CN112987084B - Seismic data partial superposition recording method and system - Google Patents
Seismic data partial superposition recording method and system Download PDFInfo
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Abstract
The invention relates to a method and a system for partial superposition recording of seismic data, which are characterized by comprising the following steps: 1) Dividing the whole acquisition construction area to obtain at least one acquisition area; 2) Selecting one divided acquisition area, and determining the recording time of seismic data acquisition in the acquisition area; 3) Determining acquisition parameters of the acquisition region according to recording time during acquisition of the seismic data in the acquisition region, requirements of surface element division in seismic data processing and the length of a streamer for acquiring the seismic data; 4) Entering the step 2) to reselect a certain divided acquisition area until the acquisition parameters of all the acquisition areas are determined; 5) According to the acquisition parameters of each acquisition area, carrying out seismic acquisition operation in the field to obtain seismic data of different acquisition areas, and processing and analyzing the acquired seismic data indoors to complete partial superposition recording of the seismic data.
Description
Technical Field
The invention relates to a method and a system for recording partial superposition of seismic data, and belongs to the field of energy development and exploration.
Background
The marine seismic data acquisition generally comprises shipborne navigation, a seismic data excitation source and seismic data recording equipment, wherein a seismic exploration ship generally tows one or more sensor towing cables behind the ship, the seismic data excitation source is excited according to set time, the generated seismic data are transmitted to sea water and strata below the sea water, the seismic data meet stratum interfaces to generate upward transmitted reflection signals, the upward transmitted reflection signals are finally transmitted to the sea surface and are detected by various sensors on the towing cables and recorded by the recording equipment, and as shown in figure 1, the deeper stratum interfaces have longer time for reflecting back signals, and the required recording time t is longer 0 The longer. In the process of seismic data excitation and recording, the seismic exploration ship always drives forwards along a preset air route according to a certain speed v, when the current driving reaches a preset time, the seismic source is excited again, and the process is repeated. The time interval between two adjacent excitations of the seismic source is t, the t is a constant in the whole acquisition process, the distance between the two excitations is called as the shot spacing x, and the relation t = x/v is provided. After seismic data are collected, the structure, the composition and whether oil gas is contained in the stratum below the seawater are inferred through indoor processing and analysis of the recorded signals.
In the exploration of reserves of global ocean oil and gas, shallow sea still dominates at present. With the continuous improvement of the demand of petroleum energy and the progress of petroleum exploration, the petroleum exploration gradually advances to deep sea, and the exploration target layer is gradually developed from a shallow layer to a deep layer. Deep water exploration is often low, and deep seismic data need to be acquired so as to carry out researches on regional structure, deposition and the like. In addition, in order to search for a mid-deep oil and gas target, seismic imaging needs to be performed on deep strata below the target, and basic data is provided for construction interpretation, hydrocarbon source analysis, oil and gas migration and the like of interpreters. In the past, 8s of seismic data are usually recorded in marine seismic acquisition, the requirements cannot be met in oil and gas exploration in a deep water area and oil and gas exploration facing a middle deep layer, and 10s or even 12s of seismic data need to be acquired so as to obtain deep information. Therefore, in deep water exploration and middle and deep depth exploration, the recording time of seismic data needs to be increased to be full ofMeets the production requirement. At present, in marine seismic data acquisition, in order to meet the requirement of data processing, seismic data generated by two adjacent cannons cannot be mutually overlapped, namely, the next cannon can be excited after the seismic data excited by the current cannon is recorded. In order to make the records of two adjacent shots not coincide as shown in FIG. 1, the time difference t between the Nth shot and the (N + 1) th shot is required to be greater than or equal to the recording time t 0 . The recording time of the past seismic data is short, and is usually less than or equal to 8s, namely the time difference t of the excitation of adjacent cannons is more than or equal to 8s. In marine collection construction, in order to drag a cable flat, the sailing speed