阅读说明：本技术 利用地震振动器阵列的波场产生 (Wavefield generation using seismic vibrator arrays ) 是由 D.F.哈利迪 J-F.霍珀斯塔德 R.M.劳斯 于 2015-03-19 设计创作，主要内容包括：本发明公开了利用地震振动器阵列的波场产生。具体地,本发明涉及一种海洋地震勘测方法、一种计算机系统和一种制品。海洋地震勘测方法包括：在一个或多个空间位置,激活阵列中的至少两个地震振动器以异相产生源梯度波场；在一个或多个其它的空间位置,在不同的时刻,激活所述至少两个地震振动器以同相产生大致单极源波场。地震振动器设置在水体中的多个深度处,其中,在第一深度处的地震振动器以第一频率发射,在第二深度处的地震振动器以更低的第二频率发射。控制位于第一深度处的地震振动器以在不同次的发射中提供源梯度波场和单极源波场,并且,控制位于大于第一深度的第二深度处的地震振动器以在不同次的发射中仅提供更低频率的单极源波场。(Wavefield generation using an array of seismic vibrators is disclosed. In particular, the invention relates to a marine seismic survey method, a computer system and an article of manufacture. A marine seismic survey method comprising: activating at least two seismic vibrators in the array to produce source gradient wavefields out of phase at one or more spatial locations; at one or more other spatial locations, at different times, the at least two seismic vibrators are activated to produce substantially monopole source wavefields in phase. The seismic vibrators are disposed at a plurality of depths in the body of water, wherein the seismic vibrators at a first depth emit at a first frequency and the seismic vibrators at a second depth emit at a second, lower frequency. The seismic vibrators located at a first depth are controlled to provide a source gradient wavefield and a monopole source wavefield at different times of emission, and the seismic vibrators located at a second depth greater than the first depth are controlled to provide a monopole source wavefield at only lower frequencies at different times of emission.)

1. A marine seismic survey method comprising:

activating (304) two or more seismic vibrators (106) in a seismic vibrator array (104) at one or more spatial locations to generate source gradient wavefields (406) out of phase to survey a target structure (116),

wherein activating the seismic vibrators of the seismic vibrator array comprises providing activation signals to the seismic vibrators of the seismic vibrator array, wherein a first output signal produced by one of the at least two seismic vibrators is out of phase with respect to a second output signal produced by another of the at least two seismic vibrators,

wherein the first and second output signals are in opposite directions, or

Wherein the first and second output signals have a phase difference whose cosine is less than zero; and is

Activating the at least two seismic vibrators in the seismic vibrator array at different times at one or more other spatial locations to produce substantially monopole source wavefields (406) in phase to survey the target structure,

characterized in that the seismic vibrators in the seismic vibrator array are arranged at a plurality of depths (D1, D2, D3) in the body of water (100), wherein the seismic vibrators at a first depth of the plurality of depths emit at a first frequency and the seismic vibrators at a second depth of the plurality of depths emit at a second, lower, frequency, and

the seismic vibrators (106) located at a first depth are controlled to provide a source gradient wavefield (406) and a monopole source wavefield (404) in different shots, and wherein the seismic vibrators located at a second depth greater than the first depth are controlled to provide a monopole source wavefield (404) at only a lower frequency in the different shots.

2. The method of claim 1, wherein generating the source gradient wavefield (406) and generating the monopole wavefield (404) are part of a pattern of monopole source wavefields (404) and source gradient wavefields (406) generated in response to activating seismic vibrators (106) in the seismic vibrator array (104).

3. The method of claim 1, wherein the at least two seismic vibrators (106) are separated by a distance (L1, L2) in the direction of the source gradient wavefield (406) that is less than half of a target minimum wavelength.

4. The method of claim 3, wherein the seismic vibrators (106) are spaced apart a distance (L1, L2) that matches a frequency range of emissions at each depth level (D1, D2, D3).

5. The method of claim 1, further comprising:

deghosting is performed using unipolar source data acquired in response to a unipolar source wavefield (404) and source gradient data acquired in response to the source gradient wavefield (406).

6. The method of claim 1, further comprising:

multi-component imaging is performed using unipolar source data acquired in response to a unipolar source wavefield (404) and source gradient data acquired in response to the source gradient wavefield (406).

7. The method of claim 1, further comprising:

a super-nyquist source reconstruction is performed using unipolar source data acquired in response to a unipolar source wavefield (404) and source gradient data acquired in response to the source gradient wavefield (406).

