Geosensor Corporation

Halliburton Energy Services, Inc.

Syntron, Inc.

Sercel Inc.

Other

John Luscombe

John L Maida

Louis W Erath

Malcolm Paul Varnham

Michael L Maples

Etienne M Samson

Gary J Craig

Erhard Lothar Edgar Kluth

John Laureto Maida, Jr

Gary Craig

Paul F Rodney

Mike Maples

Gary W Craig

James Spackman

Phillip Sam Bull

Sam Bull

Jim Spackman

David Lamance

Ed Kluth

Robert M Braham

Various optical fiber-based seismic monitoring system embodiments include a light source that drives an optical fiber positioned within a borehole. At least one light sensor analyzes Rayleigh backscattered light to obtain an acoustic signal for each of multiple points along the borehole. One or more processors operate to determine microseismic event direction, distance, and/or intensity based at least in part on phase information of said acoustic signals. The acoustic signal cross-correlations, semblances, or phase-sensitive similarity measures can be determined as a function of scanning direction to accurately determine the relevant microseismic event information. The optical fiber may be positioned in the cemented annulus of a cased borehole having a shape that extends along more than one dimension (e.g., an L-shaped borehole).

Optical fiber based downhole seismic sensor systems and methods

Downhole orientation sensing with a nuclear spin gyroscope. A method of sensing orientation of an instrument assembly in a subterranean well can include incorporating an atomic comagnetometer and an optical source into the instrument assembly, and installing the instrument assembly in the well. A downhole orientation sensing system for use in conjunction with a subterranean well can include a downhole instrument assembly positioned in the well, the instrument assembly including an atomic comagnetometer and an optical source which transmits light to the atomic comagnetometer.

Downhole orientation sensing with nuclear spin gyroscope

Downhole orientation sensing with a nuclear spin gyroscope. A downhole orientation sensing system for use in conjunction with a subterranean well can include a downhole instrument assembly positioned in the well, the instrument assembly including an atomic comagnetometer, and at least one optical waveguide which transmits light between the atomic comagnetometer and a remote location. A method of sensing orientation of an instrument assembly in a subterranean well can include incorporating an atomic comagnetometer into the instrument assembly, and installing the instrument assembly in the well.

A support structure for piezoelectric elements in a marine seismic cable is provided. The support structure comprises upper and lower cylindrical halves, each with channels formed therein. Two axial channels are adapted to retain three piezoelectric elements each. A third axial channel, positioned between the sensor element channels, is adapted to retain a flexible circuit. Transverse channels between the sensor element channels and the circuit channels accommodate extension from the flexible circuit. The piezoelectric elements are mounted within their respective channels with a resilient pad with adhesive on both sides. The piezoelectric elements are graded so that any group of three piezoelectric elements exhibits approximately the same sensitivity as any of the other three groups of piezoelectric elements on the support structure.

Solid marine seismic cable

In an interferometric sensing apparatus, a scrambler is positioned in front of a polarizer, followed by a detector. In that way, although the two beams remain orthogonal to each other, they are continuously rotated, relative to the polarizer. In some positions, both beams pass through the polarizer and interfere, thus eliminating polarization fading. The signal is amplitude modulated at the rotation frequency of the scrambler, but this modulation is removed by low pass filtering.

Method and apparatus for the elimination of polarization fading in interferometric sensing systems

A pressure sensitive optical fiber is enclosed within a pressure chamber. A mass is positioned so as to vary the pressure in the pressure chamber in response to a seismic signal. Variations in the chamber pressure are directly detected by the pressure sensitive fiber.

Geophone with optical fiber pressure sensor

A seismic sensor array includes a means for passive electrical to optical energy transformation and transmission. This transformation is used remotely with traditional sensor arrays, which may include hydrophones, geophones, or a combination of them. The transformation means is used to develop an optical signal in a fiber which then conveys the seismic signals to a recording center or data accumulator.