v of a collection ship needs more than 4 sections, and in order to ensure certain collection efficiency, the sailing speed of 4.5 sections is usually adopted in production. The distance between two adjacent guns, namely the gun spacing x = v × t, and the gun spacing needs to satisfy x ≧ 4.5 (knots) × 1.852 × 1000/3600 × 8(s) =18.52m. Therefore, if the recording length of seismic data required in production is 8S, the gun spacing needs to be more than 18.52m when the sailing speed is 4.5 knots. The shot spacing can be 18.75m, 25m, 50m and the like according to the requirements of element division in processing. At present, in order to meet the requirements of complex geological structures and complex reservoir imaging in production, the covering times are often required to be increased. The number of longitudinal coverage of streamer acquisition = cable length/(2 × shot spacing), i.e. the smaller the shot spacing, the higher the number of coverage, and therefore the minimum shot spacing is 18.75m. When the cable length is 7200m, the longitudinal covering times can reach 192 times. When the exploration is carried out in a deep water area and a middle-deep layer, the recording length of seismic data is required to reach 10s or even 12s. When the 10s navigation speed of the seismic record is 4.5 knots, the distance between the guns needs to satisfy x is more than or equal to 4.5 knots multiplied by 1.852 multiplied by 1000/3600 multiplied by 10 knots (= 23.15 m). According to the requirement of surface element division in the processing, the shot spacing can only adopt 25m, 50m, 100m and the like, and the minimum shot spacing is 25m. When the cable length is 7200m, the number of longitudinal coverage times is 144. The number of coverage was reduced by 48 times compared to 8s for seismic records. How to meet the requirements of deep and medium-deep exploration without reducing the covering times and ensuring the quality of the acquired seismic data is an urgent problem to be solved. Decreasing the sailing speed increases the time interval t between two guns. When recording time t 0 When the distance between the guns is 18.75m for 10s, the sailing speed needs to be reduced to be below 3.65 knotsCan meet the requirement, which can lead to uneven field cable and is difficult to realize in field production. Meanwhile, the navigation speed is reduced, the acquisition efficiency is greatly reduced, and the acquisition cost is increased. Therefore, the existing acquisition and data recording modes are urgently needed to be improved in marine seismic acquisition, the requirements of medium-deep exploration are met, and the quality of seismic data acquisition is ensured.
With the development of the seismic data processing method, linear interference signals in the seismic data are very easy to remove, so that the partially overlapped acquisition of the two-shot seismic data in field acquisition becomes possible. At present, however, fully folded two shot seismic data are still very difficult to separate. In deep water seismic exploration, effective seismic data only appear from the part below the sea bottom, single-shot seismic data received in the field are shown in figure 2, signals above the sea bottom only have direct waves except noise, the direct waves are not required in the processing of the seismic data, and the direct waves are cut off in the processing, so that the overlapping recording of two adjacent shot parts is possible.
Disclosure of Invention
In view of the above problems, an object of the present invention is to provide a method and a system for partially overlapping and recording seismic data, which can increase the recording time of the seismic data without reducing the coverage times and the acquisition efficiency (navigation speed) so as to record the seismic data in a middle and deep layer, thereby ensuring the acquisition quality of the seismic data.
In order to achieve the purpose, the invention adopts the following technical scheme: a seismic data partial superposition recording method, comprising the following:
1) Acquiring the water depth range of seawater in the whole collection construction area, and dividing the whole collection construction area according to the acquired water depth range to obtain at least one collection area;
2) Selecting one divided acquisition area, and determining the recording time of seismic data acquisition in the acquisition area;
3) Determining acquisition parameters of the acquisition region according to recording time during acquisition of the seismic data in the acquisition region, requirements of surface element division in seismic data processing and the length of a streamer for acquiring the seismic data;
4) Entering the step 2) to reselect a certain divided acquisition area until the acquisition parameters of all the acquisition areas are determined;
5) According to the acquisition parameters of each acquisition area, carrying out seismic acquisition operation in the field to obtain seismic data of different acquisition areas, and processing and analyzing the acquired seismic data indoors to complete partial superposition recording of the seismic data.