8. A computer system (800), comprising:

at least one processor (804) configured to:

activating two or more marine seismic vibrators (106) in a marine seismic vibrator array (104) at one or more spatial locations to generate source gradient wavefields (406) out of phase to survey a target structure (116);

wherein activating the seismic vibrators in the array of marine seismic vibrators comprises providing activation signals to the marine seismic vibrators in the array of seismic vibrators, wherein a first output signal produced by one of the at least two seismic vibrators is out of phase with respect to a second output signal produced by another of the at least two seismic vibrators,

wherein the first and second output signals are in opposite directions, or

Wherein the first and second output signals have a phase difference whose cosine is less than zero; and is

Activating the at least two seismic vibrators in the marine seismic vibrator array at different times at one or more other spatial locations to produce substantially monopole source wavefields (404) in phase to survey the target structure,

characterized in that the seismic vibrators in the seismic vibrator array are arranged at a plurality of depths (D1, D2, D3) in the body of water (100), wherein the seismic vibrators at a first depth of the plurality of depths emit at a first frequency and the seismic vibrators at a second depth of the plurality of depths emit at a second, lower, frequency, and

the seismic vibrators (106) at a first depth are controlled to provide a source gradient wavefield (406) and a monopole source wavefield (404) in different shots, and wherein the seismic vibrators (106) at a second depth greater than the first depth are controlled to provide only a lower frequency monopole source wavefield (404) in different shots.

9. The computer system (800) of claim 8, wherein the at least two marine seismic vibrators (106) are separated in the direction of the source gradient wavefield (406) by a distance (L1, L2) that is one-third to one-half of a target shortest wavelength (L1, L2).

10. The computer system (800) of claim 8, wherein the at least one processor (804) is configured to further:

controlling the phase of at least a portion of the marine seismic vibrators (106) in the array (104) of marine seismic vibrators in different shots to provide residual noise reduction between successive shots.

11. The computer system (800) of claim 8, wherein the at least one processor (804) is configured to further:

one or more of deghosting, multi-component imaging, and cross-line source reconstruction are performed using unipolar source data acquired in response to a unipolar source wavefield (404) and source gradient data acquired in response to the source gradient wavefield (406).

12. An article of manufacture comprising at least one non-transitory computer-readable storage medium (812) storing instructions that, when executed, cause a system (800) to perform the method of claim 1.

Background

Seismic surveys may be used to identify subsurface target components, such as hydrocarbon reservoirs, fresh water layers (fresh water aquifers), gas injection zones (gas injection zones), and the like. In a seismic survey, a seismic source is activated to generate seismic waves that are directed into a subsurface structure.

Seismic waves generated by a seismic source are transmitted into the subsurface structure, and a portion of the seismic waves are reflected back to the surface for receipt by seismic receivers (e.g., geophones, hydrophones, accelerometers, etc.). These seismic receivers record/generate signals representative of the detected seismic waves. Signals from the seismic receivers are processed to derive information about the contents and properties of the subsurface structures.

Marine survey arrangements may include towing streamers of seismic receivers through a body of water, or placing ocean bottom cables or other arrangements of seismic receivers on the ocean floor.

Disclosure of Invention

An overview of certain embodiments disclosed herein is given below. It should be understood that these aspects are presented merely to provide the reader with a brief summary of these embodiments and that these aspects are not intended to limit the scope of this disclosure. Indeed, this disclosure may encompass a variety of aspects that may not be set forth in this summary.

In some embodiments of the present disclosure, seismic vibrators in a seismic vibrator array are activated, the activation causing at least two seismic vibrators to be out of phase, thereby generating a source gradient wavefield to survey a target structure.

Further or alternative features will become apparent from the following description, the drawings and the claims.

Drawings

The present disclosure is described with reference to the accompanying drawings. It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale. In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.

FIG. 1 is a side view schematic diagram of a marine survey arrangement according to some embodiments.

FIG. 2 is a schematic diagram of a rear view of a marine survey arrangement including an array of seismic vibrators, according to some embodiments.

FIG. 3 is a flow diagram of a survey process according to some embodiments.

FIGS. 4-6 illustrate exemplary activation patterns of a seismic vibrator array according to various embodiments.

FIG. 7 is a schematic diagram of one example of a reconstructed source according to some embodiments.

Fig. 8 is a block diagram of a computer system, according to some examples.

In the drawings, similar components and/or features may have the same reference numerals. Further, components of the same type may be distinguished by the following reference numerals by a dash and a second numeral that distinguish between similar components. If only the first reference label is used in the specification, the description is applicable to any one of the similar components having the same first reference label irrespective of the second reference label.

Detailed Description

The following description provides preferred exemplary embodiments only, and is not intended to limit the scope, applicability, or configuration of the invention. Rather, the following description of the preferred exemplary embodiments will provide those skilled in the art with a description of the preferred exemplary embodiments which enables the practice of the invention. It should be understood that various changes can be made in the function and arrangement of elements without departing from the spirit and scope of the invention as set forth in the appended claims.

