METHOD OF PROCESSING SEISMIC DATA AND METHOD OF GENERATION OF A GEOPHYSICAL DATA PRODUCT

专利摘要:
seismic data processing. a method for processing seismic data may include obtaining acquired seismic data based on trigger times rather than based on the positions of triggered source elements. seismic data may include seismic data almost continuously recorded in split records. split records can be merged into a single, nearly continuous record to produce a trace with seismic data from a single acquired line. seismic data can be processed by performing a spatial shift for each of several time samples to correct the motion of various seismic receivers.
公开号:BR102015007713B1
申请号:R102015007713-0
申请日:2015-04-07
公开日:2021-09-14
发明作者:Stian Hegna；Gregg E. Parkes
申请人:Pgs Geophysical As；
IPC主号:

专利说明:

Cross Reference With Related Orders
[0001] This application claims priority to U.S. Provisional Application 61/979,247, filed April 14, 2014, which is incorporated by reference. background
[0002] In the last few decades, the petroleum industry has invested heavily in the development of marine seismic survey techniques that produce knowledge of underground information below a body of water, in order to find and extract valuable mineral resources, such as oil. High resolution seismic images of an underground formation are useful for quantitative seismic interpretation and improved reservoir monitoring. For a typical marine seismic survey, a marine seismic survey vessel tows one or more seismic sources below the water surface and over an underground formation to be surveyed for mineral deposits. Seismic receivers can be located on or near the water bottom, such as being fixed to the water bottom or anchored so as to be near the water bed, in one or more surface marine cables towed by the source vessel, or in a or more surface marine cables towed by another vessel. The source vessel typically contains marine seismic survey equipment such as navigation control, seismic source control, seismic receiver control and recording equipment. Seismic source control can cause one or more seismic sources, which are typically air guns or marine vibrators, to produce acoustic signals at selected times (often referred to as "trigger a detonation" or "knock").
[0003] Each acoustic signal is essentially a sound wave that descends through the water and into the underground formation. At each interface between different rock types or other formations of different composition, a portion of the sound wave can be refracted, a portion of the sound wave can be transmitted, and another portion can be reflected back to the water body to propagate. to the surface. Surface marine cables towed behind the ship are generally elongated cable-like structures. Each surface marine cable includes multiple seismic receivers that detect the pressure and/or changes in particle movement in the water created by sound waves reflected back into the water from underground formations. Seismic receivers thereby measure a wave field that was basically initiated by the triggering of the seismic source. Brief Description of Drawings
[0004] Figures 1A and 1B illustrate coordinates and terminology associated with the acquisition of seismic data and/or the processing of seismic data according to one or more embodiments of the present description.
[0005] Figure 2 illustrates diagrams of a recording after the union and spatial change of the recorded seismic data according to one or more embodiments of the present description.
[0006] Figure 3 illustrates an exemplary seismic data diagram associated with the acquisition of seismic data and/or the processing of seismic data according to one or more embodiments of the present description.
[0007] Figure 4 illustrates an exemplary seismic data diagram associated with the acquisition of seismic data and/or the processing of seismic data according to one or more embodiments of the present description.
[0008] Figure 5 illustrates an exemplary seismic data diagram associated with the acquisition of seismic data and/or the processing of seismic data according to one or more embodiments of the present description.
[0009] Figure 6 illustrates an exemplary seismic data diagram associated with the acquisition of seismic data and/or the processing of seismic data according to one or more embodiments of the present description.
[0010] Figure 7 illustrates an exemplary seismic data diagram associated with seismic data acquisition and/or seismic data processing in accordance with one or more embodiments of the present description.
[0011] Figure 8 illustrates an exemplary seismic data diagram associated with seismic data acquisition and/or seismic data processing in accordance with one or more embodiments of the present description.
[0012] Figure 9 illustrates an exemplary seismic data diagram associated with seismic data acquisition and/or seismic data processing in accordance with one or more embodiments of the present description.
[0013] Figure 10 illustrates an exemplary seismic data diagram associated with seismic data acquisition and/or seismic data processing in accordance with one or more embodiments of the present description.
[0014] Figure 11 illustrates a diagram of a system for the acquisition of seismic data and/or the processing of seismic data according to one or more embodiments of the present description.
[0015] Figure 12 illustrates a diagram of a machine for the acquisition of seismic data and/or the processing of seismic data according to one or more embodiments of the present description.
[0016] Figure 13 illustrates an exemplary method for processing seismic data in accordance with one or more embodiments of the present description.
[0017] Figure 14 illustrates an exemplary method for processing seismic data in accordance with one or more embodiments of the present description.
[0018] Figure 15 illustrates an exemplary method for processing seismic data in accordance with one or more embodiments of the present description. Detailed Description
[0019] The present description is related to the acquisition of seismic data and/or processing with sequences of signal emission from the source and continuous and/or near continuous recording. Modalities of this description allow the acquisition and/or processing of seismic data with fewer limitations or minimum blasting intervals (time between blasts), minimum recording durations and/or maximum acquisition speeds when compared to other acquisition approaches and /or seismic data processing. Furthermore, the embodiments of the present description allow to output signals from the sources, such as one or more source elements, as described herein, without an indicated and/or required listen period between detonations. Modalities in this description further allow the source to trigger based on time, rather than position. Seismic data is recorded in a continuous or quasi-continuous manner and the positions of the elements of the source and/or the seismic receivers can be derived as a function of time. For example, the positions of the source elements and/or the seismic receivers can be derived based on the input of seismic data from one or more navigation systems of a marine seismic survey vessel, the positions of the source elements and/ or of seismic receivers determined as a function of time in relation to a continuous or near continuous recording start time.
[0020] It should be understood that the present description is not limited to particular devices or methods, which may vary. It is also to be understood that the terminology used here is for the purpose of describing particular modalities only and is not intended to be limiting. As used here, the singular forms of "a", "an", and "the", "a" include both singular and plural referents unless the context clearly dictates otherwise. Furthermore, the words "may" and "may" are used throughout this order in a permissive (ie, having the potential to, being capable of) sense, not in a mandatory (ie, needing) sense. The term "include" and its derivations mean "including, but not limited to". The term "coupled" means directly or indirectly connected.
[0021] The Figures here follow a numbering convention, in which the first digit or digits correspond with the Figure number in the drawing and the remaining digits identify an element or component in the drawing. Similar elements or components between different Figures can be identified by using similar digits. As will be appreciated, the elements shown in the various embodiments herein may be added, exchanged and/or deleted in order to provide various additional embodiments of the present description. Furthermore, as will be seen, the proportion and relative scale of the elements provided in the Figures are intended to illustrate certain embodiments of the present invention and are not to be considered in a limiting sense.
[0022] This description is related, in general, to the marine seismic survey field. For example, this description may have applications in marine seismic surveying, in which one or more towed sources are used to generate wave fields and seismic receivers - towed or on the ocean floor - receive the reflected seismic energy generated by the seismic sources. The description may also have application in the acquisition and/or processing of seismic data in marine seismic survey.
[0023] Figures 1A and 1B illustrate coordinates and terminology associated with the acquisition of seismic data and/or the processing of seismic data according to one or more embodiments of the present description. Figure 1A illustrates a projection or view of the xz plane 119 of an exemplary marine seismic survey vessel 109 towing a source 103 and a marine surface cable 113 located below a free surface 115. In various embodiments, the source 103 may include a or more air guns and/or marine vibrators, among others, as source elements. In practice, the source 103 and the surface marine cable 113 can be towed by the same or different ships. Figure 1A represents a snapshot, at one instant in time, of the undulating free surface 115 and the shape as a corresponding smooth wave on the surface marine cable 113. Figure 1B includes plane xy 117 and Figure 1A includes plane xz 119 of the same Cartesian coordinate system used to specify coordinate locations within the fluid volume with respect to the three geometric spatial coordinate axes, orthogonal, marked x, y, and z. The x coordinate uniquely specifies the position of a point in a direction parallel to the ship's path of motion 109 at a particular point in time and the y coordinate uniquely specifies the position of a point in a direction perpendicular to the x axis and substantially parallel to the surface free 115 on ship 109 and the z coordinate uniquely specifies the position of a point perpendicular to the xy 117 plane at a particular point in time. Geoid 123 is the hypothetical sea level surface on ship 109 and is used to define the zero elevation (ie, z = 0). Shaded disks, such as shaded disks 105-1 and 105-2, represent seismic receivers spaced along the marine surface cable 113. Seismic receivers 105 may include, for example, seismic receivers and/or electromagnetic receivers, among others. Although illustrated in a towed surface marine cable 113, the seismic receivers 105 can be located in various ocean floor cables (OBCs) and/or in knots attached near or to the bottom of the water.
