Roger R Steinsiek

7464588, Dec 16, 2008

Oct 14, 2005

11/250598

Roger Steinsiek - Houston TX, US

Baker Hughes Incorporated - Houston TX

E21B 47/08

7315255

The method and apparatus of the present invention provides for detecting a flow of a formation fluid entering into a wellbore. An ultrasonic sensor is placed in a wellbore. The sensor has a resonant member that is exposed to a fluid in the wellbore. At a location in the wellbore, acoustic energy is measured wherein the acoustic energy is related to turbulence from formation fluid entering the wellbore. In another embodiment of the invention a tool is provided for detecting a flow of a formation fluid into a downhole location in a wellbore. The ultrasonic sensor has a resonant member that is adapted to be in contact with a fluid in the wellbore. The sensor generates electrical signals when exposed to ultrasonic turbulences caused by a formation fluid entering into the wellbore. A processor processes the electrical signals to detect the flow of the formation fluid entering into the wellbore.

8074511, Dec 13, 2011

May 21, 2007

11/804909

Cornelis Huiszoon - Houston TX, US
Homero C. Castillo - Kingwood TX, US
Shawn A. Olsen - Spring TX, US
Roger R. Steinsiek - Houston TX, US
Gabriel Villasmil - Houston TX, US

Baker Hughes Incorporated - Houston TX

E21B 47/00

7315254, 175 50, 376 25, 702 6

The downhole tool disclosed herein comprises a body, a flexible member attached to the body, and a transducer housed in the body. The flexible member compresses against one side of the wellbore and urges the body against the other side. The transducer emits a signal to the flexible member reflectable from the flexible member back to the transducer. The signal travel time from the transducer to the flexible member and back is analyzed for estimating the distance between the body and the flexible member. The standoff distance can be estimated from the distance between the body and the flexible member. From the standoff distance, the wellbore diameter is estimated. The tool may also obtain wellbore dimensions by obtaining near side wellbore standoff and using a magnetic ruler to determine bowspring flexing. The magnetic ruler results may be used in conjunction with or without the far side standoff data.

8074712, Dec 13, 2011

Apr 14, 2009

12/423540

Shawn A. Olsen - Spring TX, US
Roger R. Steinsiek - Houston TX, US
James C. Hunziker - New Caney TX, US

Baker Hughes Incorporated - Houston TX

E21B 17/10

1662416, 1662411, 1753251, 1753255

A stop collar assembly used for axially securing and/or to resist axial sliding of a downhole tool device. The assembly provided on a housing of the downhole tool and includes a generally annular ring having an inner circumference beveled outward proximate to the ring edge. A clamp ring having a raised portion on its outer surface is disposed adjacent and substantially coaxial with the annular ring. Pushing the annular ring against the clamp ring compresses the clamp ring onto the housing to resist axial sliding of the annular ring.

8634272, Jan 21, 2014

Apr 14, 2010

12/760333

Roger R. Steinsiek - Houston TX, US
Jason M. Harris - Houston TX, US
Jinsong Zhao - Houston TX, US
Douglas J. Patterson - Spring TX, US
James B. Domnanish - Spring TX, US

Baker Hughes Incorporated - Houston TX

G01V 1/00

367 35, 367 69, 181106

Measurements made by a transducer assembly for downhole imaging are affected by reverberations between the transducer and the window on the outside of the assembly. The reverberations result in a stationary noise on the image. Hardware solutions to improve signal-to-noise ratio includes using a composite transducer, adjusting the distance between the transducer and the window. SNR can also be improved by processing techniques that include stacking, fitting a sinusoid to the reverberation, by envelope peak detection, and by applying a notch filter.

20090165547, Jul 2, 2009

Dec 16, 2008

12/336220

Roger Steinsiek - Houston TX, US

BAKER HUGHES INCORPORATED - Houston TX

E21B 47/14

7315232

The method and apparatus of the present invention provides for detecting a flow of a formation fluid entering into a wellbore. An ultrasonic sensor is placed in a wellbore. The sensor has a resonant member that is exposed to a fluid in the wellbore. At a location in the wellbore, acoustic energy is measured wherein the acoustic energy is related to turbulence from formation fluid entering the wellbore. In another embodiment of the invention a tool is provided for detecting a flow of a formation fluid into a downhole location in a wellbore. The ultrasonic sensor has a resonant member that is adapted to be in contact with a fluid in the wellbore. The sensor generates electrical signals when exposed to ultrasonic turbulences caused by a formation fluid entering into the wellbore. A processor processes the electrical signals to detect the flow of the formation fluid entering into the wellbore.

20090213690, Aug 27, 2009

Feb 25, 2009

12/392487

Roger R. Steinsiek - Houston TX, US
Douglas J. Patterson - Spring TX, US
Charles E. Redding - Houston TX, US
Anjani R. Achanta - Houston TX, US

Baker Hughes Incorporated - Houston TX

G01V 1/40
G01V 1/52
G01V 1/16
B06B 1/06

367 35, 181105, 367152, 367162

A transducer assembly for downhole imaging includes a 1-3 Piezoelectric composite transducer of high Q ceramic rods in a polymer matrix. The assembly also includes a Teflon window, a fluid-filled cavity adjacent to the window, and impedance matching material between the composite transducer and the fluid. The transducer is positioned to reduce the reverberation time.

20110222369, Sep 15, 2011

Mar 3, 2011

13/039895

Rocco DiFoggio - Houston TX, US
Roger R. Steinsiek - Houston TX, US

BAKER HUGHES INCORPORATED - Houston TX

G01V 1/40
H04R 17/00
H04R 31/00

367 35, 367140, 29594

In one aspect, the disclosure provides an apparatus that includes an acoustic transducer, and a backing coupled to the transducer, wherein the backing includes solid grains with fluid between the grains.

20130099791, Apr 25, 2013

Oct 24, 2011

13/279840

Laam Angela Tse - Sugar Land TX, US
Roger R. Steinsiek - Houston TX, US
Douglas J. Patterson - Spring TX, US

Baker Hughes Incorporated - Houston TX

G01V 3/00

324347

The present disclosure relates to methods and apparatuses measuring a property of a material. The apparatus may include a transducer comprising a first electrical conductor, a second electrical conductor, and a piezoelectric component configured to receive the two conductors. The piezoelectric component may include a cavity dimensioned to improve the strength of or reduce stress on an interconnection between piezoelectric component and at least one of the conductors. The method may include using one or more transducers measuring a property of a material. In some embodiments, the material may be an earth formation.