William C Savage

6633164, Oct 14, 2003

Mar 2, 2001

09/798192

Harold J. Vinegar - Houston TX
Robert Rex Burnett - Katy TX
William Mountjoy Savage - Houston TX
John Michele Hirsch - Houston TX
Peter Anthony Crossley - Austin TX

Shell Oil Company - Houston TX

G01V 318

324355, 324368, 324373

A petroleum well ( ) for producing petroleum products that incorporates a system adapted to controllably measure a formation resistivity using induction chokes ( - ) to form electrically isolated piping structure sections that can be used as the formation contact electrodes for time-varying current, and methods of producing petroleum products while measuring formation resistivity, are provided by the present invention. The system comprises a first induction choke ( ), a second induction choke ( ), and a device ( ). The first induction choke ( ) is located about a piping structure ( ) of the well ( ). The second induction choke ( ) is also located about the piping structure ( ) of the well ( ), but the first induction choke ( ) is distally spaced from the second induction choke ( ). The device ( ) is located outside of the piping structure ( ) and comprises two terminals ( ). A first of the terminals ( ) extending from the device ( ) is electrically connected to the piping structure ( ) on one side ( ) of the first induction choke ( ).

6633236, Oct 14, 2003

Jan 24, 2001

09/768655

Harold J. Vinegar - Houston TX
Robert Rex Burnett - Katy TX
William Mountjoy Savage - Houston TX
James William Hall - Rijswijk, NL
John Michele Hirsch - Houston TX

Shell Oil Company - Houston TX

B01V 300

3408544, 3408543, 3408548, 166 73, 367 82

A system and method of communicating among devices via a piping structure using at least one induction choke about the piping structure to route a time-varying current carrying communication signals between the devices. A communications system comprises a piping structure, a first communication device, a second communication device, and an induction choke. The piping structure comprises a first location, a second location, and an electrically conductive portion extending between the first and second locations. The first and second locations are distally spaced along the piping structure. The first and second communication devices are each electrically connected to the electrically conductive portion of the piping structure along the first location and second location, respectively, and each is adapted to send and receive communication signals via time-varying current. The induction choke is located about an electrically choked portion of the electrically conductive portion of the piping structure, such that the induction choke is adapted to route time-varying current within the piping structure between the electrical connection location for the first communication device and the electrical connection location for the second communication device, and such that the first communication device can communicate with the second communication device via the piping structure. A preferred application of the present invention is a well for producing petroleum products (e. g.

6662875, Dec 16, 2003

Jan 24, 2001

09/769048

Ronald Marshall Bass - Houston TX
Harold J. Vinegar - Houston TX
Robert Rex Burnett - Katy TX
William Mountjoy Savage - Houston TX
John Michele Hirsch - Houston TX
George Leo Stegemeier - Houston TX

Shell Oil Company - Houston TX

E21B 4300

166369, 166 651, 166 53

A current impedance device for routing a time-varying electrical current in a piping structure comprising an induction choke. The induction choke is generally concentric about a portion of the piping structure such that during operation a voltage potential forms between the piping structure and an electrical return when the time-varying electrical current is transmitted through and along the piping structure, and such that during operation part of the current can be routed through a device electrically connected to the piping structure due to the voltage potential formed. The induction choke may be unpowered and may comprise a ferromagnetic material. A system for defining an electrical circuit in a piping structure using at least one unpowered ferromagnetic induction choke, comprises an electrically conductive portion of the piping structure, a source of time-varying current, at least one induction choke, a device, and an electrical return. The system can have various configurations and embodiments to define a plurality of possible electrical circuits formed using at least one induction choke to route time-varying current. An electric power transformer can also be incorporated.

6679332, Jan 20, 2004

Jan 24, 2001

09/769046

Harold J. Vinegar - Houston TX
Robert Rex Burnett - Katy TX
William Mountjoy Savage - Houston TX

Shell Oil Company - Houston TX

E21B 3406

166373, 166 53, 166 651, 166369

A petroleum well has an electronic module and a number of sensors which communicate with the surface using the tubing string and casing as conductors. Induction chokes at the surface and downhole electrically impede AC flow through the (tubing or casing if so configured) with the resulting voltage potential useful for power and communication. A high bandwidth, adaptable spread spectrum communications system is used to communicate between the downhole electronics module and a surface master spread spectrum modem. Downhole sensors, such as pressure, temperature, acoustic and seismic sensors accurately assess downhole physical conditions. In a preferred form, the electronics module and sensors are wireline insertable and retrievable into a side pocket mandrel in the tubing string. Permanent downhole sensors that can communicate with the surface allow such diverse applications as optimizing well and field performances, monitoring and assessing the geophysics of the fomrations around the well, assessing well and reservoir reserves, assessing reservoir conditions.