Seismic sensor array with electrical to optical transformers

A structure for incorporating fiber optic acoustic sensor in a seismic array includes means for supporting the sensor in a spiral around a central strength member in a manner to isolate shear waves from the sensor. In another aspect, an axially oriented sensor in a seismic array comprises a pressure sensitive optical fiber wound in a spiral around the axis, the fiber having a plurality of optical Bragg gratings and a plurality of channels. The preferred structure may include four tubes spiraling around the strength member. One of the tubes encloses an optical fiber sensor which is maintained in an extended orientation by fluid flow through the tube. Another of the tubes serves as a return path for fluid through the sensor tube. The other tubes enclose high speed and low speed data conductors, respectively. The sensor fiber may also be wound in a spiral around a compliant core in a manner to satisfy Poisson's Ratio such that strain on the compliant core does not alter the tension of the sensor fiber.

Method and structure for incorporating fiber optic acoustic sensors in a seismic array

An interferometric sensor includes a broadband optical source, a depolarizer for depolarizing optical radiation emitted by the broadband optical source, a matched interferometer, a sensing interferometer, and a detector. The matched interferometer contains a phase modulator. The sensor is configured so that the optical path length difference in the sensing interferometer is approximately equal to the optical path length difference in the matched interferometer.

Seismic sensor with interferometric sensing apparatus

A hydrophone streamer including a central member running substantially the length of the streamer with a strength member and a plurality of conductors has formed therein space adapted to receive a plurality of a spaced apart pairs of collars, a cylindrical chamber wall between each of the pairs of collars defining a chamber, and one or more hydrophones within the chamber. The chamber wall has one or more opening through it for the free passage of sea water into the chamber, thereby shielding the hydrophones from extraneous noise while exposing the hydrophones to a seismic signal conducted by the sea water surrounding the streamer.

Hydrophone carrier

A seismic sensor array includes a means for passive electrical to optical energy transformation and transmission. This transformation is used remotely with traditional sensor arrays, which may include hydrophones, geophones, or a combination of them. The transformation means is used to develop an optical signal in a fiber which then conveys the seismic signals to a recording center or data accumulator. The transformation means preferably comprises a stack of piezoelectric elements capped on each end by a rounded crown to accommodate an optical fiber wound around the stack and the crowns.

Seismic sensor array with electrical-to optical transformers

An element that is sensitive to a pressure or acceleration signal comprises an optical element capable of changing its index of refraction and/or path length in response to a time varying pressure or in response to acceleration and a pliant mounting member supporting the optical element. The mounting member changes its geometrical configuration in response to the time varying pressure or acceleration. Some embodiments of the invention use a mechanical amplifier to achieve the needed sensitivity.

Optical sensor

An arcuate or flat ferroelectric sensor is incorporated in a seismic streamer. The structure comprises an interior cable, a surrounding woven strength member, an overlying foam floatation layer, and an enclosing jacket. One or more elongate channels are formed in the overlying floatation layer, and one or more hydrophones are mounted in the channel(s). The elongate channel enlarges the acoustic aperture for the reception of seismic signals.

A seismic marine streamer (10) including hydrophones (12) housed in elongate flexible tubes (11), a pair of load carrying rope members (25, 26), and a plurality of spacers (15) which substantially fill the internal cross-section of the tube (11), the internal void within the tube being filled by a liquid, the two rope carrying members (25, 26) interconnect end fittings (21, 22) located one at each end of a tube (11) and passing through each spacer (15) on diametrically opposite sides thereof.

Seismic streamer

A system for testing a group of hydrophones includes (a) a tank having a nozzle adapted for attachment of a streamer jacket; (b) a harness reel inside the tank for reversibly retaining a group of hydrophones; (c) fluid passage means into the tank for introducing and withdrawing fluid into and out of the tank; (d) an oscillating pump in fluid communication with the tank to introduce a time varying pressure pulse in the tank; (e) a reference hydrophone inside the tank; (f) electrical coupling means to couple a hydrophone signal from the group of hydrophones and the reference hydrophone to a central processing unit; and (g) means for comparing the hydrophone signal of the reference hydrophone to the hydrophone signal of the group of hydrophones. The means for comparing the hydrophone signal of the reference hydrophone to the signal from the group of hydrophones comprises a computer that determines the maximum signal strength and the fundamental frequency from the reference hydrophone, determines the maximum signal strength from the test array at the fundamental frequency, then calculates the sensitivity of the test array from the known sensitivity of the reference hydrophone.

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Sugarland, TX, United States of America

John Luscombe