Exxonmobil Upstream Research Company

Baker Hughes Corporation

Western Atlas International, Inc.

Westerngeco L.l.p.

Michael W Norris

Marvin L Johnson

Terry R Bussear

Warren S Ross

Edward J Zisk, Jr

Steven E Heiney

Peter S Aronstam

Michael A Carmody

John E Anderson

Benn A Voll

Christian F Bayne

Otis A Johnston

Steven L Jennings

James R Zachman

Don A Hopmann

Young Ho Cha

Steve L Jennings

David A Bilberry

Graeme H Falconer

George M Wood

Ricky L Workman

Thomas J Fleure

Douglas L Bremner

Joseph M Reilly

J Todd Broome

Haiyang Wang

Steve B Hodges

Philip Burge

George William Wood

Michael Hares

Edward J Zisk

A method for obtaining zero-offset and near zero offset seismic data from a marine survey, with separation of direct arrival information and reflectivity information, the method including: modeling a direct arrival estimate at a passive near-field hydrophone array by using a notional source separation on active near-field hydrophone data; generating reflection data for the passive near-field hydrophone array by subtraction of the modeled direct wave from data recorded by the passive near-field hydrophone array; generating near zero-offset reflectivity traces by stacking the reflection data for the passive near-field hydrophone array on a string-by-string basis or on a combination of strings basis.

Method to estimate and remove direct arrivals from arrayed marine sources

Method for obtaining zero offset or near zero offset data in a marine seismic streamer survey. An acoustic transmitter () is attached to one of the buoys (or) that provide flotation to each streamer () and tow umbilical (). The acoustic transmitters, or single transmitter in the case of a 2-D survey, may be fired (-) before each shot from the survey air guns. The response to the acoustic transmitters recorded by the near sensors in each streamer, or by a water break sensor if provided, will be a near-zero to zero-offset record of the shallow subsurface below the water bottom.

Cable head marine seismic source

Method for estimating source signature of a marine seismic source array in a naturally band-limited subsurface region, for designature processing of resulting seismic data. Direct arrivals identified in the streamer receivers' records () provide a far-field estimate of the source signature, provided that the subsurface naturally limits frequencies to below the first notch frequency in the amplitude response of the seismic streamer receiver array. Processing of the direct arrivals may include move out or alignment correction (), signal enhancement (), summing of direct arrival traces over all offsets (), windowing or tapering of direct arrivals (), and deterministic corrections to the combined direct arrivals to compensate for ghosting and streamer array effects ().

Direct arrival signature estimates

The described invention relates to a method for acquiring seismic data in icy waters comprising positioning a fixed structure or movable vessel () at or near an established water opening; deploying into the water opening, from said structure or vessel one or more ROV or AUV units (), said ROV or AUV units remaining connected to said structure or vessel; operating the one or more ROV or AUV units to deploy seismic sensors recording equipment () and/or one or more seismic source equipment () on or near the water bottom; generating and applying control signals to one or more of the more ROV or AUV units to generate and to record seismic signals (); operating the one or more ROV or AUV units on the water bottom to move () and/or recover () the seismic source equipment and/or seismic sensors recording.

Underseas seismic acquisition

Method for acquiring zero offset data from a marine seismic survey. Seismic data are recorded using source signature monitor receivers located very near the air guns or other sources (). The recorded data are sorted into common-source gathers (). A common trace is computed that is common to each gather (). The common trace is subtracted from each trace in each gather (), resulting in approximately zero-offset data.

Zero offset profile from near-field hydrophones

The described invention relates to seismic acquisition means for use in shallow water marine environments, comprising: (a) a vessel () having at least one hull (); (b) one or more shaker () and baseplate () assemblies affixed to the vessel by two or more rigid supporting elements () adapted to be capable of lowering said assemblies from the vessel hull to a shallow water bottom () and of raising said assemblies from the shallow water bottom to the hull; and, wherein each of said assemblies comprise one or more vibrator units mounted on a baseplate that is adapted to rest upon the shallow water bottom and to transmit vibratory signals from the vibrator units into said water bottom. The described invention provides a high-amplitude, broadband seismic signal, provides high data-production rates, couples energy directly into the earth and minimizes damage to the water bottom.

Bottom referenced vibratory sources for shallow water acquisition

Method and apparatus for producing a bubble curtain with a diversity of bubble diameters for purposes such as modifying the characteristics of a seismic source used in marine seismic surveys. Bubble generating elements are used that combine porous wall material with discrete holes () to create a curtain of diverse-sized bubbles ().

Diverse bubble size generation

Method and apparatus for producing a bubble curtain with a diversity of bubble diameters for purposes such as suppressing surface-related multiple reflections in marine seismic surveys. Bubble generating elements are used that combine porous wall material with discrete holes.

Method for conducting a seismic survey () wherein the acquisition parameters are modified as the survey progresses using information () from sensors located to monitor structures and fixtures located in the survey area. The sensor output is compared to acceptable levels, and acquisition parameters such as the seismic source strength are adjusted () to prevent exceeding the acceptable levels. An automated arbitration scheme () is used to resolve conflicting system goals within survey resource constraints.

