EP2158501A2 - Procédés pour obtenir efficacement des données sismiques de flûte remorquée en azimut large - Google Patents

Procédés pour obtenir efficacement des données sismiques de flûte remorquée en azimut large

Info

Publication number
EP2158501A2
EP2158501A2 EP08755677A EP08755677A EP2158501A2 EP 2158501 A2 EP2158501 A2 EP 2158501A2 EP 08755677 A EP08755677 A EP 08755677A EP 08755677 A EP08755677 A EP 08755677A EP 2158501 A2 EP2158501 A2 EP 2158501A2
Authority
EP
European Patent Office
Prior art keywords
marine seismic
source
advancing path
streamers
towing
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP08755677A
Other languages
German (de)
English (en)
Inventor
Nicolae Moldoveanu
Steven Fealy
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Schlumberger Technology BV
Original Assignee
Geco Technology BV
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US12/121,324 external-priority patent/US8559265B2/en
Application filed by Geco Technology BV filed Critical Geco Technology BV
Publication of EP2158501A2 publication Critical patent/EP2158501A2/fr
Withdrawn legal-status Critical Current

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Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/38—Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/10—Aspects of acoustic signal generation or detection
    • G01V2210/16—Survey configurations
    • G01V2210/165—Wide azimuth

Definitions

  • the present invention relates to the field of marine seismic data acquisition methods. More particularly, the invention relates to methods for acquiring high quality, towed-array marine seismic surveys.
  • a marine seismic acquisition survey typically involves one or more vessels towing at least one seismic streamer through a body of water believed to overlie one or more hydrocarbon-bearing formations.
  • a “marine” survey may be performed not only saltwater environments, but also in fresh and brackish waters.
  • the term “marine” is not limited to saltwater as used in this context by those in the art.
  • a high trace density and closely spaced streamers may be used.
  • Wide-azimuth towed streamer survey data is typically acquired using multiple vessels, for example: one streamer vessel and two source vessels; two streamer vessels and two source vessels; or one streamer vessel and three source vessels.
  • Many possible marine seismic spreads comprising streamers, streamer vessels, and source vessels may be envisioned for obtaining wide- or rich-azimuth survey data.
  • the present invention is directed to overcoming, or at least reducing the effects of, one or more of the problems set forth above.
  • the present invention includes a method comprising: towing a marine seismic spread including a source and a plurality of marine seismic streamers, the marine seismic streamers including a plurality of acoustic receivers, in a generally curved advancing path over a sub-sea geologic region; actively steering the marine seismic streamers through the generally curved advancing path; shooting the source while towing the marine seismic spread in the generally curved advancing path; and recording reflections from sub-sea geologic features using the receivers during the generally curved advancing path.
  • the present invention includes a method, consisting essentially of: sailing a single vessel towing a marine seismic spread including a source and a set of marine seismic streamers, the marine seismic streamers including a plurality of acoustic receivers, in a generally curved advancing path over a sub-sea geologic region; actively steering the marine seismic streamers through the generally curved advancing path; shooting the source while towing the marine seismic spread in the generally curved advancing path; and recording reflections from sub-sea geologic features using the receivers during the generally curved advancing path.
  • the invention includes a method comprising: towing a marine seismic spread including a source and a set of marine seismic streamers, the marine seismic streamers including a plurality of acoustic receivers, in a sincurve advancing path over a sub-sea geologic region; and acquiring seismic data while traveling the sincurve advancing path.
  • the invention includes a method comprising: towing a first marine seismic spread including a first source and a first set of marine seismic streamers, the marine seismic streamers including a plurality of acoustic receivers, in a first circular path over a sub-sea geologic region; and towing a second marine seismic spread including a second source and a second set of marine seismic streamers, the marine seismic streamers including a plurality of acoustic receivers, in a second, non- overlapping circular path over the sub-sea geologic region; and acquiring seismic data while traveling the generally curved advancing path.
  • the invention includes an apparatus, comprising: a tow vessel; an array of marine seismic streamers; and a computing apparatus on board the tow vessel.
  • Each streamer of the array includes: a seismic cable; a plurality of receivers disposed on the cable along the length thereof; and a plurality of steering devices.
  • the computing device receives positioning data from the marine seismic streamers and is programmed to: sail the tow vessel in a generally curved advancing path over a sub-sea geologic region; and actively steer the marine seismic streamers through the generally curved advancing path.
  • FIG. 1 is a plan, overhead schematic view of a first embodiment of the present invention
  • FIG. 2 is a computerized rendition of a plan view of the survey area covered by generally circular sail lines of the embodiment of FIG. 1 over time during a shooting and recording survey
  • FIG. 3 is a plan, overhead schematic view of a second embodiment of the present invention
  • FIG. 4 is a computer rendition illustrating offset and azimuth distribution for a subsurface area of 1000m x 1000m in accordance with one method of the invention
  • FIG. 5 is a print of a computer display screen illustrating fold, offset and azimuth distribution for a certain bin of seismic data obtained using a method of the invention
  • FIG. 6 - FIG. 9 are plan, overhead schematic views of other, alternative embodiments of the present invention
  • FIG. 11 is a plan or overhead schematic view of one embodiment of the invention in which the generally advancing path is a sinusoidal curve, or
  • FIG. 12 is a plan view of a sinusoidal curve path symmetrical with the one presented in FIG. 1;
  • FIG. 13 is another plan view of a combination of two sinusoid curves;
  • FIG. 14A - FIG. 14B show the sincurves moved in the x direction with DX
  • FIG. 14A and in the j-direction with DY (FIG. 14B) to cover the whole survey area
  • FIG. 15 is a computer simulation of several sincurves moved in x- and y- directions by DX and DY, respectively, to cover a part of the survey area
  • FIG. 16A -FIG. 16B illustrate other possible configurations if another source vessel is added to the streamer vessel for a sincurve acquisition
  • FIG. 17 illustrates that the source on the streamer vessel could be equipped with a dual source array, si and s2; however the typical source configuration for sincurve shooting geometry is a single source array
  • FIG. 18 - FIG. 19 illustrate certain advantages of the present invention
  • FIG. 20 illustrates the ratio between the real offset versus the nominal offset measured from the source to the receiver
  • FIG. 21 graphs the offset-azimuth distribution for a series of bins generated from a sincurve acquisition geometry
  • FIG. 22 is a vector offset component diagram for a sincurve acquisition
  • FIG. 23 is a plan, overhead schematic views of another embodiment of the invention employing a circular shoot
  • FIG. 24A - FIG. 24B shows a rack mounted computer system such as may be used in some aspects of the present invention.