In the following description, specific details are given to provide a thorough understanding of the embodiments. However, it will be understood by those of ordinary skill in the art that the embodiments may be practiced without these specific details. For example, circuits may be shown in block diagrams in order not to obscure the embodiments in unnecessary detail. In other instances, well-known circuits, processes, algorithms, structures, and techniques may be shown without unnecessary detail in order to avoid obscuring the embodiments.

Furthermore, it is noted that the embodiments may be described as a process which is depicted as a flowchart, a flow diagram, a data flow diagram, a structure diagram, or a block diagram. Although a flowchart may describe the operations as a sequential process, many of the operations can be performed in parallel or concurrently. In addition, the order of the operations may be rearranged. A process ends when its operations are completed, but there may be other steps not included in the figures. A process may correspond to a method, a function, a procedure, a subroutine, a subprogram, etc. When a procedure corresponds to a function, its termination corresponds to the return of the function to the calling function or the main function.

In addition, the term "storage medium" as disclosed herein may represent one or more devices for storing data, including Read Only Memory (ROM), Random Access Memory (RAM), magnetic RAM, core memory, magnetic disk storage media, optical storage media, flash memory devices, and/or other machine readable media for storing information. The term "computer-readable medium" includes, but is not limited to portable or fixed storage devices, optical storage devices, wireless channels and various other mediums capable of storing, containing or carrying instruction(s) and/or data.

Furthermore, embodiments may be implemented by hardware, software, firmware, middleware, microcode, hardware description languages, or any combination thereof. When implemented in software, firmware, middleware or microcode, the program code or code segments to perform the necessary tasks may be stored in a machine readable medium such as a storage medium. One or more processors may perform the necessary tasks. A code segment may represent a procedure, a function, a subprogram, a program, a routine, a subroutine, a module, a software package, a class, or any combination of instructions, data structures, or program statements. A code segment may be coupled to another code segment or a hardware circuit by passing and/or receiving information, data, arguments, parameters, or memory contents. Information, arguments, parameters, data, etc. may be passed, forwarded, or transmitted via any suitable means including memory sharing, message passing, token passing, network transmission, etc.

It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of some of the elements and arrangements are described below to simplify the present disclosure. Of course, these are merely examples and are not intended to be limiting. Moreover, the present disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed. Additionally, forming a first feature over a second feature in the description that follows may include embodiments in which the first feature is formed in direct contact with the second feature; embodiments may also be included in which additional features may be formed between the first and second features, such that the first and second features are not in direct contact.

Survey equipment including one or more seismic sources and seismic receivers may be used to conduct surveys of the target structure. In some examples, the target structure may be a subsurface structure below the surface of the earth. Such subterranean structures may be surveyed for a variety of purposes, such as to identify subterranean target constituents, including hydrocarbon reservoirs, freshwater layers, gas injection zones, or other subterranean target constituents.

Although reference is made to surveying subsurface structures, techniques or mechanisms according to some embodiments may also be applicable to surveying other structures, such as human tissue, plant tissue, animal tissue, mechanical structures, solid volumes, liquid volumes, gas volumes, plasma volumes, and the like.

Different types of seismic sources may be employed. For example, the seismic source may include an air gun that, when activated, releases compressed air to generate pulses of acoustic energy. Another type of seismic source is a seismic vibrator that generates acoustic energy based on the vibration of a vibratory element, which affects structures in the seismic vibrator. The vibration of the vibratory element may be controlled by an activation signal, which may be a sine wave signal or other type of signal that causes the vibratory element to vibrate.

The phase of the activation signal may be controlled for a variety of purposes, such as for noise reduction or for other purposes. In general, a seismic vibrator refers to any seismic source that generates a wavefield in response to activation signals, the phases of which are independently adjustable at each frequency. In particular, the vibrator may be a volumetric seismic source (i.e. it generates a wave field by changing its volume.

Traditionally, a seismic source (or set of seismic sources) is activated such that the seismic source produces a substantially monopole source wavefield. A monopole wavefield is a wavefield that radiates energy substantially equally in all directions. In practice, the directivity is adjusted by the aperture effect of the source array (since the source array usually comprises sources at different horizontal and/or vertical positions), and also by the interference effect of the sea surface if said sources are located adjacent to the sea surface. In order to produce a substantially monopole wavefield using a seismic vibrator array comprising a plurality of seismic vibrators, the seismic vibrators may be controlled to be in phase with respect to each other. For example, if all vibrators are at the same depth, no two vibrators in the array have a phase difference with a cosine less than zero. A seismic vibrator array may refer to any arrangement of a plurality of seismic vibrators.