[0024] Figure 1A illustrates an illustration of a detonation and wavepaths 129-1, 129-2 of source 103 at a corresponding number of seismic receivers 105-1, 105-2. Also illustrated in the corresponding number of seismic receivers 105-1, 105-2 is the arrival of a corresponding number of signals 127-1, 127-2 from source 103 reflected off free surface 115. As used herein, the "side source" may refer to some action, item or event associated with the source (not the seismic receiver), affecting a source and/or positioned near or in the same location as the source, among others. "Receiver side" can refer to the same association of actions, items or events with a seismic receiver. Figure 1A illustrates the rising wave field 133 and the direction of the falling wave field 135, as discussed further here.
[0025] Figure 1B illustrates a top plan view or xy 117 of the marine seismic survey vessel 109 towing a source 103 with source elements 103-1, 103-2, 103-3 and four separate surface marine cables 113- 1, 113-2, 113-3, 113-4 located below a free surface. Modalities are not limited to three font elements in a font, as a font can include more or fewer font elements. Some modalities can include, for example, 35 font elements in the font. In addition, the font can be one-dimensional (eg arranged in a line as shown), two-dimensional (eg arranged in a rectangular grid) or three-dimensional (eg arranged in a cube), which can be called a matrix of font elements or an array of the font. Source 103 can be of various types including, but not limited to, a small explosive charge, an electrical spark or arc, a marine vibrator and/or a seismic source gun such as an air gun, among others. Source 103 may comprise several source elements in one source configuration and may generate, without limitation, a pulse of short duration.
[0026] The modalities are not limited to a particular number of marine surface cables and may include more or less than are shown in Figure 1B. Some embodiments may include, for example, 24 or more marine surface cables. As illustrated, marine surface cables 113-1, 113-2, 113-3, 113-4 can be modeled as a planar horizontal acquisition surface located below the free surface. However, in practice, the acquisition surface may be slightly varying due to active sea currents and/or weather conditions. In other words, towed surface marine cables can also undulate as a result of dynamic fluid conditions. The coordinates of a particular seismic receiver are given by (x, y, z) considering both the xz plane 119 and the xy plane 117. In some embodiments, the seismic receiver matrix can vary in the z direction. For example, surface marine cables can be slanted, such that seismic receivers arranged farther away from the ship may be deeper than those closer to the ship. Likewise, in some embodiments, one or more of the surface marine cables may be towed to a different depth than other surface marine cables, thereby creating an acquisition volume.
[0027] Although not illustrated, the marine seismic survey vessel 109 may include equipment, referred to here generally as a "recording system" which may provide and/or include navigation control, navigation monitoring, including position determination, seismic source control, seismic source monitoring, seismic receiver control, seismic receiver monitoring, seismic data recording, time monitoring and/or time synchronization between the various control elements, monitoring and/or recording.
[0028] Although Figures 1A and 1B illustrate horizontal and/or straight trailer, examples of the present description may include circular trailer and/or spiral trailer, among other patterns. Although Figures 1A and 1B illustrate a single ship, a plurality of ships may be present, with some or all of the ships towing surface marine cables and some or all of the ships firing sources. Surface marine cables can be towed in different directions, depths and/or angles, among other differences.
[0029] The acquisition of seismic data in accordance with one or more modalities of the present description may be applicable to a plurality of seismic data acquisition operations, including towed marine seismic, ocean floor seismic, land seismic, among other implementations and/or their combinations. In modalities using ocean floor nodes and/or OBCs, towed sources can be triggered and the resulting wave field can be detected with nodal data receivers positioned on the water floor.
[0030] The acquisition of seismic data in accordance with the present description may also include the use of a single surface seismic marine cable or an OBC. Examples of the present description can also be used with three-dimensional seismic data acquisition techniques, in which, for example, more than one seismic source and/or laterally spaced marine surface cables and/or OBCs are used to acquire the seismic data.
[0031] In some examples, a ship may tow a source that can be fired at selected times. In some examples, a marine surface cable is also towed by the ship. The surface marine cable includes seismic receivers at positions spaced along the cable. Each seismic receiver can detect pressure and/or particle movement in water and/or can be responsive to changes in pressure and/or particle movement with respect to time.
[0032] In some embodiments, an OBC may include seismic receivers spaced along the OBC. Signals generated by the seismic receivers can be recorded by a recording unit for retrieval and/or further processing.
[0033] When a source is triggered, some of the acoustic energy moves downward. Some of the energy that moves downwards can be reflected from the bottom of the water, whereby the reflected energy moves upwards. Some of the energy that moves downwards also penetrates to the bottom of the water and can reach a subsurface layer threshold. Acoustic energy can be repeated from the threshold of the subsurface layer, whereby the reflected energy moves upward. Acoustic energy moving upward can be detected by seismic receivers in the surface marine cable (or the receivers in nodes and/or an OBC at or near the bottom of the water if either is used). The energy that moves up can reflect off the surface of the water, so the energy moves down again. Energy reflected from the water surface can be detected by seismic receivers, resulting in a phantom signal. Energy reflected from the surface of the water can also be reflected from the bottom of the water and thus become energy that moves upwards. In addition, acoustic energy can reflect off the water surface (becoming falling energy) and may again reflect off the water floor (becoming rising energy) several times, resulting in multiple reflections from the water layer.
[0034] As a result of all the foregoing acoustic energy interactions with water and structures below water, the acoustic energy detected by the seismic receivers, referred to as the "total wave field", includes both upwardly moving energy ( a rising wave field) and energy moving down (a falling wave field). Rise and fall wave fields can include components resulting from subsurface and/or water surface reflectors and reflections from the water floor.
[0035] Common approaches to seismic data acquisition include synchronized recording of seismic data and triggering sources and triggering sources based on position. In such approaches, recording starts just before or at the moment when sources are triggered and the duration of time recordings is set such that it is less than the time it takes to move the vessel from a source position (or " detonation point") to the next. This means that the shorter the spacing between the detonation points, the shorter the recording time. Also, the acquisition speed can be limited by the set duration of the recording and the distance between blasts. Also, the recording duration may need to be known before recording begins and this duration may remain the same throughout the recording.
[0036] In contrast, as described here, near-continuous recording can no longer include the concept of individual records tied to detonation points and the start of seismic recording can no longer be determined by the position of the source. As used here, "almost continuous" can include no significant interruptions in seismic recording. As would be understood by one of skill in the art with the benefit of this description, operational circumstances can cause intermittent gaps in records (due to equipment failure, etc.) and "almost continuous recording" should be read to include records with intermittent or periodic gaps , whether planned or unplanned, as well as records with no intermittent or periodic gaps, thus including "continuous records". For simplicity, the terms "almost continuous" and "almost continuously" will be used here and do not exclude "continuously" or "continuously". Seismic data is recorded almost continuously and can be split into records (data samples) of desired duration, possibly on board ship and/or during processing on land. From these records, it may be possible to join the records together to create longer almost continuous records. To enable such a union, the start and/or end times of records can be synchronized against a standard clock time, as described here.
[0037] When common approaches to seismic data acquisition use sources that are triggered based on position and/or positions with a specified spacing, there may be a minimum listening time required after the sources have stopped emitting signals. If sources are triggered in a distributed time mode where a trigger sequence is initiated based on position, the trigger sequence has to be completed before the source has moved to the next trigger point, where a trigger sequence is started again. This can cause limitations on the maximum acquisition speed. For example, if the desired spacing between blast points is 25 m and the minimum time between blast points is 10 seconds, then the maximum speed that the seismic vessel can typically move forward is 2.5 m/s. Triggering the sources in this way can limit how much energy can be put into the ground per unit of time.