  • the present invention relates to methods for efficiently acquiring marine seismic data, wherein "efficiency" may be considered as more cost effective in that less seismic resources are used, and provide improved seismic imaging using minimal marine seismic equipment.
  • efficiency may be considered as more cost effective in that less seismic resources are used, and provide improved seismic imaging using minimal marine seismic equipment.
  • some embodiments may employ only one vessel, although an additional source vessel may be used in other embodiments as will be explained more fully below.
  • a richer azimuth survey can be acquired with the present invention than what is acquired with techniques employed to date that are based on parallel acquisition geometry concept.
  • the technique disclosed herein may be particularly adept at acquiring wide- and/or rich azimuth marine seismic data, and acquiring such data while traversing generally curved advancing paths, which may be characterized as coil patterns or paths.
  • certain advancing paths useful in the invention may resemble overlapping circles, as in a flattened coil.
  • the time to shoot a survey may be longer with this technique compared to traditional linear surveys. If the same survey can be acquired with 4 vessel configuration sailing generally parallel the total time required may be shorter. However the total cost is higher for multiple vessel marine seismic data acquisition, and multiple vessels are not always available.
  • a distinct feature of the inventive methods is that the azimuth is changing from shot to shot. This excludes redundancy in the azimuths acquired.
  • Conventional marine acquisition in contrast, is based on a parallel acquisition geometry that implies azimuth redundancy.
  • a wider azimuth range can be acquired with conventional parallel geometry by adding extra vessels or by repeating the survey with different cross-line offsets. However both of these options add to the cost of the seismic survey.
  • source tow vessel and streamer tow vessel may be employed in accordance with the invention
  • rich- or wide-azimuth towed streamer marine seismic surveys may be acquired in accordance with the technique disclosed herein using a single streamer vessel towing multiple streamers and a minimum of one source array.
  • the methods include positioning of streamers and/or sources employing positioning apparatus or systems (for example satellite-based systems), one or more streamer steering devices, one or more source array steering devices, and/or one or more noise attenuation apparatus or systems.
  • positioning apparatus or systems for example satellite-based systems
  • One suitable system known as Q-MARTNETM and discussed further below, includes these features and may be useful in methods of the invention.
  • FIG. 1 depicts a first embodiment 10 useful in practicing one method in accordance with the present invention.
  • FIG. 1 depicts the generally curved advancing path or sail lines 2 of a seismic source 6 and streamers 4 generally circular as illustrated by the heavy dark line.
  • both the streamers 4 and the wide- or rich-azimuth source 6 are towed by the same vessel 8, although this is not required.
  • the streamers 4 generally follow the circular sail line 2 having a radius R, where R may range from about 5,500m to 7,000m or more.
  • the sail line or path 2 is not truly circular, as once the first pass is substantially complete, the spread 10 will move slightly in the j-direction (vertical) value of DY, as illustrated in FIG. 2.
  • the spread may also move in the x-direction (horizontal) by a value DX.
  • "vertical" and “horizontal” are defined relative to the plane of the drawing.
  • FIG. 2 is a computerized rendition of a plan view of the survey area covered by the generally circular sail lines of the seismic spread and method of FIG. 1 over time during a shooting and recording survey, where the displacement from circle to circle is DY in the vertical direction and DX in the horizontal direction.
  • FIG. 2 note that several generally circular sail lines 2 (only one indicated) cover the survey area.
  • the first generally circular sail line was acquired in the southeast ("SE") corner of the survey.
  • SE southeast
  • the vessel 8 shown in FIG. 1 moves along the tangent with a certain distance, DY, in vertical direction, and starts a new generally circular path 2.
  • Several generally circular curved paths 2 may be acquired until the survey border is reached in the vertical direction.
  • a new series of generally circular paths 2 may then be acquired in a similar way, but the origin will be moved with DX in the horizontal direction. This way of shooting continues until the survey area is completely covered.
  • the design parameters for practicing methods within the invention include the radius R of the circle, the radius being a function of the spread width and also of the coverage fold desired; DY, the roll in the j-direction; DX, the roll in the x- direction. DX and DY are functions of streamer spread width and of the coverage fold desired to be acquired.
  • the radius R of the circle may be larger than the radius used during the turns and is a function of the streamer spread width.
  • the radius R may range from about 5km to about 10km.
  • the radius R ranges from 6km to 7km in one particular embodiment.
  • the values of DX and Dy may be the same or different and may each range from about 500m to about 1200m or more.
  • the value of DX and DY may be selected based on the survey objectives. For instance for a development type survey DX and DY should be smaller than for an exploration survey. Also, as DX and DY determine the source sampling, processing requirements should be considered when the survey is designed.
  • FIG. 3 is a plan, overhead schematic view of a second embodiment 20 of the present invention.
  • a source tow vessel 12 towing a source 6' following a generally circular advancing path or coil path 2' is used in conjunction with a streamer tow vessel 8 towing a source 6 and streamers 4 following its own generally circular advancing path or coil path 2.
  • One possible position of source tow vessel 12 is illustrated in FIG. 3 at a radius equal to R - clR.
  • FIG. 6 illustrates a third embodiment 30, in which towing vessels are not illustrated, comprising a second source 6' traveling on the same generally circular advancing path 2 as the source 6 associated with the streamer vessel.
  • the source 6' is positioned behind the streamers 4 at a certain interval or distance /, which is not critical but may range from about 0.5Z to 2.0Z or more where L is the streamer length.
  • FIG. 4 and FIG. 5 Two possible advantages of methods of various embodiments of the present invention for acquiring rich and/or wide-azimuth towed streamer surveys are illustrated in FIG. 4 and FIG. 5. As illustrated in the computer rendition of FIG. 4, rich azimuth and offset distribution is collected, and very high fold is acquired, as is apparent in FIG. 5, a copy of a computer screen display indicating the results of a method of the present invention.
  • FIG. 7 Another possibility is for a streamer tow vessel and at least one source tow vessel to follow a generally closed curve as illustrated schematically in FIG. 7.
  • the vessels themselves are not shown in FIG. 7, only their generally advancing paths.
  • the streamer tow vessel advances on a general closed curve passing through the following points: A, B, C, D, E, F, G, H, I, J, G, K, E, L, C, M, A.
  • the streamer tow vessel starts at point A and returns to the same point.
  • the spread may move from point A a certain distance DX, in the x-direction, and DY, in the j-direction and a new curve will start as illustrated schematically in FIG. 8.
  • FIG. 8 is an example of two closed curves that are separated by DX and DY distances.