According to some embodiments, in addition to producing a substantially monopole source wavefield, the seismic vibrator array may be controlled to produce a source gradient wavefield. The source gradient wavefield is a wavefield having a substantially different radiation pattern than the monopole source wavefield. Whereas a monopole source wavefield radiates energy equally in all directions, a gradient source radiates energy with different polarities in different directions. For example, if the gradient sources are oriented in the y-direction, the wavefield will have a positive polarity in the positive y-axis direction and a negative polarity in the negative y-axis directionAnd (4) a pole. Thus, the source has zero output in at least one direction in which the transition from positive to negative occurs. If the time domain wavefield generated by a source with y1 bits is defined as S (y)₁T), then the gradient of the wavefield in the y-direction is dS (y)_1，t) And/dy. While it may not be possible to produce a wavefield that corresponds exactly to this derivative term, it may be approximated as the difference of two monopole sources at the same depth:

dS(y₁，t)/dy≈(S(y_l+Δy，t)-S(y₁-Δy，t))/2Δ_y. (1)

in equation 1, 2 Δ y is the distance between the two unipolar sources. Thus, a source gradient can be generated by positioning two or more sources together and sweeping the two or more sources in opposite polarity (corresponding to the difference in equation 1). In this case, the output signals produced by the at least two seismic vibrators are 180 degrees out of phase, in which case the at least two seismic vibrators are considered to be in anti-phase. In other examples, the at least two seismic vibrators may not be exactly in phase opposition, but the property of the source having different polarities in different directions is still available. This may be the case, for example, when the sources are at the same depth, and any two of them are out of phase by an angle whose cosine is less than zero. The source gradient wavefield generated by a monopole source according to the foregoing configuration is not an idealized mathematical source gradient wavefield. To achieve the generation of a mathematical source gradient wavefield requires that the monopole sources be 180 degrees out of phase, that their distance 2 ay be close to zero, and that their amplitude be close to infinity. In practice, the output level of a monopole source cannot approach infinity, so in practice there is a trade-off between "close enough" to approximate an idealized mathematical gradient and "far enough apart" to produce a usable output level. Thus, the "source gradient wavefield" produced by the source array according to some embodiments is an approximate source gradient wavefield.

Further, according to some embodiments, the seismic vibrator array may also be controlled such that the seismic vibrator array is a monopole source that produces a monopole source wavefield. To generate a monopole source wavefield, the seismic vibrators of the seismic vibrator array are controlled such that they are in phase (with some of the seismic vibrators being slightly out of phase to account for different locations of the seismic vibrators, e.g., different depths of the seismic vibrators in a body of water, assuming the seismic vibrator array is part of a marine survey arrangement).

Utilizing a seismic vibrator array according to some embodiments provides greater flexibility because the seismic vibrator array can be selectively controlled to be a monopole source or a gradient source. During survey operations, the seismic vibrator array may be controlled to be a monopole source for some emissions (shots) and a gradient source for others, so that a target emission pattern may be generated. "launch" may refer to the activation of an array of seismic vibrators.

FIG. 1 is a schematic diagram of an exemplary marine survey arrangement including a marine vessel 102, the marine vessel 102 towing a seismic vibrator array 104 through a body of water 100, according to some embodiments. The seismic vibrator array 104 includes seismic vibrators 106, the seismic vibrators 106 being activatable in response to an activation signal generated by a controller 108 and provided by the controller 108 via a connection element 110 with the seismic vibrator array 104.

In the example of FIG. 1, marine vessel 102 also tows a streamer 112, streamer 112 including a seismic receiver 114. For other types of survey arrangements, the arrangement of seismic receivers may be disposed at the water bottom 101, may be deployed on an unmanned autonomous vehicle, may be suspended in the water, or may be deployed in any other structure.

The seismic receivers 114 are configured to detect wavefields reflected from subsurface structures 116 below the earth's surface (in FIG. 1, the water bottom 101, e.g., the sea floor). The subsurface structure 116 may include one or more subsurface target components 118. The source wavefield propagated by the seismic source 106 propagates into the subsurface structure 116. The subsurface structure 116 reflects a portion of the source wavefield, where the reflected wavefield is detected by the seismic receivers 114. The measurement data obtained by the seismic receivers 114 may be transmitted to the controller 108 for storage or for processing.

According to some embodiments, the seismic vibrators 106 in the seismic vibrator array 104 may be controlled to be in-phase or out-of-phase to cause the production of a monopole source wavefield or a source gradient wavefield, respectively. The controller 108 may send activation signals to the seismic vibrator array 104 to control the seismic vibrator array 104 to generate a unipolar source wavefield in a first shot (i.e., a first activation of the seismic vibrator array 104) and a source gradient wavefield in a second shot.

In some instances, activation of the seismic vibrator array 104 may be controlled such that a monopole source wavefield and a source gradient wavefield pattern are generated in successive shots. The pattern may be an alternating pattern in which the seismic vibrator array 104 alternately produces a monopole source wavefield and a source gradient wavefield in successive shots. In other examples, other activation patterns may be generated.