[0038] Furthermore, it usually takes less time to recharge sources than it does to move between detonation points, so firing sources based on position can be limiting in terms of how much energy can be put into the ground in total. . In addition, sources can consist of a plurality of source elements in an array that can be fired simultaneously to produce the maximum peak output possible. This method of operation may not be very suitable in an environmental sense because too much energy is emitted in very short periods of time. Position-based source triggering can result in rate-limited blasting records, so any operators applied to records can result in edge effects at the beginning and/or end of records.
[0039] In contrast, embodiments of the present description may include trigger sources based on time, not position. In some modalities, this can result in a shorter time lag between each source trigger. In some modalities, there may not be a listening time required after a source has finished emitting signals. This can allow for unrestricted signal emission and/or detonation triggering in some examples. Additionally, single font elements can fire individually or multiple font elements can fire simultaneously or in a coordinated sequence. Processing the seismic data acquired in accordance with the present description may include determining a sequence of trigger times for the source. In addition, the position of each source element and the wave field or wave fields emitted from it can be determined as a function of time. Furthermore, the position of each of the seismic receivers can also be determined as a function of time.
[0040] The seismic data acquired from the seismic receivers can be recorded in a quasi-continuous mode, such that it is possible to create records with quasi-continuous seismic data. As described here, the times of recorded seismic data samples, the times when the sources are triggered and/or the positions of the source elements and/or seismic receivers as a function of time can be determined and/or correlated precisely by these times be synchronized. This quasi-continuous seismic data can be manipulated with less edge effects and record duration constraints when compared to other approaches.
[0041] Arrangements of the present description may allow alternatives to trigger all source elements at once. For example, in several examples, rather than triggering all font elements in a font array simultaneously, the font elements or a subset of the font elements can be triggered in sequences spread over time. This means that instantaneous peak pressure levels and sound pressure levels can be reduced compared to other approaches. This may alleviate some environmental concerns related to the seismic survey.
[0042] Furthermore, in some examples according to the present description, there may be little or no limit in terms of minimum detonation intervals, minimum recording durations and/or maximum acquisition speeds. Therefore, acquisition speed can be faster than other approaches with consequent savings in time and/or efficiency. Seismic data acquired as such may be more accurate due to closer spatial relationships.
[0043] In some cases, the air compressor capacity that is available on a tow ship can be better utilized when compared to other approaches. Because there are little or no restrictions on listening time after a source has been triggered, and because a subset of the available source elements can be triggered in predetermined sequences spread over time, onboard air compressors may not need to recharge a such large volume in the source elements for each blast. As a result, the total energy emitted in a survey can be increased and/or the signal-to-noise (S/N) ratio can be improved across the frequency range, including ultra-low frequencies.
[0044] In some examples of the present description, during seismic data processing, the depth range of a resulting seismic image can be chosen and can be greater than in other seismic data processing and/or acquisition approaches with a duration fixed record. In several examples, sources can be fired at higher spatial densities compared to other approaches and/or detonation intervals can be chosen during processing to have a finer spacing than other approaches. The methods described herein may be applicable to a variety of seismic data acquisition techniques, including towed marine seismic, ocean floor seismic and/or land seismic, among others. More details regarding how the acquisition of seismic data can be performed and how the resulting seismic data can be processed will be discussed further here.
[0045] For example, in some exemplary embodiments, the acquisition of seismic data may include recording of seismic data from geophysical receivers. As described herein, these receivers can include ocean floor receivers, land receivers and/or receivers located on a towed surface marine cable. As such, embodiments may include towing at least one surface marine cable and a plurality of source elements behind a vessel in a body of water, where the seismic receivers are located on the towed surface marine cable. As used herein, the term "receiver" is intended to mean "seismic receiver" unless otherwise described. Receivers can include hydrophones, geophones, pressure sensors, particle motion sensors, among other types of seismic sensors and/or combinations thereof. That is, in various embodiments, at least two of the plurality of font elements can be different types of font elements.
[0046] The recording of seismic data from the receivers can start before the first source is triggered and the recording system can record almost continuously the seismic data from a plurality of seismic receivers. This seismic data can be divided into records (data samples) of limited duration, such that it is possible to merge the records to create an almost continuous record. The positions of source elements and/or receivers as a function of time in relation to the start time of quasi-continuous recording can be determined, for example, based on data input from the navigation systems as monitored by the recording system. Positions can be of sufficient density such that they are not confused in a spatial or temporal sense. In other words, the positions for each time sample in the seismic records may not be necessary, as long as such information can be unambiguously interpolated from the available positions. Preferably, a portion of the positions for each font element can be determined and others interpolated.
[0047] Different source elements can be triggered at pre-set times in relation to the start of quasi-continuous recording. For example, quasi-continuous recording of seismic data received from a plurality of receivers can begin prior to triggering any of the source elements. The time interval between font element firings can be very short, such as only a few milliseconds, and in some cases font element firing may not be evenly distributed in time (with equal sized time intervals) and/or font element positions may not be evenly spaced (with equal size separations). Time intervals can be random or pseudo-random, for example. In some examples of towed receivers, the towing vessel can move at any speed as the trigger point of detonation may be based on time, not position. Detonation point depths can be different, for example, between approximately 5 and approximately 15 m, such that in the case of marine seismic surveys, the ghost diversity of the desired seismic data can be obtained to enable robust ghost elimination. As this applies to the acquisition of marine seismic data, a ghosting effect can result from reflections from the sea surface. Ghost reflections can interfere with early reflections, limiting usable bandwidth and/or data integrity.
[0048] In an exemplary modality, for each source element that is triggered, the following information can be determined: which source element was triggered; the time he started sending the signals; the wave field that was emitted (which can be determined based on supplementary information such as recordings of hydrophones near the field or some form of signature modeling/estimation based on air pressure measurements at the guns, pressure atmospheric, water temperature at gun depths, volume of air released and/or depth of source elements, etc., in the case of air guns); the depth of each font element as a function of time and/or the position of each font element as a function of time.
[0049] As mentioned, it may not be necessary to know the position of the detonation points at each time sample in the recorded seismic data or exactly at the moment when each source element is triggered, as long as the positions of the source elements are sampled with density sufficient in both a temporal and spatial sense, such that they can be interpolated to the time of interest. In various examples, clocks in the recording of seismic data, source controller and/or navigation systems and possibly others, can be precisely synchronized by the recording system, such that the times of different systems can be related to each other. Thus, in some embodiments, the positions of the source elements and/or the seismic receivers can be derived based on data input from one or more navigation systems of a marine seismic survey vessel, the positions of the source elements and /or of the seismic receivers determined entirely as a function of the relative time with the almost continuous recording start time.
[0050] In order to produce an image of the subsurface, the recorded seismic data can be processed. An exemplary approach includes performing a direct imaging of the seismic data using a separate wave field imaging (SWIM) approach. For example, both rising and falling wave fields recorded by a receiver can be used to produce seismic images based on surface multiples. This can provide complementary and useful images at a plurality of target depths. Surface geophysical analysis may be possible, for example, even in areas of very shallow water. Deep imaging around and/or below salt bodies and other complex geologies can be improved, particularly for multi-vessel survey scenarios, including wide azimuth, full azimuth, etc. Incorporating surface multiples into the imaging process can also improve subsurface illumination in several instances.
[0051] Other exemplary modalities can be used to process the recorded seismic data. Although the following exemplary approach is described in a particular order, no specific order is required to process the recorded seismic data.
[0052] If the recorded seismic data from the receivers is divided into records of limited time durations, the records can be merged, such that the seismic data which was recorded at a given receiver position is included in the same trace. In some examples, the given receiver position may include all seismic data that was recorded at a given receiver position. In contrast to other approaches, this can allow for nearly continuous recording, rather than multiple individual records incremented over time.