  • the way points of the second path are 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 1.
  • the closed curve could be generated as a series of tangent circles as illustrated schematically in FIG. 9.
  • the streamer tow vessel traverses 1 A of a circle and moves to the next circle ("figure 8" pattern) until the survey limit is reached. Then the vessel will traverse in reverse direction acquiring the other semi-circumferences. The next series of circles will be shifted with DX and DY in x-direction and respectively, j-direction.
  • the extent of closed curve in one direction and the total number of closed curves acquired over an area depend on the survey size.
  • the methods of the invention may be used in 4D, or time lapse, marine seismic data acquisition.
  • an acquisition shooting pattern such as the one shown in FIG. 1OA.
  • the initial survey (or baseline) is acquired with a very "tight" curved shooting pattern (three-dimensional or four-dimensional baseline).
  • This shooting pattern results in wide- or rich-azimuth seismic data.
  • This seismic data is very finely sampled and provides a good baseline exploration survey.
  • the objective of time lapse surveys is to determine the changes that are occurring in the reservoir as a result of hydrocarbon production. Therefore, in certain embodiments there is a need only to acquire enough seismic data to monitor the changes in the reservoir, and not necessarily to use the time lapse seismic to interpret the geology as in an exploration survey.
  • subsequent time lapse surveys may be acquired with a looser curved shooting pattern where the coils overlay the previous acquisition track, but are not as numerous. This is shown in FIG. 1OB, wherein the dashed curves represent traverses from the baseline survey of FIG. 1OA that are not repeated. This allows use of wide- or multi-azimuth acquisition in a cost effective way for 4D or time lapse analysis.
  • the data processing on the time lapse may be repeated in comparison to a subset of the original dataset that matches the new coil pattern that is acquired.
  • the illustrated embodiments employ QTM and Q- MARTNETM technologies.
  • QTM is the WesternGeco proprietary suite of advanced seismic technologies for enhanced reservoir location, description, and management.
  • Q-MARTNETM systems, as discussed herein, refer to the marine seismic spreads employed by WesternGeco and having an accurate positioning system; streamer steering; and advance noise attenuation capabilities.
  • the streamers are steered through their generally curved advancing paths by controlled steering from streamer steering devices.
  • each seismic acoustic receiver is determined during the turns through acoustic networks, which may or may not be full streamer length acoustic networks. This ability to control the motion of the streamers and determine positions of the receivers during turns allows the marine seismic team to gather valuable reservoir and geologic data with increased efficiency.
  • wide- and/or rich azimuth seismic survey means acquiring marine seismic data through a range of (or all) angles that a direct line from a source to a receiver makes with true north.
  • the phrase includes full- azimuth seismic surveys.
  • cluster means a plurality (i.e., more than one) of similar components that are used together.
  • seismic energy means a device for detecting seismic energy in the form of particle motion during seismic acquisition (land, marine, or transition zone environments).
  • hydrophone means a device for detecting seismic energy in the form of pressure changes under water during marine seismic acquisition
  • multicomponent refers to a combination of seismic data sensors that includes two or more closely-spaced (within a fraction of the minimal wavelength of interest) seismic sensors such as a hydrophone, a geophone, an accelerometer, or a pressure gradient configuration of hydrophones.
  • 4C refers to a particular type of multicomponent seismic data resulting from the combination of a hydrophone with three orthogonally oriented geophones or accelerometers.
  • operatively connected means directly or indirectly connected for transmitting or conducting information, force, energy, or matter.
  • streamer configurations may be useful in the invention, including conventional single component streamers and multicomponent streamers.
  • One set of streamer systems useful in the invention are those described in assignee's published United States patent application number 20060239117 Al, published October 26, 2006, and incorporated below. This published patent application describes streamer systems for acquiring seismic data including a plurality of first cable sections each employing a first sensor configuration therein, and at least one second cable section operatively connected to one or more of the first cable sections and employing a second sensor configuration therein.
  • each of the first cable sections has substantially the same length, and each of the second cable sections has a length substantially less than the length of the first cable sections.
  • the first cable sections may be operatively connected in series to substantially define a single streamer.
  • the single streamer may include at least one second cable section operatively connected in series with the first cable sections.
  • the one or more second cable sections may be positioned upstream of the first cable sections within the single streamer, or positioned between two of the first cable sections within the single streamer.
  • the single streamer may include at least one second cable section operatively connected in parallel with one or more of the first cable sections.
  • the single streamer may include three second cable sections connected in parallel with one or more of the first cable sections.
  • a plurality of streamers may be operatively connected in parallel to substantially define a streamer array.
  • the streamer array may include at least one second cable section each operatively connected in series with a plurality of the first cable sections within a single streamer. Accordingly, each series-connected second cable section may be positioned upstream of the respective first cable sections within the single streamer, or positioned between two of the first cable sections within the single streamer.
  • such a streamer array may include at least one second cable section each operatively connected in parallel with the streamers. Accordingly, each second cable section may be positioned between two of the streamers, e.g., so as to substantially define a mini-streamer.
  • Particular embodiments of streamer systems useful in the invention may employ a first sensor configuration adapted for measuring seismic data in an upper part of the frequency band of interest, e.g., having a frequency in the range of approximately 20Hz to approximately 125Hz. These embodiments may further employ a second sensor configuration adapted for measuring seismic data in a lower part of the frequency band of interest, e.g., having a frequency in the range of approximately 2Hz to approximately 20Hz.
  • 20Hz is used as a representative threshold frequency that separates an "upper” frequency portion or band from a "lower” frequency portion or band. Accordingly, the phrase “approximately 20Hz” means 20Hz+/-an appropriate margin (e.g., 10Hz).
  • the first sensor configuration may include a conventional hydrophone distribution
  • the second sensor configuration may include one or more multicomponent sensors.
  • the first sensor configuration may include a plurality of hydrophones distributed longitudinally along each first cable section.
  • the first sensor configuration may include longitudinally spaced hydrophones, or it may include longitudinally-spaced hydrophone clusters.
  • the hydrophone clusters may be arranged to define a pressure gradient configuration.
  • the hydrophone clusters may have a longitudinal spacing from one another not exceeding approximately 3.125 m.
  • the hydrophone clusters may each include at least two transversely-spaced hydrophones. Accordingly, each hydrophone cluster may include three or more hydrophones having a relatively short transverse spacing, e.g., a transverse spacing from one another not exceeding approximately 4-10 cm.
  • the first sensor configuration may include a plurality of hydrophones distributed longitudinally according to a first separation distance
  • the second sensor configuration may include a plurality of hydrophones distributed longitudinally according to a second separation distance that is substantially different from the first separation distance.