FIG. 2 is a schematic rear view of the exemplary survey arrangement of FIG. 1. As depicted in the example of fig. 2, the survey vibrator array 104 includes seismic vibrators at a plurality of different depths D1, D2, and D3. Although the seismic vibrators are shown at three different depths in the example of FIG. 2, it should be noted that in other examples, the seismic vibrators may be included at less than three depths or more than three depths. Seismic vibrators at different depths are configured to be activated with activation signals of different frequency ranges. For example, the seismic vibrator 106-3 at the depth D3 may be configured to be activated with an activation signal swept across a frequency of 0 to 15 hertz (Hz). Sweeping the activation signal from the first frequency to the second frequency refers to controlling the activation signal such that the frequency of the activation signal changes from the first frequency to the second frequency.

The seismic vibrator 106-2 at depth D2 may be configured to be activated with an activation signal swept across a frequency of 15 to 25 Hz. The seismic vibrator 106-1 at depth D1 may be configured to be activated with an activation signal swept over a frequency of 25 to 100 Hz. In other examples, the activation signal for the seismic vibrators at different depths may be swept over different frequency ranges. More generally, a shallower set of one or more seismic vibrators is swept in a higher frequency range and a deeper set of one or more seismic vibrators is swept in a lower frequency range.

The seismic vibrators are spaced apart by a spacing L. In some examples, the spacing L may be 1/3 of the shortest target wavelength, and in some embodiments, is 1/2 of no greater than the shortest target wavelength.The shortest target wavelength depends on the maximum frequency output of two or more seismic vibrators and therefore may be different for different seismic vibrators, for example deployed at different depth levels as described above. One way to define the shortest target wavelength may be to define the maximum target exit angleSuch that the shortest target wavelength is defined as:

here, λ_minIs the shortest target wavelength, f_maxIs the maximum output frequency (e.g., for the current depth level), and c is the speed of sound in the water. Thus, for vibrators deployed at different depth levels, the spacing may vary, provided that vibrators located at different levels emit frequency bands of different frequencies, as described. Thus, the seismic vibrator 106-1 may be separated by a distance L1 and the seismic vibrator 106-2 may be separated by a distance L2.

The spacings L1 and L2 are each large enough to allow the source gradient wavefield to produce usable output levels, while being small enough to maintain the desired mathematical gradient characteristics. As noted above, the spacing may generally be 1/3 of the minimum wavelength of the source gradient wavefield produced by the corresponding seismic vibrator. In other examples, the spacing may be 1/3 wavelengths greater than the minimum wavelength, so long as the spacing enables generation of a source gradient wavefield.

In the example of FIG. 2, the seismic vibrators 106-3 at depth D3 are driven in phase. That is, the cosine of the relative phase is greater than zero. As a result, the seismic vibrator 106-3 does not generate a source gradient wavefield. In contrast, the seismic vibrator 106-3 pair is configured to produce a monopole-only source wavefield.

Although two pairs (1 st and 2 nd) of seismic vibrators 106-2 are shown in FIG. 2 at depth D2, it should be noted that in other examples, only two seismic vibrators 106-2 may be provided at depth D2, wherein the two seismic vibrators are spaced apart by distance L2. Likewise, only one seismic vibrator 106-3 may be provided at depth D3.

To generate a monopole source wavefield using the seismic vibrator array 104 depicted in FIG. 2, the seismic vibrators 106-1, 106-2 and 106-3 are driven in phase. The seismic vibrators 106-1, 106-2, and 106-3 are considered to be in phase, although the activation signals of the seismic vibrators 106-1, 106-2, and 106-3 may be slightly out of phase, with the phase delay provided between the activation signals accounting for the depth difference of the seismic vibrators 106-1, 106-2, and 106-3. The net effect of the activation signals being slightly out of phase is that the seismic vibrators 106-1, 106-2 and 106-3 at different depths produce wavefields as if they were driven in phase.

On the other hand, to generate the source gradient wavefield, the left and right seismic vibrators 106-1 at depth D1 are driven out of phase (more specifically, in anti-phase), and the left seismic vibrator 106-2 pair at depth D2 is driven out of phase (more specifically, in anti-phase) as is the right seismic vibrator 106-2 pair.

FIG. 3 is a flow diagram of a survey process according to some embodiments. The survey process includes providing (at 302) a seismic vibrator array (e.g., 104 in fig. 1 and 2) having seismic vibrators. The survey process activates (at 304) the seismic vibrators in the seismic vibrator array, for example, under the control of the controller 108 of fig. 1 and 2, wherein the activation causes at least two of the seismic vibrators to be out of phase to generate a source gradient wavefield to survey a target structure, such as the subsurface structure 116 shown in fig. 1.