[0053] If the almost continuously recorded seismic data has been divided into records of limited durations, all the seismic data originally recorded almost continuously can be merged into one record. In the case of towed surface marine cables, where the receivers are moving almost continuously as a function of time, it may be useful to perform a spatial shift for each time sample to place the seismic data samples at the receiver positions at the moment in that they were recorded. In some cases, for some seismic data acquisition methodologies where the receivers are located in fixed positions for the entire duration of the quasi-continuous recording, such spatial correction may not be applicable. An example of seismic data after many seismic records have been merged and after a spatial correction has been applied to each time sample is illustrated in Figure 2.
[0054] Figure 2 illustrates diagrams 200-1, 200-2 and 200-3 of a recording after merging and spatial change of the recorded seismic data according to one or more embodiments of the present description. Diagram 200-1 illustrates an example of an almost continuous integer record after spatial changes to correct the movement of the receivers. The examples illustrated in Figure 2 include seismic data received from a common receiver at a plurality of different source positions over time. For example, Figure 2 illustrates many seconds of seismic data at one receiver position. Diagram 200-2 illustrates an enlargement of a particular time period of the record shown in diagram 200-1. Diagram 200-3 illustrates a different magnification of a particular time period of the record shown in diagram 200-1.
[0055] In the examples illustrated in Figure 2, the geometric x axes 203-1, 203-2 and 203-3 can represent a spatial position of the receivers and the geometric y axes 201-1,201-2 and 201-3 can represent time . For example, the ship with its surface marine cable towed behind moves a greater distance in diagram 200-1 as compared to diagram 200-3 because diagram 200-1 represents a longer period of time than diagram 200-3. The 200-1, 200-2, and 200-3 diagrams do not include the same aspect ratios.
[0056] The aforementioned spatial shift can be performed using an operator applied to the seismic data in a time-wavenumber domain. Spatial change includes shifting seismic data spatially in an x direction and the operator can include:
where kx is the number of horizontal waves in the x direction (typically inline) and Δxi is the distance the receiver has moved in the x direction at time t relative to the beginning of the near continuous recording. This operator can be applied as a complex multiplication in the time-wavenumber domain, and the seismic data can be transformed back to space and time via an inverse Fourier transform.
[0057] In various embodiments, after this spatial change as a function of time, the seismic data can be arranged such that each trace represents the seismic data of a common receiver position in the x direction. Any receiver-based operations, such as wavefield separation or receiver-side ghost elimination, can be performed at that point. This organization of seismic data into a quasi-continuous record can reduce edge effects when compared to conventional methods of organizing and/or processing the seismic data into individual records of limited durations.
[0058] Figure 3 illustrates a diagram 359 of exemplary seismic data associated with the acquisition of seismic data and/or the processing of seismic data in accordance with one or more embodiments of the present description. As illustrated in Figure 3 and within box 355, a trace 357 at a position of common receiver 312 may contain seismic data from a plurality of time-triggered source elements 314-1, 314-2,...,314-n different relative to the beginning of the trace of the common receiver. In some examples, the position of common receiver 312 may include the time it takes for an entire receiver to be towed through that particular position. For example, this could take 2,000 to 3,000 seconds estimated in some examples. As illustrated in Figure 3, the y-axis 304 can represent the time when a font element is triggered and the y-axis 306 can represent the position of the font element. Pressure variation at the position of receiver 312 is illustrated as line 310, while a subsurface interface can be illustrated as line 308, for example.
[0059] Figure 4 illustrates a diagram 420 of exemplary seismic data associated with seismic data acquisition and/or seismic data processing in accordance with one or more embodiments of the present description. As illustrated in Figure 4 and within box 455, a trace 457 at a position of common receiver 412 may contain the seismic data of a plurality of source elements 414-1, 414-2,...,414-n fired at different times relative to the beginning of the trace of the common receiver. For example, the y axis 404 can represent the time when a font element is triggered and the axis x 406 can represent the position of the font element. Font elements 414-1, 414-2,..., 414-n can be grouped into font formations 416-1, 416-2,...,416-m (Xs8,..., Xs1) fired at different positions with source elements fired at different times. If the time when each source element was triggered is known and its position beyond the wave field it emitted is determined, the wave field emitted from each source matrix can be calculated and/or corrected into a wave field as if it were emitted from a single point in space and time. In some instances this may be stable only if there are no deep notches in the full wave field emitted by the source array. As mentioned, the groups of source elements 414-1, 414-2,...,414-n can be considered as source formations in different spatial positions relative to the position of the common receiver 412 and the spatial information can be contained along the geometric time axis 404 of the common receiver trace 457. For example, the font array 416-3 can include the font elements 414-3, 4144, and 414-5. In some examples, different font formations may overlap and include common points, for example, matrix 416-6 and matrix 416-7 both include font element 414-8. Each source matrix may include information associated with different source positions relative to the common receiver position.
[0060] Similar to Figure 3, the y axis 404 can represent the time when a font element is triggered and the axis x 406 can represent the position of the font element. Pressure variation at the position of receiver 412 is illustrated as line 410, while a subsurface interface can be illustrated as line 408, for example. The 416-1, 416-2,...,416-m font formations can be consistent or inconsistent in size and can be of a plurality of different sizes, eg 3 font elements, 50 font elements, 100 font elements, etc., for example, depending on how they are triggered.
[0061] Figure 5 illustrates a diagram 524 of exemplary seismic data associated with the acquisition of seismic data and/or the processing of seismic data in accordance with one or more embodiments of the present description. In order to determine which font elements are included in a particular font array, a trace can be divided into time windows. As illustrated in Figure 5, a limited time window 526 of a common receiver trace was contributed by a specific set of source elements 514-1, 514-2, 514-m. These 514-1, 514-2, 514-m font elements can be thought of as a font array including any number of font elements at different positions fired at different times. The number of font elements contributing to any window can depend on the window length and/or position. Font elements may fire at unequal time intervals, so it may be that a slightly different number of fonts may fall within each window 526 (of fixed length) as it moves below the trace. The limited time window 526 can allow the seismic data to be transformed into the source array, with the appearance that all source elements 514-1, 514-2, 514-m were fired at the same time. Similar to Figures 3 and 4, the y axis 504 can represent the time when a font element is triggered and the x axis 506 can represent the position of the font element. Pressure variation at the position of receiver 512 is illustrated as line 510, while a subsurface interface can be illustrated as line 508, for example.
[0062] An operator can be defined to transform the seismic data recorded in the time window to seismic data that would have been recorded if the source elements had been fired at the same time; for example, a new matrix can be calculated. If the wave field emitted by each source element is and the time each source element was triggered relative to the common receiver trace start time is Δtn, then an operator can be applied to the receiver trace time window to convert the wavefield emitted by that source matrix into a wavefield emitted by a source matrix including the same number of source elements at the same spatial positions, each emitting a peak of the same amplitude and triggered at the same time. The operator can be applied as follows:

[0063] Alternatively, the correction can be applied using a least squares approach:
The bar above represents the complex conjugate and is a stabilization parameter to avoid division by zero. A passband filter can also be applied to limit the output range. The operator can be applied as a complex multiplication in the frequency domain and then the seismic data can be transformed back to time.
[0064] Figure 6 illustrates a diagram 630 of exemplary seismic data associated with the acquisition of seismic data and/or the processing of seismic data in accordance with one or more modalities of the present description. Diagram 630 includes seismic data resulting from the operator in equation (2) or (3) being applied. As illustrated, the operator
can convert the emitted wavefield of that source matrix including the 614-1, 614-2 and 614-m source elements fired at different times, each with an emitted wavefield that is
on a wave field emitted from an array at the same spatial position including source elements fired at the same time, each emitting a peak (or some desired limited-range ripple). For example, limited time window 632 can be illustrated as a resultant trace with the same spatial position for source elements 614-1, 614-2, and 614-m. Similar to Figure 5, the y axis 604 can represent the time when a font element is triggered and the axis x 606 can represent the position of the font element. A subsurface interface can be illustrated by line 608.