  • the first separation distance may be approximately 3.125m, 6.25m, or 12.5m.
  • the second separation distance may lie in a range of approximately 1.5m to approximately 3m.
  • the first sensor configuration may include one or more particle motion sensors therein, such as a particle velocity sensor, a pressure gradient sensor, an accelerometer, or a combination of these.
  • the second sensor configuration may include one or more particle motion sensors therein.
  • the particle motion sensors may include at least one of a particle velocity sensor, a pressure gradient sensor, an accelerometer, and a combination thereof.
  • the second sensor configuration may include one or more hydrophones.
  • the second sensor configuration may include a plurality of longitudinally- spaced hydrophone clusters. In particular embodiments, these clusters may be spaced apart by a separation distance in the range of approximately 1.5m to approximately 3m.
  • the sources used to implement various embodiments of the present invention may be practically any seismic source known to this art.
  • the source may be a conventional impulse type source, such as an airgun, or a conventional sweep source.
  • one embodiment employs the QTM and Q-MARTNETM technologies which, as mentioned above, includes the calibrated Q-MARTNETM source.
  • the invention is not so limited.
  • “spread” and the phrase “seismic spread” are used interchangeably herein and mean the total number of components, including vessels, vehicles, and towed objects including cables, sources and receivers, that are used together to conduct a marine seismic data acquisition survey, "position", when used as a noun, is broader than “depth” or lateral (horizontal) movement alone, and is intended to be synonymous with “spatial relation.” Thus “vertical position” includes depth, but also distance from the seabed or distance above or below a submerged or semi-submerged object, or an object having portions submerged. When used as a verb, "position” means cause to be in a desired place, state, or spatial relation. The term may also include orientation, such as rotational orientation, pitch, yaw, and the like. "control”, used as a transitive verb, means to verify or regulate by comparing with a standard or desired value. Control may be closed loop, feedback, feed-forward, cascade, model predictive, adaptive, heuristic, and combinations thereof.
  • controller means a device at least capable of accepting input from sensors and meters in real time or near-real time, and sending commands directly to a vessel steering sub-system, and optionally to spread control elements, and/or to local devices associated with spread control elements able to accept commands.
  • a controller may also be capable of accepting input from human operators; accessing databases, such as relational databases; sending data to and accessing data in databases, data warehouses or data marts; and sending information to and accepting input from a display device readable by a human.
  • a controller may also interface with or have integrated therewith one or more software application modules, and may supervise interaction between databases and one or more software application modules.
  • PID controller means a controller using proportional, integral, and derivative features, as further explained herein. In some cases the derivative mode may not be used or its influence reduced significantly so that the controller may be deemed a PI controller. It will also be recognized by those of skill in the control art that there are existing variations of PI and PID controllers, depending on how the discretization is performed. These known and foreseeable variations of PI, PID and other controllers are considered useful in practicing the methods and systems of the invention.
  • swipe control element means a spread component that is controllable and is capable of causing a spread component to change coordinates, either vertically, horizontally, or both, and may or may not be remotely controlled.
  • control position means we use at least a tracking point position and compare it to a pre-plot path in order to give steering commands to vessel steering elements.
  • Real-time means dataflow that occurs without any delay added beyond the minimum required for generation of the dataflow components. It implies that there is no major gap between the storage of information in the dataflow and the retrieval of that information. There may be a further requirement that the dataflow components are generated sufficiently rapidly to allow control decisions using them to be made sufficiently early to be effective.
  • “Near-real-time” means dataflow that has been delayed in some way, such as to allow the calculation of results using symmetrical filters. Typically, decisions made with this type of dataflow are for the enhancement of realtime decisions. Both real-time and near-real-time dataflows are used immediately after the next process in the decision line receives them, phrase “vessel steering sub-system” means any device or collection of components that are capable of generating commands to vessel steering elements, such as rudders, thrusters, and the like, to accomplish the intended movements of the seismic towing vessel. In some embodiments the vessel steering sub-system may include a vessel tracking computer and/or an autopilot.
  • a vessel steering sub-system may bypass conventional tracking and autopilot functions, and may be simply a vessel rudder controller, and/or a vessel thruster controller (these embodiments may be referred to as "steering the vessel directly" using the controller).
  • a vessel steering sub-system may bypass conventional tracking and autopilot functions, and may be simply a vessel rudder controller, and/or a vessel thruster controller (these embodiments may be referred to as "steering the vessel directly" using the controller).
  • all of these components tilt computer, autopilot, rudder controller, and thruster controllers may be employed.
  • the methods disclosed herein may be used in conjunction with conventional spread control devices. These devices include source steering devices and streamer steering devices. Such devices are often part of the spread and towed by the vessel. For example, a source reference point generally must be within 10m cross line of the target in order for a source steering device with an ability to move the source 10m crossline to move the source reference closer to the target.
  • Methods of the invention may incorporate one of the so-called Advance
  • a marine seismic spread includes a vessel-mounted acoustic Doppler current meter to measure at least a horizontal component of a current velocity vector at least at one location generally ahead of the seismic spread elements, and a controller adapted to use at least the horizontal component of the measured current velocity vector to control position of a seismic spread element.
  • the controller may control position either before the spread element encounters the measured current ahead of the vessel, or when the spread element passes by the point or location where the current was measured.
  • the described systems may include a seismic spread comprising one or more vessels such as towing vessels, a chase vessel, a work vessel, one or more a seismic sources, and one or more seismic streamers towed by towing vessels.
  • the streamers and sources may be separately towed or towed by the same vessel, and the acoustic Doppler current meter may be mounted on a chase vessel, a work vessel, an automated underwater vehicle ("AUV"), or a tow vessel, as long as it is able to provide the desired data, and may comprise a transducer that produces at least one beam that is horizontal and forward looking, or has a useable forward-looking horizontal component, and may be adapted to measure a current velocity vector at a point ahead of the towing vessel.
  • the controller may control position of all or some of the spread elements through commands given to spread control elements, such as deflectors, steerable birds, and the like.
  • the vessel-mounted acoustic Doppler current meter may be motion- compensated.
  • Controllers useful in the systems and methods of the invention may vary in their details.
  • One PID controller useful in the invention may be expressed mathematically as:
  • J ⁇ integrate J ⁇ integrate
  • e(t) the time derivative
  • u(t) ⁇ controller output either meters across to a tracking control device such as that known under the trade designation Robtrack/STS500, or heading to an autopilot
  • e(t) difference between wanted (planned, reference) and measured (current position, y) value
  • Td ⁇ a constant for describing the derivative part of the algorithm (the derivative part may be filtered to avoid deriving high frequencies)
  • Ti ⁇ a constant for describing the integrating part of the algorithm
  • Kp ⁇ a proportional gain constant.