Out of phase seismic vibrators may be accomplished by sweeping the seismic vibrators in anti-phase (or near anti-phase, e.g., to maintain energy output or account for depth differences). With an anti-phase swept frequency seismic vibrator is meant that the first seismic vibrator is activated with an activation signal that is in anti-phase with respect to the activation signal used to activate the other seismic vibrator. The seismic vibrators swept in anti-phase are separated by an appropriate distance (e.g., as described further above) to generate source gradient signals. As mentioned above, the spacing is frequency dependent, an example of which is 1/3 the minimum wavelength of the source gradient wavefield.

FIG. 4 illustrates an exemplary emission pattern that may be produced using a seismic vibrator array 104 towed by a marine vessel 102, according to some examples. The tow path of the marine vessel 102 is shown at 402. As shown in FIG. 4, the stars (404) and arrows (406) represent the corresponding emissions of the seismic vibrator array 104. The star (404) represents the corresponding activation of the seismic vibrator array 104 that produces a monopole source wavefield. Arrows (406) represent activation of the seismic vibrator array 104 to generate the source gradient wavefield. In FIG. 4, the first two stars along path 402 are referred to as 404-1 and 404-2, respectively, and the first arrow along path 402 is referred to as 406-1. General reference to star 404 includes references 404-1 and 404-2 and general reference to arrow 406 includes reference 406-1.

In the example of FIG. 4, an alternating pattern of monopolar source activation and source gradient activation is depicted, where successive emissions alternate between monopolar source activation (activation of the seismic vibrator array 104 producing a monopolar source wavefield) and source gradient activation (activation of the seismic vibrator array 104 producing a source gradient wavefield).

FIG. 5 illustrates another exemplary emission pattern in which the seismic vibrator array 104 traverses a generally U-shaped path, as shown at 502. In fig. 5, the star (404) also represents unipolar source activation, while the arrow (406) represents source gradient activation.

FIG. 6 is an example of another exemplary emission pattern in which the seismic vibrator array 104 is towed in a coiled (hover) emission pattern along a path 602. The transmit pattern includes alternating unipolar source activations and source gradient activations, as shown by respective stars (404) and arrows (406).

According to other embodiments, the phase of each shot of the seismic vibrator array 104 may be controlled such that the residual emission noise (RSN) from one shot may be attenuated in the next shot. For a given transmission, residual transmit noise may result from one or more previous transmissions. If the firing pattern of the seismic vibrator array 104 is an alternating pattern that alternates between unipolar source activations and source gradient activations in successive firings, the residual firing noise from the unipolar firing activations may have a strong effect on subsequent source gradient activations.

By controlling the phase of successive shots to reduce residual shot noise, the shot spacing (distance or time) between successive shots can be reduced with unipolar source activation and source gradient activation to increase online sampling without compromising survey data quality. Online sampling refers to the acquisition of survey data in response to the corresponding emissions of the seismic vibrator array 104. Increasing online sampling refers to acquiring a greater amount of survey data due to the large number of shots provided.

Increasing online sampling may improve the results of acquiring survey data. For example, adding online sampling may improve the results of cross-line wavefield reconstruction with survey data acquired in response to a source gradient wavefield. Cross-line wavefield reconstruction is discussed further below.

An example of a Residual emission Noise removal or reduction technique IS described in U.S. provisional application No.61/886,409 entitled "Using Phase-Shifted machine detectors fans to Reduce the product of the Residual emission Noise from Previous Shots shoes", filed on 3.10.2013 (attorney docket number IS12.2212-US-PSP), which IS incorporated herein by reference for all purposes. In some embodiments, the residual emission noise removal or reduction technique in U.S. provisional application No.61/886,409 may be modified to separate residual unipolar source noise (noise due to previous unipolar source activations) from and residual source gradient noise (noise due to previous source gradient activations) from and from source gradient recordings (including survey data obtained in response to a unipolar source wavefield).

In some instances, residual noise removal or reduction may be accomplished by changing the unipolar source activation phase by 180 ° from unipolar source to unipolar source while keeping the gradient source phase unchanged. For example, in FIG. 4, the phase of a unipolar source (represented by star 404-1) may be set to +90 while the phase of the next successive unipolar source (represented by star 404-2) is set to-90. Thus, the phase of successive unipolar sources is changed. Thus, the monopole source (404-1) and the monopole source (404-2) are 180 ° out of phase with each other. The phase for the source gradient source (represented by arrow 406) need not be modified. Residual transmit noise reduction may be achieved with other combinations of phases.