[0065] Figures 7 and 8 illustrate how the methods described with respect to Figures 5 and 6 can be repeated for a different time window to end up with a source array in a different spatial position relative to the position of the common receiver.
[0066] For example, Figure 7 illustrates a diagram 761 of exemplary seismic data associated with seismic data acquisition and/or seismic data processing in accordance with one or more embodiments of the present description. As illustrated in Figure 7, a second common receiver trace time window 736 can be considered, with some different source elements 714-1, 714-2 and 714-m at different positions relative to the common receiver position contributing to the window 736. Similar to Figure 6, the y-axis 704 can represent a time when a font element is triggered and the x-axis 706 can represent the position of the font element. A subsurface interface can be illustrated by line 708.
[0067] Figure 8 illustrates a diagram 837 of exemplary seismic data associated with the acquisition of seismic data and/or the processing of seismic data in accordance with one or more modalities of the present description. As illustrated in Figure 8, an operator can be derived that converts the wavefield emitted from the second source matrix to a wavefield emitted from another matrix at the same spatial position including source elements fired at the same time, with each emitting a peak (or some desired limited-band ripple). Similar to Figure 7, the y-axis 804 can represent the time when a font element is triggered and the x-axis 806 can represent the position of the font element. A subsurface interface can be illustrated by line 808.
[0068] These new formations, as illustrated in Figures 6 and 8, can be used to create a "common receiver cluster". As used here, a "cluster" of seismic data represents a set of traces. A common receiver cluster is a set of traces recorded at a single receiver position, where each trace in the cluster represents the detection of a wave field emitted by an individual source element at a particular position, for example, in a matrix of font elements. In some examples, traces from all positions of source elements in a source array can be collected and combined to create this common receiver grouping. In contrast, a "common blast cluster" is a set of traces related to a single position of the source element, where each trace in the cluster represents seismic data recorded at a different position on the receiver.
[0069] Figure 9 illustrates a diagram 940 of exemplary seismic data associated with the acquisition of seismic data and/or the processing of seismic data in accordance with one or more modalities of the present description. As illustrated in Figure 9, seismic data from all source element positions derived by methods associated with Figures 5 through 8 can be grouped into a common receiver grouping, in which each trace represents the displacement or lateral distance between the position of the common receiver and each source matrix. In some modalities, seismic data can be organized such that a two-dimensional operator can be applied to the seismic data. In some embodiments, seismic data can be organized such that a three-dimensional operator can be applied to the seismic data. The spacing between each trace is defined by the chosen time windows, the time between them and the ship's speed. The time windows and font formations released from these steps can be overlaid. However, a different set of font elements can contribute in each time window, so as to end up with font formations in different positions. This factor can be related to the spacing of the detonation in time and space of the entered seismic data and defines the minimum spacing between source formations released from the methods associated with Figures 5 to 8.
[0070] The example illustrated in Figure 9 includes font formations with pulses shown in lines 942-1,...,942-p. The seismic data associated with Figure 9 can allow correction of wave fields emitted by source formations by including multiple source elements at different spatial positions in a wave field emitted from a single point in space. A wave field emitted from a single point in space may be desired because of the improved spatial resolution of the resulting seismic data. This correction will be discussed further here in connection with Figure 10. In several examples, lines 942-1,...,942-p can represent pressure signals received from a reflector at the common receiver position of different source formations. Geoaxis 904 can be the geometry axis of time and geometry axis 906 is the position geometry axis.
[0071] An operator that can be applied in grouping the two-dimensional common receiver in the wavenumber-frequency domain to convert the wavefield emitted from a source array into a wavefield emitted from a single point in space without the phantom of the source can be:
where r is the sea surface reflectivity, zn is the depth of the source element n, xn is the spatial position of the source element n relative to the center of the source matrix, kx is the horizontal wave number in the direction x (inline) and kz is the vertical wave number given by:
where c is the speed of propagation of sound in water.
[0072] Alternatively, the operator expressed in equation 4 can be applied using a least squares approach:

[0073] Figure 10 illustrates a diagram 1050 of exemplary seismic data associated with the acquisition of seismic data and/or the processing of seismic data in accordance with one or more modalities of the present description. As illustrated in Figure 10, wavefields emitted by source formations can be converted to wavefields emitted from single points in space, and ghosting effects can be unrolled, for example, using equation (4) or (6 ). Two-dimensional ghosting of the seismic data can be performed, for example, as long as there is diversity in the depths of the source elements. In some examples, three-dimensional ghosting of the seismic data can be performed.
[0074] The 1050 diagram of Figure 10 includes wave fields emitted from unique positions in space, for example, as illustrated by the peaks in the lines 1052-1,...,1052-s, when compared to the pulses of Figure 9. In contrast to Figure 9, the lines 1052-1,...,1052-s can represent reflectivity as opposed to pressure, as ghost elimination has occurred, and seismic data includes wave fields emitted from single points in space rather than the font formations. In several examples, after applying the operator in the wave-frequency number domain, the seismic data can be transformed back to spacetime. Operators can be applied to the two-dimensional common receiver grouping to correct the responses of the source formations.
[0075] Thus, a processing system in accordance with various embodiments of the present description may include several non-transient machine-readable media with executable instructions to perform various actions and/or functions. In various embodiments, the processing system may include executable instructions for selecting a plurality of time slots from a near-continuous record of seismic data aided by a respective plurality of sets of source elements that define a first respective plurality of source formations, where at least two of the source elements in each of the plurality of source element sets are at different positions and are fired at different times. The processing system may include executable instructions for converting a respective first wavefield emitted by each of the first plurality of source formations into a respective second wavefield as if emitted by a second respective source array including a same number of elements source in the same spatial position, each emitting peaks of the same amplitude and triggered at the same time. The processing system may include executable instructions to create a common receiver array based on the respective second wavefield and convert the common receiver array as if emitted from a single point in space.
[0076] In various embodiments, the processing system can include executable instructions to convert the common receiver array by applying an operator to the common receiver array based on sea surface reflectivity, depth of source elements, number of waves horizontal and/or in the number of vertical waves. In various embodiments, the processing system can include executable instructions for dismembering the common receiver array based on the sea surface reflectivity, the depth of the source elements, the horizontal wavenumber, and/or the vertical wavenumber. In various embodiments, the processing system can include executable instructions for creating the common receiver array such that each trace within the common receiver array represents an offset between a common seismic receiver position and a source array. In various embodiments, the near-continuous recording of seismic data can be split records and the processing system can include executable instructions to join the record to produce a trace of seismic data from a single acquired line.
[0077] Various types of geophysical data can be generated according to various modalities of the present description. In some embodiments, geophysical data may include raw or processed data relating to, for example, almost continuously recorded seismic data received from a plurality of seismic receivers, triggering a plurality of source elements, based on time and not based on position, in a predetermined sequence of times relative to the beginning of an almost continuous recording. In some embodiments, geophysical data may include raw or processed data related to, for example, obtaining the seismic data acquired based on firing times and not based on the positions of a plurality of fired source elements, where the seismic data include seismic data recorded almost continuously in split records. Split records can be merged into a single nearly continuous record to produce a trace with the seismic data of a single acquired line. Seismic data can be processed by performing a spatial shift for each of several time samples to correct for the movement of a number of seismic receivers.
[0078] Geophysical data can be obtained and stored, that is, recorded, on a machine-readable, non-transitory tangible medium suitable for onshore import. A geophysical data product can be produced by assembling and/or processing the geophysical data offshore (ie, by equipment on a ship) or onshore (ie, at an onshore facility) within the United States or in another country. If the geophysical data product is produced offshore or in another country, it can be imported onshore to a facility in the United States. In some cases, once ashore in the United States, geophysical analysis can be performed on the geophysical data product. In some cases, geophysical analysis can be performed on the offshore geophysical data product. For example, seismic data processing can be performed from offshore data to facilitate further processing of seismic data measured offshore or on land.