  • the PID controller may be expressed as:
  • Tf ⁇ a constant describing the filtering part of the derivative part of the algorithm.
  • the z-transform may be used, meaning that the integral part of the algorithm may be approximated by using a trapezoid model of the form:
  • Model Predictive Control is an advanced multivariable control method for use in multiple input/multiple output (“MIMO”) systems.
  • MPC computes a sequence of manipulated variable adjustments in order to optimize the future behavior of the process in question.
  • MPC solves a dynamic optimization problem using a model of the controlled system, so as to optimize future behavior (at time k+l, k+2...k+n) over a prediction horizon n. This is again performed at time k+l, k+2.
  • MPC may use any derived objective function, such as Quadratic Performance Objective, and the like, including weighting functions of manipulated variables and measurements.
  • Dynamics of the process and/or system to be controlled are described in an explicit model of the process and/or system, which may be obtained for example by mathematical modeling, or estimated from test data of the real process and/or system.
  • Some techniques to determine some of the dynamics of the system and/or process to be controlled include step response models, impulse response models, and other linear or non-linear models. Often an accurate model is not necessary.
  • Input and output constraints may be included in the problem formulation so that future constraint violations are anticipated and prevented, such as hard constraints, soft constraints, set point constraints, funnel constraints, return on capital constraints, and the like.
  • the introduction of a tracking point may serve at least two purposes.
  • the vessel will in many occasions have "spare" steering capacity available. This may mean that by moving the tracking point aft of the sources, streamer front ends and consequentially also the receivers may be closer to where they should be, which may help the streamer steering devices, such as those known under the trade designation Q-FIN, available from WesternGeco, L.L.C., in achieving their steering objectives.
  • Q-FIN trade designation
  • a tracking point will not be a static point in the spread, as time varying currents may result in the center of source steering objective and the tracking point steering objective unable to be met at the same time.
  • the tracking point may be moved, either dynamically or non-dynamically, until both objectives can be met with a certain slack. The reverse might also be the case, i.e., having excess steering power resulting in moving the tracking point further aft. If the movement of the tracking point is above a predefined distance, a new set of parameters for both the controller and the feed forward controller may be used to optimize the controller performance.
  • the control systems and methods discussed herein may be used in the spread embodiments disclosed herein as well as other spread configurations.
  • the vertical distance between seismic streamers in an over/under seismic streamer pair may range from Im to 50m or more. In one particular embodiment, the vertical distance may be about 5m.
  • a selected number of hydrophones, either mounted within the seismic streamer or in/on equipment mounted onto the seismic streamer, may be used as receivers in an acoustic ranging system and thereby provide knowledge of the horizontal and vertical position of seismic streamers.
  • the streamer tow vessel and streamers may be part of a system known under the trade designation Q-MARTNETM, from WesternGeco.
  • streamers may be equipped with acoustic transmitters and point receivers for accurate position determination, employing intrinsic ranging modulated acoustics, as taught in U.S. Letters Patent 5,668,775 ("the ⁇ 775 patent”), incorporated below.
  • the streamer transmitters and point receivers may form a full-streamer-length acoustic network, wherein a unique spread spectrum code of acoustic frequencies are emitted by each of a plurality of acoustic transmitters placed within the streamers, all frequencies being within the seismic frequencies detected by the same receivers during shooting and recording, and the point receivers within the streamers are able to distinguish each transmitter's unique code.
  • Conventional streamers use arrays of hydrophones, such as 12 or 18 hydrophones per group, which are summed together in analog fashion and than recorded.
  • Systems known Q-MARTNETM use single sensors or point receivers: these are placed in the streamer at intervals, for example one every 3 m to 4m, and recorded. All point receivers route data to a computer, where digital filters are applied taking advantage of the very fine sampling of the receivers for very powerful coherent noise attenuation of line swell noise and/or streamer cable noise. During the turns the noise from marine current may be stronger, since at least portions of the streamers may be traveling cross-current. This is one reason shooting during turns is not possible with conventional streamers. With systems known as Q-MARTNETM, noise can be attenuated from each point receiver very well. Furthermore, streamers may be steered into desired positions by steering devices, as further described herein.
  • Methods of the invention may employ any number of spread control elements, which may include one or more orientation members, a device capable of movements that may result in any one or multiple straight line or curved path movements of a spread element in three dimensions, such as lateral, vertical up, vertical down, horizontal, and combinations thereof.
  • spread control elements which may include one or more orientation members, a device capable of movements that may result in any one or multiple straight line or curved path movements of a spread element in three dimensions, such as lateral, vertical up, vertical down, horizontal, and combinations thereof.
  • orientation members such as lateral, vertical up, vertical down, horizontal, and combinations thereof.
  • a "steerable front-end deflector” such as typically positioned at the front end of selected streamers, and other deflecting members, such as those that may be employed at the front end of seismic sources or source arrays, may function as orientation members in some embodiments, although they are primarily used to pull streamers and steer sources laterally with respect to direction of movement of a tow vessel.
  • Horizontal separation between individual streamers may range from 10 to about 200 meters. The horizontal streamer separation may be consistent between one streamer and its nearest neighboring streamers.
  • Horizontal and/or vertical control of streamers may be provided by orientation members (not illustrated) which may be of any type as explained herein, such as small hydrofoils or steerable birds that can provide forces in the vertical and/or horizontal planes.
  • One suitable orientation member is the device known under the trade designation Q-FINTM, available from WesternGeco L.L.C., and described in U.S. Pat. No. 6,671,223, describing a steerable bird that is designed to be electrically and mechanically connected in series with a streamer; another suitable device is that known under the trade designation DIGIBIRDTM, available from Input/Output, Inc., Stafford, Texas.
  • Other streamer positioning devices such as the devices described in U U.S. Letters Patent 3,774,570; U.S. Letters Patent 3,560,912; U.S. Letters Patent 5,443,027; U.S. Letters Patent 3,605,674; U.S. Letters Patent 4,404,664; U.S.
  • Systems used in practicing methods of the invention may communicate with the outside world, for example another vessel or vehicle, a satellite, a hand-held device, a land-based device, and the like. The way this may be accomplished varies in accordance with the amount of energy the system requires and the amount of energy the system is able to store locally in terms of batteries, fuel cells, and the like. Batteries, fuel cells, and the like may be employed, and wireless communication may be sufficient. Alternatively, or in addition, there may be a hard-wire power connection and a hard wire communications connection to another device, this other device able to communicate via wireless transmission.
