples obtained at each position, and accordingly, may be selected ones of the measurement samples, or alternatively, may be averages of the measurement samples. The aforementioned modeled index samples may be found from application of a predetermined tool response to the enhanced index samples, which in turn, may be found by iteration. Once the difference has been reduced below some threshold, the relationship between the enhanced index samples and the reference index samples may be used to calculate a deconvolution filter for all of the original measurement samples from the borehole. When applied to the original measurement samples, the deconvolution filter produces measurement samples having an enhanced resolution.

US Patent:

6584407, Jun 24, 2003

Filed:

Jan 10, 2001

Appl. No.:

09/757969

Inventors:

Samuel M. Haugland - Houston TX
Teruhiko Hagiwara - Houston TX
Martin Paulk - Houston TX

Assignee:

Halliburton Energy Services, Inc. - Houston TX

International Classification:

G01V 140

US Classification:

702 7, 703 10, 175 45

Abstract:

A method of compensating for tool motion is disclosed. In one embodiment, the method includes passing a logging tool through a borehole, obtaining a series of tool response measurements, and obtaining a series of tool position measurements associated with the tool response measurements. The tool position measurements preferably indicate the distance between the tool axis and the borehole axis. The tool position measurements are preferably examined to determine if the tool was moving while the tool was making measurements. For measurements made while the tool was moving, the measurement time interval is preferably divided into subintervals each having a corresponding tool position. A formation property (such as resistivity) is estimated, and the expected tool response for each tool position is calculated. The expected tool responses are combined to form a model tool response, that is, the tool response that might be expected for a tool in motion. The model tool response is then compared to the measured tool response.

US Patent:

6760666, Jul 6, 2004

Filed:

Dec 3, 2002

Appl. No.:

10/308733

Inventors:

Teruhiko Hagiwara - Houston TX

Assignee:

Shell Oil Company - Houston TX

International Classification:

G01V 318

US Classification:

702 7, 324343

Abstract:

A method for determining the anisotropic resistivity properties of a subterranean formation traversed by a borehole utilizing a multi-component induction logging tool. The method utilizes the measured phase and attenuation signals induced by eddy currents in the formation to determine the azimuthal angle and to create a second set of signals based on the measured signals and the azimuthal angle. The anisotropic resistive properties, as well as the dip angle, are then simultaneously derived from the second set of signals by means of minimizing error functions within an inversion model.

US Patent:

7135862, Nov 14, 2006

Filed:

Mar 13, 2001

Appl. No.:

09/803819

Inventors:

Teruhiko Hagiwara - Houston TX, US

Assignee:

Halliburton Energy Services, Inc - Houston TX

International Classification:

G01V 3/00

US Classification:

324303

Abstract:

Method for data acquisition and processing, which uses time-domain averaging to increase the signal to noise ratio (SNR) in single-event measurements. In a preferred embodiment, NMR echo-trains obtained using high-speed NMR logging are provided, the echo trains are time-domain averaged, preferably in real-time, over one or more time intervals to sharpen the spatial resolution of the logging tool and/or to increase the signal to noise ratio (SNR) of the data train.

US Patent:

7414406, Aug 19, 2008

Filed:

Nov 9, 2005

Appl. No.:

11/270094

Inventors:

Erik Banning - Houston TX, US
Teruhiko Hagiwara - Houston TX, US
Rich Ostermeier - Houston TX, US

Assignee:

Shell Oil Company - Houston TX

International Classification:

G01V 3/18

US Classification:

324338

Abstract:

A method and a system are provided for allowing determination of a direction and distance from a tool to anomaly in a formation. The apparatus for performing the method includes at least one transmitter and at least one receiver. An embodiment of the method includes transmitting electromagnetic signals from the at least one transmitter through the formation near the wellbore and detecting responses at the at least one receiver induced by the electromagnetic signals. The method may further include determining the direction from the device to the anomaly based on the detected responses. The method may also include calculating at least one of an apparent azimuth angle and an apparent dip angle based on the responses, monitoring the at least one calculated apparent angle over time, and determining the direction to the anomaly after the at least one monitored apparent angle deviates from a zero value.

US Patent:

7425830, Sep 16, 2008

Filed:

Nov 5, 2003

Appl. No.:

10/701735

Inventors:

Erik Banning - Houston TX, US
Teruhiko Hagiwara - Houston TX, US
Rich Ostermeier - Houston TX, US

Assignee:

Shell Oil Company - Houston TX

International Classification:

G01V 3/08
G01V 3/30

US Classification:

324338

Abstract:

A method and a system are provided for allowing determination of a direction and distance from a tool to anomaly in a formation. The apparatus for performing the method includes at least one transmitter and at least one receiver. An embodiment of the method includes transmitting electromagnetic signals from the at least one transmitter through the formation near the wellbore and detecting responses at the at least one receiver induced by the electromagnetic signals. The method may further include determining the direction from the device to the anomaly based on the detected responses. The method may also include calculating at least one of an apparent azimuth angle and an apparent dip angle based on the responses, monitoring the at least one calculated apparent angle over time, and determining the direction to the anomaly after the at least one monitored apparent angle deviates from a zero value.

US Patent:

7425831, Sep 16, 2008

Filed:

Nov 9, 2005

Appl. No.:

11/270705

Inventors:

Erik Banning - Houston TX, US
Teruhiko Hagiwara - Houston TX, US
Rich Ostermeier - Houston TX, US

Assignee:

Shell Oil Company - Houston TX

International Classification:

G01V 3/18

US Classification:

324338

Abstract:

A method and a system are provided for allowing determination of a direction and distance from a tool to anomaly in a formation. The apparatus for performing the method includes at least one transmitter and at least one receiver. An embodiment of the method includes transmitting electromagnetic signals from the at least one transmitter through the formation near the wellbore and detecting responses at the at least one receiver induced by the electromagnetic signals. The method may further include determining the direction from the device to the anomaly based on the detected responses. The method may also include calculating at least one of an apparent azimuth angle and an apparent dip angle based on the responses, monitoring the at least one calculated apparent angle over time, and determining the direction to the anomaly after the at least one monitored apparent angle deviates from a zero value.