Data adaptive vibratory source acquisition method

An apparatus and methods are disclosed for using optical sensors to determine the position of a movable flow control element in a well control tool. A housing has a movable element disposed within such that the element movement controls the flow through the tool. An optical sensing system senses the movement of the element. Optical sensors are employed that use Bragg grating reflections, time domain reflectometry, and line scanning techniques to determine the element position. A surface or downhole processor is used to interpret the sensor signals.

Optical position sensing for well control tools

A technique for providing auxiliary conduits in multi-trip completions is disclosed. The technique has particular applicability to liner mounted screens which are to be gravel packed. In the preferred embodiment, a protective shroud is run with the gravel pack screens with the auxiliary conduits disposed in between. The auxiliary conduits terminate in a quick connection at a liner top packer. The gravel packing equipment can optionally be secured in a flow relationship to the auxiliary conduits so as to control the gravel packing operation. Subsequent to the removal of the specialized equipment, the production tubing can be run with an auxiliary conduit or conduits for connection down hole to the auxiliary conduits coming from the liner top packer for a sealing connection. Thereafter, during production various data on the well can be obtained in real time despite the multiple trips necessary to accomplish completion. The various completion and/or production activities can also be accomplished using the auxiliary conduits such as actuation of down hole flow control devices, chemical injection, pressure measurement, distributed temperature sensing through fiber optics, as well as other down hole parameters.

Method of providing hydraulic/fiber conduits adjacent bottom hole assemblies for multi-step completions

A method and apparatus for placing acoustic devices in wellbores. The method comprises: providing a tubing with at least one anchoring device in the wellbore, where the anchoring device is extendable to the wellbore to exert a force on the wellbore; attaching at least one acoustic device to at least one anchoring device; placing the tubing in the least one acoustic device attached to the at least one anchoring device in the wellbore; and setting the anchoring device to extend to the wellbore to exert a force on the wellbore, thereby coupling the acoustic device to the wellbore. The wellbore system comprises a tubing that has an annular space between the tubing and the wellbore. At least one anchoring device is disposed on an outer surface of the tubing and extends to and exerts a force on the wellbore. An acoustic device is attached to the anchoring device.

Method and apparatus for deployment, mounting and coupling of downhole geophones

One or more autonomous devices are deployed in the well to provide a moveable sensor source or obstruction for coupling a tube wave seismic signal into the formation adjacent the well bore. The autonomous devices move in the well and provide moveable obstructions or discontinuities which couple tube waves existing in the well bore or production tubing into the formation adjacent the well bore. Wellbore tube wave energy is converted to body wave energy at minor borehole obstructions or irregularities that become sources of seismic energy. A well bore may contain a plurality of minor obstructions or discontinuities. Each obstruction or discontinuity position along the borehole has an associated unique waveform source coda that may be measured for processing the wavefield radiated into the earth formation surrounding the well bore. A plurality of sensors detects the radiated seismic energy after the seismic energy has transited intervening earth formations. The system may be employed as a permanent monitoring device for mineral resource management so that measurements may be acquired at many different times. A time lapse profile may be created that is representative of the temporal and areal changes in the petrophysical characteristics and mineral content or distribution of the intervening earth formation.

Use of autonomous moveable obstructions as seismic sources

A method for identifying optimal seismic energy source configurations for a selected seismic survey area. Physical properties of the surface or near-surface soil or rock are assessed and are tested to determine the response of such soil to energy source characteristics and geometries. A test model for a source is generated and is projected to create a far-field seismic response model. A seismic event is initiated within the survey area to measure seismic data, and such measured data is compared against the far-field seismic response model. Differences can be assessed to permit modifications to the model, and the model can be tested for different types and configurations of seismic source energy sources.

Method for customizing seismic explosives

This invention provides near real-time systems and methods for acquiring seismic data in reservoirs at very high resolution such that advancing fluid fronts can be mapped substantially in real time. In one system, one or more autonomous devices are deployed in the well to detect seismic data. Each device includes at least one seismic receiver. An acoustic energy source, preferably at the surface, induces acoustic waves into the subsurface formations. The autonomous devices move in the well and detect seismic waves at selected discrete locations in the well. The seismic data is stored in on-board memory. After the data acquisition, the devices dock at a receiver stations in the well. The receiver stations download the stored data from the memory and transmit such data to a surface control unit via a two-way data link between the receiver and the surface control unit. The surface computer system also sends command signals to the downhole receiver to control the operation of the individual devices. The receiver stations can be programmed to control the operation of the devices. The devices may include resident programs to perform the survey operations at specified intervals. The data gathered by the devices is used to update existing seismic maps in determining the boundary conditions of the fluid fronts. For subsea wells, autonomous devices may also be deployed at sea bottom to travel along predefined paths to collect seismic data. A subsea control station or receiver provides power and data transmission function for the subsea devices. The seismic data from the well and the sea bottom are then used to update the 3D maps to obtain 4D maps and to model the reservoirs.

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Cypress, TX, United States of America

Michael W Norris