  • Certain methods of the invention may work in feed-forwarded fashion with existing control apparatus and methods to position not only the tow vessels, but seismic sources and streamers.
  • Sources and streamers may be actively controlled by using GPS data or other position detector sensing the position of the streamer (e.g., underwater acoustic network), or other means may sense the orientation of one or more individual streamers (e.g. compass) and feed this data to navigation and control systems. While gross positioning and local movement of one or more tracking points, centers of sources and/or a streamer front end center may be controlled via controlling one or more tow vessels, fine control may be accomplished on some other vessel, locally, or indeed a remote location.
  • environmental information ahead of the vessel may be sent to one or more local controllers, as well as the controller for each vessel.
  • the local controllers may in turn be operatively connected to spread control elements comprising motors or other motive power means, and actuators and couplers connected to the orientation members (flaps), and, if present, steerable birds, which function to move the spread components as desired. This in turn adjusts the position of the spread element, causing it to move as desired.
  • Feedback control may be achieved using local sensors positioned as appropriate depending on the specific embodiment used, which may inform the local and remote controllers of the position of one or more orientation members, distance between streamers, a position of an actuator, the status of a motor or hydraulic cylinder, the status of a steerable bird, and the like.
  • a computer or human operator can thus access information and control the entire positioning effort, and thus obtain much better control over the seismic data acquisition process.
  • Methods of the invention comprise acquiring wide- or rich-azimuth data (as defined herein to include full azimuth data) using a streamer vessel (for example, a single streamer vessel, such as a Q- TECHNOLOGYTM streamer vessel) towing multiple streamer cables using one or more calibrated marine seismic sources (in certain embodiments Q-MARTNETM sources), wherein the streamer vessel and the one or more source arrays traverse a generally curved advancing shooting pattern. In certain embodiments one or more source arrays may traverse a smaller or larger curved pattern than the streamer vessel.
  • a streamer vessel for example, a single streamer vessel, such as a Q- TECHNOLOGYTM streamer vessel
  • calibrated marine seismic sources in certain embodiments Q-MARTNETM sources
  • the streamer vessel and the one or more source arrays traverse a generally curved advancing shooting pattern.
  • one or more source arrays may traverse a smaller or larger curved pattern than the streamer vessel.
  • the phrase "generally curved advancing path" means that the vessels and streamers travel generally in a curve, and there is an advancement in one or more of the x- and j-directions, as explained further herein.
  • the path may be expressed as a coil.
  • the curve may be circular, ovoid (including one or more ovals), elliptical (including one or more ellipses), figure 8, sinusoidal, or other curved path.
  • the path may vary within the same survey; for example, a first portion of the survey may follow an ovoid path, a second portion of the survey may follow an elliptical path, as one of many examples.
  • the subsequent paths may be different from the first or "baseline" path.
  • the phrase "tow vessel” includes both streamer tow vessels and source tow vessels; a “streamer tow vessel” means a vessel towing one or more seismic streamer cables, with or without one or more seismic sources; and “source tow vessel” means a vessel towing at least one seismic source, with or without one or more streamers.
  • Methods of the invention include those wherein there is more than one streamer in the spread, and the distance between streamers is substantially maintained by a plurality of actively controlled streamer steering devices, such as those known under the trade designation Q-FINTM, available from WesternGeco L.L.C., although the invention is not limited to this particular type of streamer steering device.
  • Q-FINTM actively controlled streamer steering devices
  • Combinations of the methods of the invention may be practiced, wherein shooting and recording during the generally curved advancing pattern is performed along with positioning the source and streamer(s) to acquire a wide- and/or rich azimuth seismic survey without the need for the spread to repeat a path once traversed.
  • Methods of the invention include those wherein split-spread seismic data is acquired by acquiring seismic data simultaneously on one or more seismic source lines, including embodiments wherein the deploying of one or more tow vessels comprises deploying a streamer tow vessel, and methods including deploying one or more source tow vessels starboard of the streamers and one or more source tow vessels positioned port of the streamers, wherein the starboard and port distances are either the same or different, and all vessels traverse their own generally curved advancing paths.
  • the generally curved advancing paths are generally circular and differ in radius by known, controlled amounts.
  • the generally curved advancing paths are generally sinusoid curves, the shape of the curves being controlled by the design parameters.
  • Other methods of the invention comprise collecting split-spread marine seismic data, comprising deploying a streamer tow vessel towing a plurality of streamers in a generally curved advancing path over a sub-sea geologic region, and deploying all of the source tow vessels on the starboard (or port) side of one or more streamer tow members to acquire wide- and/or rich azimuth seismic survey data.
  • Certain of these method embodiments may comprise deploying two or more source tow vessels port of (or starboard of) and positioned ahead of the streamers, and deploying two more source tow vessels port of (or starboard of) and positioned behind the streamers.
  • a variation of these embodiments is deploying two or more sources utilizing the same source tow vessels.
  • Other methods of the invention comprise controlling the one or more source tow vessels and/or streamer tow vessels with one or more controllers alone or in conjunction with other controllers. Certain methods of the invention may comprise towing one or more streamer tow vessels wherein the streamers are towed in configuration selected from side-by-side configuration, over/under configuration, "V" configuration, "W” configuration, or some other configuration.
  • Methods of the invention may employ multiple, in certain embodiments from 4 to 12 streamer cables, wherein the streamers may be from 1000m to about 5km in length, with a separation between streamers ranging from about 25 to about 50m.
  • Methods of the invention include those which employ so-called "split-spread" systems. These embodiments would comprise passive and/or active deflecting members, such as deflectors known in the art as MONO WINGTM, available from WesternGeco L.L.C., and other deflectors, such as door-type deflectors.
  • Methods of the invention for acquiring rich- or wide-azimuth marine seismic data may comprise one or more receiver positioning apparatus or systems, source positioning apparatus or systems, one or more streamer steering devices, one or more source array steering devices, and/or noise attenuation apparatus or systems.
  • Systems known as Q-MARTNETM include these features and may be useful in methods of the invention.
  • all methods of the invention may utilize sequential source shooting or, alternatively, two or more sources may be shot simultaneously, with the sources being encoded so that they may be distinguished during data interpretation. For the same nominal shot point interval, firing two or more sources simultaneously may reduce the shot time interval on each source line compared with sequential shooting.