[0079] Figure 11 illustrates a diagram of an example of a system 1192 for the acquisition of seismic data and/or the processing of seismic data according to the present description. As shown in the example in Figure 11, system 1192 may include a database 1198 accessible by and/or in communication with a plurality of mechanisms 1194. Mechanisms 1194 may include a registration mechanism 1196, a determination mechanism 1197, and a mechanism of action 1199, for example. System 1192 may include fewer or more mechanisms than illustrated to perform the various actions and/or functions described herein, and embodiments are not limited to the example shown in Figure 11. System 1192 may include hardware in the form of transistor logic and /or application-specific integrated circuits (ASICs), firmware and/or software, in the form of executable, machine- or computer-readable instructions (CRI/MRI). CRI/MRI can be program (programming) instructions stored on a computer or machine-readable medium (CRM/MRM) which in cooperation can form a computing device as discussed in conjunction with Figure 12.
[0080] The plurality of mechanisms 1194, such as the registration mechanism 1196, the determination mechanism 1197 and/or the action mechanism 1199, as used herein may include a combination of hardware and software, but at least include hardware that is configured to perform particular functions, tasks and/or actions. For example, the mechanisms shown in Figure 11 are used for seismic data acquisition and/or seismic data processing.
[0081] For example, recording mechanism 1196 may include hardware and/or a combination of hardware and program instructions to almost continuously record seismic data received from a geophysical receiver and action mechanism 1199 may include hardware and/or a combination of hardware and program instructions to trigger a plurality of source elements at predefined intervals relative to the beginning of the near continuous recording. For example, the plurality of source elements can be triggered at predefined irregular time intervals.
[0082] The determination mechanism 1197 may include, for example, hardware and/or a combination of hardware and program instructions to determine for each source trigger: which of the plurality of source elements is triggered; at what time each of the plurality of source elements began to emit the signals; a characteristic of a wave field in the signals emitted by each of the various source elements; the depth of each of the plurality of source elements as a function of time and/or the position of each of the plurality of source elements as a function of time. In some examples, at least two of the plurality of source elements may be located at different depths. After each of the various source elements completes the emission of the signal, there may not be an indicated listening time. For example, font elements can be triggered with a shorter time interval compared to other methods. Because the exemplary modalities in the present description have little or no indicated listening time, the imaging time can be shortened. For example, other approaches require listen times after triggering the sources and this listen time is usually the length of time that will be played back.
[0083] Once acquired, the seismic data can be processed using the plurality of mechanisms 1194. For example, the action mechanism 1199 can process the acquired seismic data based on the firing times of the plurality of triggered source elements. Seismic data can be almost continuously recorded seismic data. In some cases, when seismic data is received split into a plurality of records, the action mechanism 1199 can merge the almost continuously split seismic data recorded into one quasi-continuous record.
[0084] Seismic data processing may also include the recording mechanism 1196 obtaining data, for example, from one or more navigation systems to determine the positions of the plurality of source elements fired from within the quasi-continuous record based on time and the action mechanism 1199 can arrange the seismic data such that each quasi-continuous record represents the seismic data of a common receiver direction and can apply an operator on the arranged seismic data to convert a common receiver cluster as if emitted from a single point in space. This may also include ghosting the common receiver grouping. The action mechanism 1199 can apply an operator on the seismic data to change the seismic data spatially based on the horizontal wave number in a particular direction and a receiver moved in the same direction at a particular time relative to the beginning of the near continuous recording.
[0085] In some examples, the determination engine 1197 can determine a particular time window to parse as a font array based on and including particular font elements from within the triggered font elements, where the particular font elements are within the almost continuous record. In addition, action mechanism 1199 may apply an operator to convert a respective first wavefield emitted by each of the first plurality of source formations into a respective second wavefield as if emitted by a second respective source array including a same number of source elements in the same spatial position, each emitting peaks of the same amplitude and triggered at the same time.
[0086] Based on the respective second wave field and/or source element positions derived by applying the operator in the time window, the action mechanism 1199 can create a common receiver cluster and apply an operator on the receiver cluster common, where the operator is based on a reflectivity of the sea surface, the depth of each of the source elements within the same number of source elements, the spatial position of each of the source elements within the same number of source elements. source relative to the center of the source matrix, the horizontal wavenumber and/or the vertical wavenumber.
[0087] The examples in the present description are not limited to the exemplary mechanisms shown in Figure 11 and, in both cases, one or more described mechanisms can be combined or be a sub-mechanism of another mechanism. Also, the mechanisms shown may be far apart in a distributed computing environment, cloud computing environment, etc.
[0088] Figure 12 illustrates a diagram of an example of a machine 1282, such as a computing device, for the acquisition of seismic data and/or the processing of seismic data in accordance with the present description. Computing device 1282 may utilize hardware, software, such as program instructions, firmware, and/or logic to perform various functions, as described herein. Computing device 1282 can be any combination of hardware and program instructions configured to share information. Hardware may include, for example, a processing facility 1284 and/or a memory facility 1288, such as CRM/MRM, a database, etc. Processing facility 1284 may include, as used herein, one or more processors capable of executing instructions stored by memory facility 1288. Processing facility 1284 may be implemented on a single device or distributed across multiple devices. Program instructions, such as CRI/MRI, may include instructions stored in memory resource 1288 and executable by processing facility 1284 to perform a particular function, task, and/or action, such as the acquisition of seismic data and/or the seismic data processing.
[0089] Memory resource 1288 can be a non-transient CRM/MRM, including one or more memory components capable of storing instructions that can be executed by processing facility 1284 and can be integrated into a single device or distributed across multiples devices. In addition, memory resource 1288 can be integrated wholly or partially in the same device as processing resource 1284 or it can be separate but accessible for that device and processing resource 1284. Thus, it is noted that the computing device 1282 may be deployed on a participating device, a server device, a collection of server devices, and/or a combination of a participating device, eg, user and one or more server devices as part of a distributed computing environment, environment cloud computing, etc.
[0090] The memory resource 1288 may be in communication with the processing resource 1284 via a communication link, for example a path 1293. The communication link 1293 may provide a wired and/or wireless connection between the resource. processing 1284 and memory resource 1288.
[0091] In the example of Figure 12, the memory resource 1288 may include a plurality of modules, such as a 1285 register module, a 1287 determination module and/or an action module 1289. As used herein, a "module " can include hardware and software, such as program instructions, but includes at least program instructions that can be executed by a processing facility, such as processing facility 1284, to perform a particular task, function, and/or action, as described here. The plurality of modules can be independent modules or sub-modules of other modules. As shown in Figure 12, registration module 1285, determination module 1287, and action module 1289 can be individual modules located in a memory resource, or they can be located in separate and distinct memory resource locations, such as in a distributed computing environment, cloud computing environment, etc.
[0092] Each of the plurality of modules may include instructions which, when executed by processing facility 1284, may function as a corresponding mechanism described in conjunction with Figure 11. For example, register module 1285 may include instructions which, when performed by processing facility 1284, can function like the registration engine 1196 shown in Figure 11. Determination module 1287 can include instructions that, when executed by processing facility 1284, can function like the determination engine 1197 shown in Figure 11 In some cases, action module 1289 may include instructions that, when executed by processing facility 1284, can function like action mechanism 1199 shown in Figure 11. In various embodiments, record module 1285, determination module 1287, action module 1289, processing facility 1284, and/or memory facility 1288, among other elements described here, may be used in combination as a recording system as described here.
[0093] In several examples, the recording module 1285 can almost continuously record the seismic data received from a plurality of receivers. The action module 1289 can trigger, at predefined times relative to the start time of a quasi-continuous recording, a portion of a plurality of source elements at irregular time intervals and record the received results of the trigger. These recorded results can be used in refining the acquisition and/or processing the almost continuously recorded seismic data.
[0094] The determination module 1287 can determine, in some embodiments, the positions of a portion of the plurality of receivers as a function of time relative to the start time of the near continuous recording. For example, the positions of all receivers may not be known; rather, the positions of a portion of the receivers can be determined based on time. In some examples, determination module 1287 can determine receiver depths as a function of time relative to the start time of the near continuous recording. These depths may not all be the same; preferably, at least two of the determined depths may be different.
