JAMES DAVIS
Electrician at Heffington Rd, Bray, OK

5252918, Oct 12, 1993

Dec 20, 1991

7/812199

Charles F. VanBerg - Duncan OK
James L. Davis - Marlow OK

Halliburton Company - Duncan OK

G01B 714, G01R 3312

32420719

A plug released into an oil or gas well carries one or more metallic strips that affect the inductance of a resistive-inductive bridge circuit mounted adjacent a conduit through which the plug and fluids are pumped into the well. This unbalances the bridge circuit to produce a signal preferably uniquely identified with the plug so that an indicator can be activated to confirm proper release of the plug into the well. When an amorphous metal is used in the metallic strips, the unbalancing of the bridge produces a signal having an identifiable harmonic of a fundamental frequency of an oscillator signal driving the bridge circuit, which harmonic is not present in other signals resulting from the bridge circuit being unbalanced by other materials flowing in the conduit.

5003502, Mar 26, 1991

Oct 25, 1988

7/262406

James L. Davis - Marlow OK

Halliburton Company - Duncan OK

G06F 1500, G01T 116

364572

A digital filter for use with a randomly generated variable, such as in a radioactive densometer, is provided and includes a microprocessor and timing clock for sampling the random variable over a specific time interval. The microprocessor utilizes a weighting factor based upon a first confidence factor and computes the mean value of a first sample of the random variable and compares the number of standard deviations that a subsequent sample is from the mean value of the previous sample and uses a probability related factor to determine if the subsequent sample represents an actual change in density. Further, the microprocessor uses a second confidence factor in determining the weighting factor which counts the number of consecutive times that the subsequent samples are greater than, or less than the mean value and again determines a probability related factor to determine if a change in density is actually occurring. As both the first and second confidence factors increase, so does the weighting factor and the probability that an actual change in fluid density has occurred.

5689248, Nov 18, 1997

Dec 15, 1994

8/358069

Farhad Esfahani - Dallas TX
James Lloyd Davis - Marlow OK

Gas Research Institute - Chicago IL

G01V 300

3408531

The methods of this invention reduce the amount of power consumed by a remotely positioned (i. e. downhole) sensor/transmitter used in applications such as well bore telemetry. The method involves the sensing of physical characteristics such as pressure and/or temperature to generate a first absolute value than is transmitted to a surface receiver located at the earth's surface. At a later time (or period) the physical characteristic is again sensed to generate a second absolute value that is subtracted from the first absolute value to generate a difference. If the difference is significant (i. e. , greater than a predetermined value), the difference will be transmitted to the surface receiver. Because the difference will generally have fewer bits of data than the absolute data, less data can be transmitted so that battery power is conserved in the remote sensor/transmitter. In the event that the difference is not significant, even fewer bits need to be transmitted by the remote sensor/transmitter.

5784004, Jul 21, 1998

Jun 20, 1995

8/492814

Farhad Esfahani - Dallas TX
James Lloyd Davis - Marlow OK
Robert L. Toellner - Duncan OK

Gas Research Institute - Chicago IL

G01V 300

3408546

The system of the subject invention includes an antenna system, a surface apparatus and a battery-powered remote apparatus useful for applications such as well bore telemetry. In well bore telemetry, the surface apparatus is located uphole on the earth's surface and the remote apparatus is positioned at a remote location downhole in a well bore. The remote apparatus includes a sensor/transmitter unit for sensing physical characteristics such as pressure and/or temperature. The remote apparatus conserves power stored in its battery by transmitting change-in-pressure and/or change-in-temperature data that requires less power for transmission than absolute pressure and/or temperature data. The remote apparatus also conserves power by transmitting absolute pressure data in a single data frame and transmitting absolute temperature data in portions in a series of data frames. The remote apparatus can transition between initial time delay, fixed transmit sequence, sleep, operation, and test states based on its control program and/or based upon the transmission of control data from the surface apparatus.

5323856, Jun 28, 1994

Mar 31, 1993

8/040708

James L. Davis - Marlow OK
Charles F. Van Berg - Duncan OK

Halliburton Company - Duncan OK

E21B 4400

166253

A system for sensing the passage of a member past a predetermined location along a tubing disposed in an oil or gas well comprises: a magnet connected to the member, the magnet having a soft body so that the magnet can be drilled out by a drill bit lowered into the well after the member has passed the predetermined location; and a sensor, connected to the outside of the tubing at the predetermined location, for detecting a magnetic field of the magnet as the member with the magnet connected thereto passes the sensor. A method for assisting the proper placement of a cement slurry in an oil or gas well comprises: pumping a cement slurry through a tubing into an oil or gas well; releasing a cementing plug into the tubing in series with the cement slurry, the cementing plug having a magnet as referred to above; and sensing the cementing plug at a predetermined location along the tubing, including: generating a null signal in response to providing a biasing magnetic field in opposition to a magnetic field naturally occurring in the tubing at the predetermined location; and changing the null signal to an indicator signal in response to the magnet moving in the tubing to the predetermined location.

4654802, Mar 31, 1987

Jun 7, 1984

6/618850

James L. Davis - Marlow OK

Halliburton Company - Duncan OK

G05D 1113, G01N 900, B28C 704

364502

For use in preparing cement to cement a well, a cement metering system is set forth. The preferred and illustrated embodiment incorporates flow meters measuring water delivered to a cement jet mixer for cement and water into a slurry. A downstream density meter is included. A second water line dilutes the slurry to adjust the density downwardly to the desired slurry density controlled by the control system. The control system includes a data formatting circuit connected to the various transducers which converts the data so that the density required for the slurry is obtained. As desired, the data can be totalled by integrating over a period of time and shown on the data display. Volume flow rate of the controlled density slurry and bulk volume of dry cement may be determined.

4618939, Oct 21, 1986

Jul 13, 1983

6/513528

James L. Davis - Marlow OK

Halliburton Company - Duncan OK

G01T 116

364555

A system for quickly indicating changes in density of a flow of material using a radiactive source and detector where the count rate indicative of density is processed for sensing significant changes in the density in the flow of material as distinguished from random changes and for producing an indication of such changes. In one aspect of the invention, a time filter is utilized with an RC circuit and diodes to require a count rate indicative of a significant density change before producing an indication. In another aspect of the present invention the count rate is processed with respect to a predetermined formulation to determine the occurrence of a significant density change in a time frame and for producing an indication when such change occurs.

7568380, Aug 4, 2009

Nov 3, 2006

11/592521

Jason D. Bivens - Duncan OK, US
James L. Davis - Marlow OK, US

Halliburton Energy Services, Inc. - Duncan OK

G01N 11/14

73 5428, 73 5423, 73 5432

A turbine viscometer for measuring the viscosity of fluid flowing through a conduit, such as a pipe or manifold. The viscometer has a viscosity turbine positionable in the pipe or manifold. The viscosity turbine has a central portion and a plurality of blades extending therefrom such that fluid flow does not induce any rotational movement of the viscosity turbine. The viscometer also has a drive device for rotating the viscosity turbine so that fluid drag on the viscosity turbine can be measured to determine the viscosity of the fluid. In one embodiment, the drive device creates a rotational magnetic field around the viscosity turbine so that it is rotated. In a second embodiment, the drive device is a drive turbine connected to the viscosity turbine and rotated by fluid flowing through the pipe or conduit.