Texaco Inc.

Donald J Dowling

Jackie C Sims

Dan M Arnold

Albert P Richter

Wayne F Warren

Theodore W Nussbaum

Kerry D Savage

Brian C Considine

Richard S Simpson

William Schoen

Roy P Mazzagatti

Harold A Palmer

Robert E Kunetka

Vernon L Heeren, Deceased

The control system and method of the present invention controls a heat treater receiving wet gas from a pipeline. The heat treater reduces the water content of the gas to provide dry gas to the pipeline. A sensor monitors the wet gas and provides a signal corresponding to the water content of the wet gas. A second sensor monitors the dry gas and provides a signal corresponding to the water content of the dry gas. A difference signal corresponding to the difference between the two water content signals. Apparatus controls the flow of fuel to the heat treater, so as to control the drying process, in accordance with the water content signal of the wet gas and the difference signal.

Means and methods for controlling the drying of wet gas

A fluid capacitance sensor includes a device, receiving a stream of fluid, which converts the fluid flow to annular fluid flow. A capacitance sensing network has an internal capacitance substantially greater than the capacitance of the fluid. The capacitance sensing network measures the capacitance of the annular flowing fluid and provides a signal corresponding to the sensed capacitance of the fluid.

Fluid capacitance sensing means and method

A steam quality monitor measures the quality of steam flowing in a steam pipe. A measurement cell is connected in the steam pipe so that steam flows through the measurement cell. The cell has two windows aligned along an axis which is traverse to the flow axis of the steam. A source spatially arranged with the windows of the measurement cells provides IR energy which enters the measurement cells through one window and leaves through the other window so that the IR energy passes through the steam flowing in the measurement cell. An IR detector detects the IR energy as it leaves the measurement cell and provides a corresponding signal. The temperature of the steam flowing through the measurement cell is also sensed and a temperature signal provided. Circuitry derives the steam quality of the steam flowing in the steam pipe in accordance with the signal from the IR detector and the temperature signal.

Radiant energy absorption steam quality monitoring means and method

A system of the present invention monitors the quality of steam flowing in a pipeline includes a test cell which is connected inline into the pipeline and has the steam flowing through it. A plurality of electrodes are located within the test cell and cooperate with the test cell to provide capacitance signals corresponding to capacitances of the steam passing between the electrodes and the test cell. The electrodes have different spacings between them and an interior wall of the test cell. A sensor senses the temperature of the steam flowing through the test cell and provides a temperature signal corresponding to the sensed temperature. Another sensor senses the pressure of the steam and provides a pressure signal corresponding to the sensed pressure. Circuitry connected to the test cell, to all the electrodes, to the temperature sensor and to the pressure sensor measures the quality of the steam in accordance with the temperature signal, the pressure signal and one of the capacitance signals.

Multi-sensor steam quality monitoring means and method

A steam quality monitor monitoring the quality of steam flowing in the pipe includes capacitance sensing apparatus which senses the capacitance of the flowing steam and provides a capacitance signal corresponding to the said capacitance. Another sensor which may be either a temperature sensor or a pressure sensor senses either the temperature or pressure of the steam and provides a representative type signal. Circuitry connected to the capacitance sensor and to the temperature or pressure sensor provides an output corresponding to the quality of steam in accordance with the capacitance and the temperature or pressure signal.

Steam quality monitoring means and method

The present invention is an apparatus and method which monitors the quality of steam flowing in a pipe. A steam sensor located in the pipe provides a steam signal which is frequency related to the quality of the steam flowing in the pipe. A network connected to the sensor provides a high frequency signal and a low frequency signal in accordance with the steam signal. The steam quality is the in accordance with the high frequency signal and the low frequency signal.

Method and apparatus determining the water saturation of a petroleum reservoir earth formation include transmitting electromagnetic energy in the earth formation from within a borehole traversing the earth formation and at least two frequencies within a preferred range of frequencies. The electromagnetic energy is received at two locations from the earth formation and within the borehole. The water saturation of the earth formation is derived from the received electromagnetic energy.

Well logging means and method for determining water saturation of a

A method and apparatus is applicable to in situ heating of oil shale or tar sand. The heating is by radio frequency that is applied down hole by a central conductor that extends beyond a coaxial shielding conductor to form the antenna or applicator. Encroachment by the heated formation is overcome by applying motion to the central conductor to remove encroaching formations.