[0095] In some examples, the determination module 1287 may interpolate the positions of the portion of the plurality of receivers and/or another portion of the plurality of receivers with previously unknown positions. This makes it possible for only a portion of the positions to be determined based on time, rather than the positions of each of the plurality of receivers. The 1289 action module can split the almost continuously recorded seismic data into a plurality of durations and merge the split seismic data into a quasi-continuous record. This quasi-continuous recording can be used for processing the quasi-continuously recorded seismic data in some cases.
[0096] The 1289 action module can also synchronize, in some examples, the quasi-continuous recording time recording devices, a source element controller, and the navigation systems such that the times of different systems are related to each other . This synchronization can improve the precision in processing the almost continuously recorded seismic data. Therefore, the 1289 action module can be part of the recording system.
[0097] During seismic data processing, recording module 1285 can receive a quasi-continuous record of seismic data and determination module 1287 can select a plurality of time windows from a quasi-continuous record of seismic data aided by a respective plurality of sets of font elements that define a first respective plurality of font formations. In some examples, at least two of the font elements in each of the plurality of font element sets are at different positions and fire at different times.
[0098] Action module 1289 can convert a respective first wavefield emitted by each of the first plurality of source formations into a respective second wavefield as if emitted by a second respective source array including a same number of elements source in the same spatial position, each emitting peaks of the same amplitude and triggered at the same time. Action module 1289 may also create a common receiver array based on the respective second wave field to convert the common receiver array as if emitted from a single point in space. Action module 1289, in some cases, may create the common receiver array such that each dash within the common receiver array represents an offset between a common receiver position and a source matrix.
[0099] In some examples, the 1289 action module can convert the common receiver cluster by applying an operator to it based on the sea surface reflectivity, the depth of the source elements, the horizontal wavenumber, and the wavenumber vertically and similarly, it can break apart from the seismic data based on the reflectivity of the sea surface, the depth of the source elements, the horizontal wavenumber and/or the vertical wavenumber.
[00100] As previously mentioned, in some cases, seismic data can be acquired from split records. In such cases, recording module 1285 can receive the seismic data into split records and action module 1289 can merge the split records into a single, quasi-continuous record.
[00101] The modalities are not limited to the exemplary modules shown in Figure 12 and, in some cases, several modules can operate together to function as a particular mechanism. In addition, the mechanisms and/or modules of Figures 11 and 12 may be located in a single computing system and/or device or may reside in separate, distinct locations in a distributed network, computing environment, computing environments in cloud, etc.
[00102] Figure 13 illustrates an exemplary method 13101 for processing seismic data in accordance with one or more embodiments of the present description. As shown at 13104, method 13101 may include obtaining acquired seismic data based on firing times and not based on the positions of a plurality of fired source elements. Seismic data, in some cases, can include seismic data almost continuously recorded in split records. As shown at 13106, method 13101 may include joining the split records into a single continuous record to produce a trace with seismic data from a single acquired line. As shown at 13108, method 13101 may include processing the seismic data by performing a spatial shift for each of several time samples to correct for the motion of several seismic receivers. In several examples, method 13101 can be performed by a machine, such as machine 1282 illustrated in Figure 12.
[00103] As described herein, method 13101 may include determining a number of firing times a position of each of the plurality of fired source elements and/or the position of each of several seismic receivers as a function of time, where the time function includes known times relative to the start of the almost continuous recording. In some embodiments, method 13101 may include receiving the seismic data into split records and merging the split records into a single quasi-continuous record. In several modalities, the union can produce a trace with the seismic data of a single acquired line, for example, as illustrated in Figures 3 to 10.
[00104] As described here, seismic data processing can include, in various modalities, obtaining seismic data to determine the positions of the plurality of source elements fired from within the quasi-continuous record based on time, organizing the seismic data, such as that each quasi-continuous record represents the seismic data of a common seismic receiver direction and apply an operator on the arranged seismic data to convert a source matrix present in the quasi-continuous record into a plurality of source elements. In some embodiments, method 13101 may include breaking apart the seismic data.
[00105] As described here, method 13101 may include applying an operator to the seismic data to change the seismic data spatially based on a horizontal wave number in a particular direction and a receiver moved in the same direction at a particular time. relative to the beginning of the almost continuous recording. In various embodiments, method 13101 may include determining a particular time window to parse as a font array based on and including several particular font elements from within the triggered font elements, where the particular font elements are within the almost continuous register. Method 13101 may include applying an operator in the time window to convert the particular font elements in the font array including an even number of font elements, where each font element emits a peak of the same amplitude and triggered at the same time and where the operator is based on the time each source element is triggered relative to the almost continuous recording start time. In various embodiments, method 13101 can include creating a common receiver grouping based on source element positions derived by applying the operator to the time slot. Method 13101 may include, in various embodiments, applying an operator to the common receiver array, where the operator, as described herein, may be based on the reflectivity of the sea surface, the depth of each of the source elements within the same number. of font elements, in the spatial position of each of the font elements within the same number of font elements in relation to the center of the font array, in the horizontal wavenumber, in the vertical wavenumber and/or in the depth of each of the font elements within the same number of font elements.
[00106] As described here, method 13101 may include performing a spatial shift for each of several time samples to correct the motion of multiple seismic receivers and place the seismic data samples at seismic receiver positions at a time at which the seismic data was recorded. Each of the seismic receiver positions can produce a trace with seismic data from a single stationary seismic receiver position. As used here, a "seismic receiver position stationary" does not necessarily mean that the physical receiver is stationary, but that the trace represents data as if received from a receiver position that is stationary. In various embodiments, method 13101 can include, for example, selecting a time window of the trace including several particular font elements and applying an operator in the time window to define a font array including an even number of font elements each. one emitting a peak of the same amplitude and fired at the same time. In various embodiments, method 13101 can include, for example, selecting a time window of the trace, identifying which particular source elements contribute to the time window as a function of time, and applying an operator to transform a wave field. emitted by the identified source elements in the time window in another wave field that would have been emitted by the identified source elements if the identified source elements had been fired at the same time. In various modes, the time window can be moved from the beginning to the end of the trace.
[00107] As described herein, method 13101 may include, in various embodiments, creating for each of a plurality of time windows, a trace in a common seismic receiver cluster based on the seismic data of each time window and/ or create for a plurality of time windows, a common seismic receiver grouping based on a trace from each of the plurality of time windows. Method 13101 may include applying an operator to transform a wavefield emitted by the identified source elements in the time window into another wavefield that would have been emitted by the identified source elements had the identified source elements been located at a single point in space. In some embodiments, method 13101 may include applying an operator to break apart the seismic data.
[00108] Figure 14 illustrates an exemplary method 14110 for processing seismic data according to one or more modalities of the present description. As shown at 14112, method 14110 may include obtaining acquired seismic data based on firing times and not based on the positions of a plurality of fired source elements, wherein the seismic data includes almost continuously recorded seismic data. As shown at 14114, method 14110 may include processing the seismic data by applying an operator to the seismic data to shift the seismic data spatially in a particular direction based on the horizontal wave number and a distance that a seismic receiver has moved in the particular direction in a time relative to the beginning of almost continuous recording.
[00109] As described here, method 14110 may include organizing the seismic data such that each trace represents the seismic data of a common receiver position in the particular direction. The method may include breaking apart the seismic data based on the position of the common receiver.
[00110] Figure 15 illustrates an exemplary method 15120 for processing seismic data in accordance with one or more embodiments of the present description. As shown at 15122, method 15120 may include obtaining acquired seismic data based on firing times rather than based on the positions of a plurality of fired source elements, wherein the seismic data includes almost continuously recorded seismic data. As shown at 15124, method 15120 may include processing the seismic data. As shown at 15126, processing may include identifying the source elements that contribute to each of a plurality of time slots of the same length in a trace of the seismic data. As shown at 15128, processing may include applying an operator to the seismic data in each of the plurality of time windows to transform the seismic data as if the source elements were fired at the same time, wherein the operator is based on the time that each source element is triggered relative to the almost continuous recording start time.