  • Tracking points may be anywhere in the marine seismic spread, for example but not limited to the center of a source, a streamer front end center, a streamer back end center, a tracking point somewhere between a center of source and a streamer front end center, a center of a plurality of streamers, a front of any one streamer, and the like. Tracking points may be dynamically or non- dynamically moved within a spread to optimize a given steering strategy, particularly during data acquisition during traversal of the generally curved advancing (coil-like) paths discussed herein.
  • Controllers may be physically a part of the vessel steering subsystem or located separately from the steering sub-system, and may use some or all available information, including, but not limited to, source and vessel positions, vessel gyroscope reading, vessel compass reading, vessel speed log, streamer front end positions (if streamers are present), and historical, real-time, and future current and wind information and predictions when calculating the residual difference, and thus these may taken into consideration in the calculation of optimum vessel steering path by the vessel steering sub-system.
  • Controllers may be selected from PI controllers, PID controllers (including any known or reasonably foreseeable variations of these), and compute a residual equal to a difference between a tracking point three-dimensional (“3D") coordinate position and a pre-plot track, optionally together with current and wind measurements, to produce a set point input to a vessel steering algorithm used by a vessel steering sub-system. Controllers may compute the residual continuously or non-continuously.
  • controllers comprise more specialized control strategies, such as strategies selected from feed forward, cascade control, internal feedback loops, model predictive control, neural networks, and Kalman filtering techniques.
  • Systems and methods of the invention may be used during seismic data collection, including 3D and 4D seismic surveying.
  • Methods of the invention may include use of seismic spreads comprising one or more other vessels such as chase vessels, work vessels, and the like.
  • the streamers and sources may be separately towed or towed by the same vessel.
  • two controllers may be employed and two residuals computed.
  • the controller may compute the residual based on what the position measurement system reports as the 3D coordinate position of the tracking point. Although there may be some degree of error in the reported 3D coordinate position due to a variety of error sources, including instrument measurement error, even with the errors the tracking point may be better controlled by steering the vessel the majority of the time.
  • Methods of the invention may optionally be used in conjunction with other systems and methods. For example, if the centers of each of the sources are tracking points, their 3D coordinate positions may be determined from acoustic ranging networks, GPS, and other position sensors, and since the seismic team knows the paths each tracking point is supposed to follow based on the survey specifications, the controllers may use at least that information to calculate residuals, and a series of set points based on the residuals, for the steering algorithms of each vessel, either to steer the vessels back to the survey-specified paths, or ensure that the survey-specified paths are adhered to.
  • a full- or wide-azimuth towed streamer survey may also be acquired in accordance with the present invention using a single streamer vessel comprising multiple streamers and a minimum of one source array.
  • the methods include positioning of streamers and/or sources employing positioning apparatus or systems (for example satellite-based systems), one or more streamer steering devices, one or more source array steering devices, and/or one or more noise attenuation apparatus or systems.
  • FIG. 11 represents a sinusoidal curved path 1100 that is followed by the streamer vessel (not shown); T and A are parameters that control the shape of the curve. The extent of the curve, L, as well as T and A parameters are survey design parameters.
  • a first marine seismic spread embodiment 10 useful in practicing one method in accordance with the invention is illustrated schematically, with the generally curved advancing path or sail lines of a seismic source 6 and streamers 4 generally sincurve as illustrated by the heavy dark line. In this embodiment both streamers 4 and source 6 are towed by the same vessel (not illustrated). In other words, streamers 4 generally follow the sincurve sail line having the amplitude A and the period T.
  • the forward and reverse paths along two symmetrical sincurves are illustrated in FIG. 13.
  • the solid sinusoid path is followed by the streamer vessels in one direction and the symmetric dashed sinusoid path is followed by the streamer vessel in the opposite direction.
  • the way points are: 1,2,3,4,5,6,7,8,9 (forward direction) and 10,11,12,13,14,15 16,17,18 (reverse direction).
  • the spread may also move in the x-direction (horizontal) by a value DX.
  • FIG. 14A - FIG. 14B are computerized renditions of plan views of the survey area covered by the generally sincurve sail lines of the seismic spread and method of FIG. 11 over time during a shooting and recording survey, where the displacement from sincurve to sincurve is DY in the vertical direction and DX in the horizontal direction.
  • FIG. 15 note that several sincurves cover the survey area.
  • the starting point of the sincurves versus survey boundary is a design parameter that controls the shot density over the survey area.
  • the first sincurve sail line was acquired in the SE corner of the survey. When a first sincurve sail path is completed the vessel moves with a certain distance, DY, in vertical direction, and starts a new sincurve advancing path.
  • the design parameters for practicing methods within the invention include the sincurve parameters, A, T and L, DY, the roll in the j-direction; DX, the roll in the x-direction and the starting point of sincurves.
  • DX and DY are functions of streamer spread width and of the coverage fold desired to be acquired.
  • the amplitude A of the sincurve may be larger than the radius used during the turns and is a function of the streamer spread width.
  • the amplitude A may range from about 5km to about 10km, and may range from 6km to 7km.
  • the period T of the sincurve may range from 10km to about 25km.
  • the extent of the sincurve, L has a minimum value of TT, and a maximum value equal with the survey length or survey width and it may range from 20km to 30km.
  • the values of DX and DY may be the same or different and may each range from about 500m to about 1200m or more.
  • Methods of invention include those where a single streamer tow vessel travels along a sincurve, clockwise and counterclockwise. This could be an advantage in an area with localized strong marine currents.
  • FIG. 16A is a plan or overhead schematic view of another embodiment of the invention.
  • a source-only vessel S2 towing a source following a sincurve is used in conjunction with a source-streamer vessel Sl towing a source 6 and streamers 4 following its own sincurve.
  • the source vessel S2 travels parallel to the streamer vessel following the same sincurve advancing path.
  • One possible position of source vessel 12 is illustrated in FIG. 13 at a distance dh. The distance dh is determined by design.
  • FIG. 16B illustrates another embodiment, comprising a second source S2 traveling on the same sincurve as the source Sl associated with the streamer vessel.
  • the source S2 is positioned behind streamers 4 at a certain interval or distance L, which is not critical but may range from about 0.5Z to 2.0Z or more where L is the streamer length and is determined by design.
  • Another possible embodiment consists in using a dual source array Sl and
  • FIG. 18 is a computer rendition illustrating offset and azimuth distribution for a subsurface area of 500m x 500m in accordance with one method of the invention.
  • the azimuth-offset distribution is represented by the vector offset component diagram. It can be noticed that for all azimuths the offset distribution is similar: the inline offsets (horizontal axis) and the crossline offsets (vertical axis) have the same range; the gray colors represent the azimuths.