Method and apparatus for combating encroachment by in situ treated

A method for measuring temperatures of a hydrocarbon stratum subjected to RF electromagnetic energy includes in one embodiment sensing the temperature at different positions within an inner conductor of an applicator used to radiate the RF electromagnetic energy into the hydrocarbon stratum. In another embodiment, the temperature measurements are made from a borehole which is utilized to obtain hydrocarbon fluids resulting from the retorting of the hydrocarbon stratum in which the sensing is done in different positions within the producing borehole and in the vicinity of the hydrocarbon stratum. Electrical signals representative of the sensed temperatures are provided. The electrical signals are conducted from the sensing positions to the surface of the earth. An RF voltage which combines with the electrical signals is decoupled from the electrical signals. An indication of the temperatures is provided in accordance with the decoupled electrical signals.

Method for measuring temperature of a hydrocarbon stratum subjected to

A method of determining the permeability of a particular stratum in an earth formation traversed by a borehole includes injecting a liquid into the borehole at a first pressure thereby causing liquid flow into the stratum. A first flow rate of the liquid is determined at the first pressure. The pressure of the liquid being injected into the borehole is then changed to a second pressure level and a second flow rate of the liquid flowing into the stratum is determined at the second pressure. An indication of the permeability of the stratum is then derived in accordance with the two pressures, the two flow rates and known characteristics of the stratum.

In-situ permeability determining method

A method and apparatus for measuring the temperature in a subsurface earth formation that is being heated in situ by subjection to a radio frequency electromagnetic field. It includes lowering a maximum registering thermometer into the formation on a non-conductive flexible line, and holding it there long enough to reach the ambient temperature at that location. Then, the thermometer is raised to the surface fast enough to avoid any significant change on the way up to read that registered maximum.

Method and apparatus for measuring temperature of an earth formation in

Disclosed is a down hole logging tool featuring a neutron generator, an acoustic disturbance generator, and a radiation detection system. In the embodiment shown, an array of acoustic magnetostriction transducers is arranged about the target of a neutron accelerator. Two gamma ray sensors are separated from the accelerator target by shielding. According to the method of the invention, the underground fluid at the level of a formation is bombarded by neutrons which react with oxygen in the fluid to produce unstable nitrogen 16 particles according to the reaction O.sup.16 (n,p)N.sup.16. Acoustic pulses are communicated to the fluid, and are incident on the boundary of the borehole at the formation. The resulting net flow of fluid across the boundary is determined from radiation detection measurements of the decaying N.sup.16 particles in the fluid. A measure of the permeability of the formation is obtained from the determination of net fluid flow across the boundary.

Acoustic-nuclear permeability logging system

Oxygen in a borehole fluid in the vicinity of a reference region, such as an earth formation of known fluid permeability, is activated with a logging instrument by being bombarded with neutrons of 14 MEV energy level to form the unstable isotope nitrogen 16 giving rise to gamma radiation. Flow of the activated fluid is then caused by an electrohydraulic flow generator which forms an intense pressure pulse in the fluid. A gamma ray detector in the logging instrument senses the amount of flow of the activated fluid within the borehole in the reference region. The logging instrument is then moved to a formation whose liquid permeability is to be tested. Borehole fluid opposite the formation to be tested is activated by neutron bombardment, again giving rise to gamma radiation, and fluid flow in the formation under test is caused by the electrohydraulic flow generator. The gamma ray detector reading of activated fluid flow in the borehole opposite the formation under test, when compared with the flow reading in the borehole opposite the reference region, is a measure of relative fluid permeability in the formation being tested.

Radioactive well logging to measure earth formation fluid permeability

Apparatus and method for measuring oil flowing in a pipe include continuously sampling the cil to provide a stream of sample oil. The temperature of the sample oil is changed by a predetermined amount. The acoustical velocity of the sample oil is determined prior to the temperature change and after the temperature change by sensors providing corresponding signals. A circuit provides a signal corresponding to the water content of the oil in accordance with the acoustical velocity and the known temperature change.

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Houston, TX, United States of America

Donald J Dowling