[00111] As described herein, method 15120 may include creating a common seismic receiver cluster based on source element positions derived from the application of the operator. Method 15120 may include applying an operator to the array of the common seismic receiver, where the operator is based on the reflectivity of the sea surface, the depth of each of the source elements, the spatial position of each of the source elements in relation to at the center of the source array, the horizontal wavenumber, the vertical wavenumber, and the depth of each of the source elements.
[00112] Although specific modalities have been described above, these modalities are not intended to limit the scope of the present description, even where only a single modality is described with respect to a particular feature. Examples of features provided in the description are intended as illustrative rather than restrictive, unless stated otherwise. The above description is intended to cover such alternatives, modifications, and equivalents as would be evident to one skilled in the art having the benefit of that description.
[00113] The scope of this description includes any feature or combination of features disclosed herein (explicitly or implicitly), or any generalization thereof, whether or not it ameliorates any or all of the problems addressed here. Various advantages of the present description have been described herein, but embodiments may provide some, all, or none of such advantages or may provide other advantages.
[00114] In the foregoing detailed description, some features are grouped into a single modality for the purpose of improving the description. This method of description is not to be interpreted as reflecting an intention that the disclosed embodiments of the present description are to use more features than are expressly recited in each claim. Preferably, as the following claims reflect, the inventive subject matter falls within less than all of the features of a single disclosed embodiment. Thus, the following claims are hereby incorporated into the detailed description, with each claim sufficing as a separate embodiment.

权利要求:
Claims (13)
[0001]
1. Method (13101), characterized in that it comprises: obtaining (13104), from a number of seismic receivers (105), seismic data indicative of an underground formation acquired based on firing times and not with based on the positions of a plurality of source elements (314, 414, 514, 614, 714, 814) fired, where the seismic data includes seismic data almost continuously recorded in split records, join (13106), by a machine (1282), records split into a single nearly continuous record to produce a trace (357, 457) with seismic data from a single acquired line; and processing (13108), by the machine (1282), the seismic data by: determining positions of the plurality of source elements (314, 414, 514, 614, 714, 814) fired from within the near continuous recording based on time ; perform a spatial shift based on the determined positions of each of the plurality of source elements (314, 414, 514, 614, 714, 814) fired and a distance moved from a previous location at a particular time by each of the numbers of seismic receivers (105) with respect to the beginning of recording the almost continuously recorded seismic data for each of a number of particular times to correct the movement of the number of seismic receivers (105) and produce seismic data more indicative of underground formation; organizing the seismic data so that each quasi-continuous record represents seismic data from a common seismic receiver position (312, 412); and applying an operator to the arranged seismic data to convert a source matrix present in the nearly continuous record into a plurality of source elements (314, 414, 514, 614, 714, 814).
[0002]
2. Method (13101) according to claim 1, characterized in that it further comprises determining for a number of shooting times the positions of the seismic receiver as a function of time in known times relative to a start of recording almost continuous.
[0003]
3. Method (13101), according to claim 1, characterized in that joining includes producing a trace (357, 457) respectively for each of the positions of the seismic receiver; and wherein processing the seismic data results in the respective trace (357, 457) representing seismic data as if received from a single stationary seismic receiver position.
[0004]
4. Method (13101) according to claim 3, characterized in that it further comprises: selecting a time window (526, 632, 736) of the trace (357, 457) including contributions from a number of elements of particular font (314, 414, 514, 614, 714, 814); and applying a different operator to the time window (526, 632, 736) to define a source array including the same number of source elements (314, 414, 514, 614, 714, 814) each emitting a peak of the same amplitude and fired at the same time.
[0005]
5. Method (13101), according to claim 3, characterized in that it further comprises: selecting a time window (526, 632, 736) of the trace (357, 457); identifying which particular source element bursts (314, 414, 514, 614, 714, 814) contribute to the time window (526, 632, 736) as a function of time; and applying an operator to transform a wave field (133, 135) emitted by triggers from source elements (314, 414, 514, 614, 714, 814) identified in the time window (526, 632, 736) into another field waveform (133, 135) that would have been emitted by the identified source elements (314, 414, 514, 614, 714, 814) had the identified source elements (314, 414, 514, 614, 714, 814) been identified. fired at the same time.
[0006]
6. Method (13101) according to claim 5, characterized in that the time window (526, 632, 736) is moved from the beginning to the end of the trace (357, 457).
[0007]
7. Method (13101) according to claim 5, characterized in that it further comprises creating: for each of a plurality of time windows, a trace (357, 457) in a common seismic receiver array (312, 412) based on the seismic data of each time window (526, 632, 736); and for a plurality of time windows, a common seismic receiver array (312, 412) based on a trace (357, 457) of each of the plurality of time windows.
[0008]
8. Method (13101) according to claim 7, characterized in that it further comprises applying a different operator to transform a wave field (133, 135) emitted by the source element triggers (314, 414, 514, 614, 714, 814) identified in the time window (526, 632, 736) in another wave field (133, 135) that would have been emitted by the source elements (314, 414, 514, 614, 714, 814 ) identified if the identified source elements (314, 414, 514, 614, 714, 814) had been located at a single point in space.
[0009]
9. Method (13101), according to claim 8, characterized in that it further comprises applying another different operator to dismember the seismic data.
[0010]
10. Method (13101), according to claim 1, characterized in that it obtains seismic data acquired based on firing times and not based on the positions of a plurality of source elements (314, 414, 514, Triggered 614, 714, 814) further comprises obtaining acquired seismic data based on trip times and not based on positions of a plurality of triggered impulsive source elements (314, 414, 514, 614, 714, 814).
[0011]
11. Method (13101) according to claim 1, characterized in that it further comprises determining for a number of firing times a position of each of the plurality of source elements (314, 414, 514, 614 , 714, 814) triggered as a function of time at known times with respect to the beginning of near-continuous recording.
[0012]
12. Method of generating a geophysical data product, the method characterized by the fact that it comprises: obtaining geophysical data through: obtaining, from a number of seismic receivers (105), seismic data indicative of an underground formation acquired on a time basis firing and not based on the positions of a plurality of fired source elements (314, 414, 514, 614, 714, 814), the seismic data including almost continuously recorded seismic data; uniting, by a machine (1282), the divided records into a single nearly continuous record to produce a trace (357, 457) with seismic data from a single acquired line; processing the geophysical data to generate a geophysical data product, the processing comprising: determining positions of the plurality of source elements (314, 414, 514, 614, 714, 814) fired from within the near-continuous record based on time; processing, by the machine (1282), the seismic data by performing a spatial shift based on the determined positions of each of the plurality of fired source elements (314, 414, 514, 614, 714, 814) and a moved distance of one previous location at a particular time by each of the numbers of seismic receivers (105) with respect to the beginning of recording the almost continuously recorded seismic data for each of a number of particular times to correct the movement of the number of seismic receivers (105) and to produce seismic data more indicative of underground formation; organizing the seismic data such that each quasi-continuous record represents seismic data from a common seismic receiver position (312, 412); and applying an operator to the arranged seismic data to convert a source array present in the near-continuous records into a plurality of source elements (314, 414, 514, 614, 714, 814) and record the geophysical data product in medium readable by non-transient machine.
[0013]
13. Method according to claim 12, characterized in that processing geophysical data comprises processing offshore or onshore geophysical data.

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法律状态:
2015-12-29| B03A| Publication of a patent application or of a certificate of addition of invention [chapter 3.1 patent gazette]|

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2018-10-30| B06F| Objections, documents and/or translations needed after an examination request according [chapter 6.6 patent gazette]|

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2020-04-22| B06U| Preliminary requirement: requests with searches performed by other patent offices: procedure suspended [chapter 6.21 patent gazette]|

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2021-08-03| B09A| Decision: intention to grant [chapter 9.1 patent gazette]|

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2021-09-14| B16A| Patent or certificate of addition of invention granted [chapter 16.1 patent gazette]|Free format text: PRAZO DE VALIDADE: 20 (VINTE) ANOS CONTADOS A PARTIR DE 07/04/2015, OBSERVADAS AS CONDICOES LEGAIS. |

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