  • FIG. 18 is a computer rendition illustrating offset and azimuth distribution for a subsurface area of 500m x 500m in accordance with one method of the invention.
  • the azimuth-offset distribution is represented by the vector offset component diagram. It can be noticed that for all azimuths the offset distribution is similar: the inline offsets (horizontal axis) and the crossline offsets (vertical axis) have the same range; the gray colors represent the azimuths.
  • FIG. 18 is a computer rendition illustrating offset and azimuth distribution for a sub
  • 19 is a print of a computer display screen illustrating fold, offset and azimuth distribution for a series of bins generated from a sincurve acquisition geometry; it can be noticed that the azimuths from 0° to 360° (full azimuth distribution) are recorded with the same offset range.
  • FIG. 21 graphs the offset-azimuth distribution for a series of bins generated from a sincurve acquisition geometry.
  • FIG. 22 is a vector offset component diagram for a sincurve acquisition.
  • FIG. 23 illustrates an efficient method to acquire wide-azimuth surveys using coil shooting and simultaneous sources.
  • Vessel 8 and vessel 8' shoot a circular geometry over the same prospect (not shown).
  • the vessels 8, 8' are separated by an optimum distance d that could be, for example, 20 to 30km.
  • Vessel 8 shoots always every N seconds and vessel 8' shoots at N+/- ⁇ . It is noted that the value of dt can be determined based on the processing requirements. Different mathematical algorithms could be used to optimally derive the shooting sequence.
  • the total acquisition time can be reduced by 50% relative to conventional marine surveys.
  • FIG. 24A - FIG. 24B depict a rackmounted computing apparatus 2400 with which the navigation and control systems may be implemented.
  • the computing apparatus 2400 includes a processor 2405 communicating with some storage 2410 over a bus system 2415.
  • the storage 2410 may include a hard disk and/or random access memory ("RAM") and/or removable storage such as a floppy magnetic disk 2417 and an optical disk 2420.
  • RAM random access memory
  • the storage 2410 is encoded with a data structure 2425 storing the data set acquired as discussed above, an operating system 2430, user interface software 2435, and an application 2465.
  • the user interface software 2435 in conjunction with a display 2440, implements a user interface 2445.
  • the user interface 2445 may include peripheral I/O devices such as a key pad or keyboard 2450, a mouse 2455, or a joystick 2460.
  • the processor 2405 runs under the control of the operating system 2430, which may be practically any operating system known to the art.
  • the application 2465 is invoked by the operating system 2430 upon power up, reset, or both, depending on the implementation of the operating system 2430.
  • the application 2465 issues navigation commands ("NAV") to the vessel 8, 8' in accordance with its program to sail the vessel 8, 8' on the generally advancing curved path 2 and to tow the marine seismic streamers 4 and/or source 6, depending on the particular embodiment.
  • the application 2465 also, in this particular embodiment, receives positioning data ("POSITION”) from the marine seismic streamers 4 and issues steering commands ("STEERING”) to the steering devices thereon.
  • POSITION positioning data
  • STEERING steering commands
  • the nature of the software control in terms of architecture or situs is material to the practice of the invention.
  • the navigation and streamer steering may be performed by separate software components that may be, for instance, utilities or daemons.
  • this functionality may be distributed across separate computing apparatuses in some embodiments, as well.
  • the software implemented aspects of the invention are typically encoded on some form of program storage medium or implemented over some type of transmission medium.
  • the program storage medium may be magnetic (e.g., a floppy disk or a hard drive) or optical (e.g., a compact disk read only memory, or "CD ROM"), and may be read only or random access.
  • the transmission medium may be twisted wire pairs, coaxial cable, optical fiber, or some other suitable transmission medium known to the art. The invention is not limited by these aspects of any given implementation.
  • the technique disclosed herein offers a number of benefits and advantages relative to conventional practice.
  • the benefits and advantages may include: more efficient acquisition of marine seismic data, wherein "efficiency” may be considered as more cost effective in that less seismic resources are used, improved seismic imaging using minimal marine seismic equipment; some embodiments may employ only one vessel, although an additional source vessel may be used in other embodiments as will be explained more fully below; a richer azimuth survey can be acquired, i.e., a survey rich azimuth and offset distribution; reduced redundancy in azimuth in the acquired data since azimuths are different from shot to shot; a line change on the order of only a few minutes is required only for data management reasons, otherwise the survey may be acquired continuously; the number of shots acquired over the survey is larger than the number of shots acquired over the same survey by a parallel design and, depending on the design of the acquisition, the ratio could be between 1.5 to 2 times more shots for sincurve acquisition versus parallel wide-azimuth or parallel rich-azimuth acquisition
  • EP Patent Publication No. EP 0613025 entitled “A Device and Method for Positioning of Towing Systems for Use in Marine Seismic Surveys", and filed February 22, 1994, in the name of the inventor Tor Elholm.

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Abstract

L'invention concerne une technique devant être utilisée dans la prospection sismique marine qui comprend un procédé et un appareil. Dans un aspect, le procédé comprend le remorquage d'un système à propagation sismique comprenant une source de multiples flûtes sur une voie d'avancement généralement courbée, les flûtes étant activement manœuvrées. La source est chauffée et des données sont obtenues sur la courbe. Dans d'autres aspects, le procédé est effectué avec seulement une cuve unique ou sinon la voie d'avancement généralement courbée est une voie d'avancement incurvée. Le procédé peut comprendre une glissière circulaire double dans un autre aspect. Et, dans encore un autre aspect, l'invention comprend un appareil constitué d'un appareil informatique à bord d'un navire de remorquage recevant des données de positionnement des flûtes sismiques marines. Il est également programmé pour naviguer le navire de remorquage dans une voie d'avancement généralement courbée et de manœuvrer activement les flûtes sismiques marines à travers la voie d'avancement généralement courbée.
EP08755677A 2007-05-17 2008-05-16 Procédés pour obtenir efficacement des données sismiques de flûte remorquée en azimut large Withdrawn EP2158501A2 (fr)

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US12/121,324 US8559265B2 (en) 2007-05-17 2008-05-15 Methods for efficiently acquiring wide-azimuth towed streamer seismic data
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WO2008144492A3 (fr) 2009-11-05
WO2008144492A2 (fr) 2008-11-27
CN101680961A (zh) 2010-03-24
MX2009012362A (es) 2010-01-14
AU2008254856A1 (en) 2008-11-27
AU2008254856B2 (en) 2013-01-31

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