6715550, Apr 6, 2004

Jan 24, 2001

09/768705

Harold J. Vinegar - Houston TX
Robert Rex Burnett - Katy TX
William Mountjoy Savage - Houston TX

Shell Oil Company - Houston TX

E21B 4300

16625015, 166 53, 166 66, 166 667, 166 685, 166106, 137155, 3408533, 3408544, 3408545

A gas-lift well having a controllable gas-lift valve is provided. The well uses the tubing and casing to communicate with and power the controllable valve from the surface. Induction chokes at the surface and downhole electrically isolate the tubing from the casing. A high band-width, adaptable communication system is used to communicate between the controllable valve and the surface. Additional sensors, such as pressure, temperature, and acoustic sensors, may be provided downhole to more accurately assess downhole conditions. The controllable valve is varied opened or closed, depending on downhole conditions, oil production, gas usage and availability, to optimize production and assist in unloading. While conventional, bellows-type, gas-lift valves frequently fail and leakâoften undetectedâthe controllable valve hereof permits known precise operation and concomitant control of the gas-lift well.

6758277, Jul 6, 2004

Jan 24, 2001

09/768656

Harold J. Vinegar - Houston TX
Robert Rex Burnett - Katy TX
William Mountjoy Savage - Houston TX

Shell Oil Company - Houston TX

E21B 4312

166372, 16625003, 16625015

A controllable gas-lift well having controllable gas-lift valves and sensors for detecting flow regime is provided. The well uses production tubing and casing to communicate with and power the controllable valve from the surface. A signal impedance apparatus in the form of induction chokes at the surface and downhole electrically isolate the tubing from the casing. A high band-width, adaptable spread spectrum communication system is used to communicate between the controllable valve and the surface. Sensors, such as pressure, temperature, and acoustic sensors, may be provided downhole to more accurately assess downhole conditions and in particular, the flow regime of the fluid within the tubing. Operating conditions, such as gas injection rate, back pressure on the tubing, and position of downhole controllable valves are varied depending on flow regime, downhole conditions, oil production, gas usage and availability, to optimize production. An Artificial Neural Network (ANN) is trained to detect a Taylor flow regime using downhole acoustic sensors, plus other sensors as desired.

6840316, Jan 11, 2005

Mar 2, 2001

10/220251

George Leo Stegemeier - Houston TX, US
Harold J. Vinegar - Houston TX, US
Robert Rex Burnett - Katy TX, US
William Mountjoy Savage - Houston TX, US
John Michele Hirsch - Houston TX, US

Shell Oil Company - Houston TX

E21B 4700

16625012, 166 66, 1662526

A petroleum well having a well casing, a production tubing, a source of time-varying current, a downhole tracer injection device, and a downhole induction choke. The casing extends within a wellbore of the well. The tubing extends within the casing. The current source is located at the surface. The current source is electrically connected to, and adapted to output a time-varying current into, the tubing and/or the casing, which act as electrical conductors for providing downhole power and/or communications to the injection device. The injection device having a communications and control module, a tracer material reservoir, and an electrically controllable tracer injector.

6840317, Jan 11, 2005

Mar 2, 2001

10/220455

John Michele Hirsch - Houston TX, US
George Leo Stegemeier - Houston TX, US
James William Hall - Houston TX, US
Robert Rex Burnett - Katy TX, US
William Mountjoy Savage - Houston TX, US

Shell Oil Company - Houston TX

E21B 4700
E21B 4706

16625015, 166372

A method for optimizing the production of a petroleum well is provided. The petroleum well includes a borehole, a piping structure positioned within the borehole, and a tubing string positioned within the borehole for conveying a production fluid. Production of the well is optimized by determining a flow rate of the production fluid within the tubing string and determining a lift-gas injection rate for the gas being injected into the tubing string. The flow rate and injection rate data is communicated along the piping structure of the well to a selected location, where the data is collected and analyzed. After analysis of the data, an optimum operating point for the well can be determined.