In other embodiments, control of the seismic vibrators of the frequency dispersive (split) seismic vibrator array 104 may also be based, for example, such that the separation between the seismic vibrators is optimized to produce gradients for different bandwidths. In some cases, the seismic source array 104 is controlled to produce source gradients of only higher frequencies. In other words, the seismic vibrators of the seismic source array 104 configured to generate the higher frequency wavefield are controlled to generate a source gradient wavefield at least some of the shots. However, at lower frequencies, the corresponding seismic vibrators of the seismic vibrator array 104 are controlled to be swept in phase, thus producing a monopole-only source wavefield, rather than a source gradient wavefield.

For example, in the arrangement of FIG. 2, the seismic vibrators 106-1 and 106-2 (which produce higher frequency wavefields) may be controlled to alternate between in-phase and anti-phase, such that a unipolar source wavefield and a source gradient wavefield are alternately produced in each shot. However, the seismic vibrator 106-3 (which produces a lower frequency wavefield) is controlled to be in-phase (such that the seismic vibrator 106-3 does not produce a source gradient wavefield).

As described above, survey data acquired in response to a source gradient wavefield (referred to as "source gradient data") may be utilized for cross-line reconstruction of the source. Reconstruction of a source refers to evaluating the source based on the actual source.

FIG. 7 illustrates the emission patterns produced by the seismic vibrator array 104 traversing along paths 702, 704, and 706. In fig. 7, the darker arrows represent actual unipolar sources, while the lighter (dashed or dotted) arrows represent reconstructed unipolar sources. The direction of arrows 702, 704, or 706 is the in-line direction (or the direction of movement of seismic vibrator array 104). The cross-line direction is the direction indicated by the double-headed arrow 708, which is generally perpendicular to the in-line direction. Cross-line reconstruction refers to source reconstruction between actual sources in the cross-line direction 708. Cross-line reconstruction can be done by interpolating between the actual sources.

In fig. 7, the reconstruction sources provided by cross-line reconstruction include reconstruction sources 710 and 712. Reconstruction source 710 is between paths 702 and 704 and reconstruction source 712 is between paths 704 and 706.

When using source gradient data (survey data acquired in response to a source gradient wavefield) for cross-line reconstruction, the use of a dedicated low frequency seismic vibrator may avoid having to use a low frequency source gradient wavefield, as cross-line reconstruction may not need to be performed at low frequencies. This has the added benefit of increasing the low frequency output, as the source gradient wavefield may result in a reduced output energy. Varying the frequency output of different seismic vibrators may also enable the seismic vibrators to be swept repeatedly at different time intervals, allowing online sampling to be varied for different frequencies. In some cases, this may allow the acquisition of a unipolar source wavefield and a source gradient wavefield without confusion.

According to some embodiments, the cross-line reconstruction may include a faster than Nyquist (Nyquist) source side reconstruction. An example OF supernyquist source side Reconstruction is described in MassimianoVassallo et al, "Cross Wavefield Reconference for Multi-Components Streamer Data: Part 1-Multi-Channel interaction by Matching Pursuit (MIMAP) Using Pressure and Its Cross gradient," SOCIETY OF expression geographic location (2010), which is incorporated herein by reference. Although the method of Vassallo et al performs reconstruction of the receiver-side wavefield, it should be noted that methods employing measurements of pressure and its cross-line gradients can be adapted to the source side (e.g., for source wavefield reconstruction) because the source wavefield and the corresponding gradient wavefield have similar characteristics to the pressure wavefield and its gradients.

In addition to performing cross-line reconstruction, FIG. 7 also depicts an online reconstruction for reconstructing a monopole source between actual monopole sources in an online direction. For example, along path 702, the unipolar source represented by lighter arrow 714 is a reconstructed unipolar source provided by online reconstruction.

According to further embodiments, the source gradient data may also be used for other purposes. For example, the source gradient data may also be used for up-down source side wavefield separation for deghosting purposes (to remove or attenuate ghost data). An example of up-down source-side wavefield separation is described in U.S. patent No.7,876,642, which is incorporated herein by reference.

One problem associated with marine seismic surveying is the presence of ghost data. Ghost data refers to data in the measurement data resulting from reflections from the air-water interface (e.g., 103 in fig. 1) from the marine environment. The seismic wavefield generated by the seismic source generally propagates downward into the subsurface structure. The reflected seismic wavefield, which is responsive to the seismic wavefield propagated by the seismic source, generally propagates upward toward the deployed seismic receivers. In a marine environment, where the receivers are typically placed below the water surface, the seismic wavefield reflected from the subsurface structure continues to propagate upward past the receivers towards the air-water interface, where the seismic wavefield is reflected back downward.

This downwardly propagating seismic wavefield, which is reflected from the air-water interface, causes interference with the wavefield, which is directly propagating downwardly from the source, resulting in undesirable ghost notches in the source wavefield. The presence of ghost notches can result in reduced accuracy when generating a representation of a subsurface structure based on measurement data. Performing up-down source-side wavefield separation allows the up-going source wavefield to be determined such that its effects may be removed or attenuated for source-side deghosting.

In some implementations, the unipolar source data (survey data acquired in response to the unipolar source wavefield) may be combined with the source gradient data (survey data acquired in response to the source gradient wavefield) to remove the source-side ghosts from the survey data.

Source gradient data may also be used for multi-component imaging, which may also be referred to as vector acoustic imaging. Examples of vector acoustic Imaging are described in I.Vasconcelos et al, "Reverse-Time Imaging of Dual-Source for Marine semiconductor Data Using Primaries, Ghosts, and multiplets" 74^th EAGE CONFERENCE&Exihibition (month 6 2012), which is incorporated herein by reference. Multi-component imaging provides an alternative to wavefield reconstruction, such as provided by the cross-line reconstruction described above. Unipolar source data and source gradient data are acquired, which are fed into multi-component imaging (which combines unipolar source data and source gradient data) that produces an image with interleaved data.

As indicated above, in addition to towing a marine survey arrangement, a water bottom marine survey arrangement may be used instead. In a water bottom marine survey arrangement, survey receiver positions may be fixed. In a conventional bottom marine survey, a marine vessel towing a seismic source will repeat the source line at close intervals. However, if the source gradient is obtainable using a technique or mechanism according to some embodiments, the source line spacing (e.g., the spacing between the arrows 702, 704, 706 in fig. 7) may be increased such that the survey time may be shortened (because fewer shots need to be taken). In the common receiver domain, the alternating monopole gradient source array in combination with the multi-component faster-than-nyquist reconstruction technique may allow for recovery from the wider cross-line sampling depicted in fig. 7 to smaller cross-line sampling.

To further improve survey efficiency, one alternating monopole gradient source array (104) and another alternating monopole gradient source array (104) may be used simultaneously. For example, the source may utilize a joint source technique (simultaneoussource technique) based on temporal or phase dithering (dithering), phase sequencing (phase sequencing), or frequency-sparse techniques. Examples of temporal dithering are described in Moore et al, "Simultaneous Source Separation Using heated Sources," SEG Las channels 2008 annular Meeting, which is incorporated herein by reference. Examples of phase ordering are described in U.S. patent publication No. us 2014/0278119, which claims priority from provisional application No.61/788,265 entitled "Simultaneous semiconductor Sources," filed 3, 15, 2014, both of which are incorporated herein by reference. An example of Frequency-sparseness techniques IS described in U.S. publication No.2014/0278116, which claims priority from provisional application No.61/787,643 entitled "Frequency-Sparse Sources," filed 3, 15, 2013, both of which are incorporated herein by reference (attorney docket No. IS 12.2908).

Fig. 8 is a block diagram of a computer system 800, which may be part of the controller 108 shown in fig. 1. The computer system 800 includes a seismic vibrator control module 802 that is executable on one or more processors 804 to control seismic vibrators of the seismic vibrator array 104. The computer system 800 may also include a processing module 806 that is executable on the processor 804 to perform any of the tasks described above, such as, in some instances, cross-line reconstruction, on-line reconstruction, up-down source side wavefield reconstruction, and/or multi-separation imaging. Note that the processing module 806 may be provided in a computer system that is separate from the computer system that includes the seismic vibrator control module 802.

One or more processors 804 may be coupled to network interface 808 (to enable computer system 800 to communicate over a network) and storage medium (or storage media) 810 to store data and machine-executable instructions.

Storage medium (or storage media) 810 may be implemented as one or more non-transitory computer-readable or machine-readable storage media. The storage medium may include different forms of memory (including semiconductor memory) devices such as dynamic or static random access memory (DRAM or SRAM), erasable and programmable read-only memory (EPROM), electrically erasable and programmable read-only memory (EEPROM), and flash memory; magnetic disks such as fixed disks, floppy disks, and removable disks; other magnetic media, including magnetic tape; optical media, such as Compact Discs (CDs) or Digital Video Discs (DVDs); or other type of storage device. Note that the instructions discussed above may be provided on one computer-readable or machine-readable storage medium, or alternatively, may be provided on multiple computer-readable or machine-readable storage media distributed in a large system with possibly multiple nodes. Such computer-readable or machine-readable storage media are considered to be part of an article (or article of manufacture). An article or article may refer to any manufactured single component or multiple components. The storage medium or media may be located on the machine on which the machine-readable instructions are executed, or at a remote site from which the machine-readable instructions are downloaded over a network for execution.

In the preceding description, numerous details are set forth to provide an understanding of the subject matter disclosed herein. However, embodiments may be practiced without some of these details. Other embodiments may include modifications and variations to the details described above. It is intended that the appended claims cover such modifications and variations.