Further, the specific process of step 2) is as follows:
2.1 Selecting a certain divided acquisition area, extracting the minimum water depth h in the acquisition area, and calculating the propagation time delta t of the seismic data when the water depth is 2h as follows:
Δt＝2×h/v water (I)
Wherein v is Water (I) The water speed is adopted;
2.2 Adopting a single-point model method, and calculating the required recording time according to the requirement that diffracted waves generated by the deepest stratum interface in the acquisition region can shift to return;
2.3 The recording time of seismic data acquisition in the acquisition area is calculated according to the propagation time of the seismic data when the water depth is 2h and the required recording time.
Further, the specific process of step 2.2) is as follows:
2.2.1 Calculate the two-pass reflection time t of the deepest destination layer of the acquisition region based on the one-dimensional velocity model of a single point v ；
2.2.2 Will calculate the two-way reflection time t v Adding the residual motion correction time t of the multiple nmo Obtaining the recording time t 1 ：
t 1 ＝t v +t nmo
2.2.3 ) the steepest dip α in the range of the target layer on the existing seismic section is taken into account according to the recording time t 1 Determining the recording time as t 2 ：
2.2.4 To converge as much scattered energy as possible, the partial recording time dt is increased to obtain the desired recording time t 0 ' is:
further, the recording time t of the seismic data acquisition in the acquisition area in the step 2.3) 0 Comprises the following steps:
t 0 ＝t 0 ′-Δt+t c
wherein, t c Is constant or 0; t is t 0 ' is the desired recording time; and delta t is the propagation time of the seismic data when the water depth is 2 h.
Further, the acquisition parameters of the acquisition region in the step 3) comprise the time interval between two adjacent excitations, the minimum shot spacing between two adjacent excitations and the longitudinal coverage times.
Further, the specific process of step 3) is as follows:
3.1 Based on the recording time t of seismic data acquisition within the acquisition area 0 Determining the range of a time interval t and a shot spacing x between two adjacent excitations of a seismic source excited by seismic data, and determining the minimum shot spacing x according to the binning requirement in the seismic data processing min ；
3.2 Streamer length L and minimum shot spacing x based on seismic data acquisition min Determining the number of longitudinal (along the cable direction) coverage times N of the acquisition area:
N＝L/(2×x min )。
further, the specific process of step 3.1) is as follows:
3.1.1 Based on the recording time t of seismic data acquisition within the acquisition area 0 Determining the time interval t between two adjacent excitations of the seismic source of seismic data excitation:
t≥t 0
3.1.2 Based on the recording time t of seismic data acquisition within the acquisition area 0 And seismic data excitation sourceAnd determining the range of shot spacing x between two adjacent excitations of the seismic source excited by the seismic data by the time interval t between the two adjacent excitations:
x＝v ship with a detachable cover ×t≥v Ship with a detachable hull ×t 0
Wherein v is Ship with a detachable hull The ship speed;
3.1.3 ) determining the minimum shot spacing x based on the binning requirement and the determined range of shot spacings x in seismic data processing min 。
A seismic data partial coincidence recording system comprising:
the collection area dividing module is used for acquiring the water depth range of seawater in the whole collection construction area, and dividing the whole collection construction area according to the acquired water depth range to obtain at least one collection area;
the recording time calculation module is used for selecting one divided acquisition area and determining the recording time when the seismic data in the acquisition area are acquired;
the acquisition parameter determining module is used for determining acquisition parameters of the acquisition region according to recording time during acquisition of the seismic data in the acquisition region, the requirement of surface element division in seismic data processing and the length of a towing cable for acquiring the seismic data;
the seismic data acquisition, processing and analysis module is used for carrying out seismic acquisition operation in the field according to the acquisition parameters of each acquisition area to obtain seismic data of different acquisition areas, and processing and analyzing the acquired seismic data indoors.
A processor comprising computer program instructions, wherein said computer program instructions when executed by the processor are adapted to perform the steps corresponding to the above-described seismic data partial superposition recording method.
A computer readable storage medium having computer program instructions stored thereon, wherein the computer program instructions, when executed by a processor, are configured to implement the steps corresponding to the seismic data partial superposition recording method.
Due to the adoption of the technical scheme, the invention has the following advantages:
1. in the existing offshore deep water area and medium-deep layer seismic acquisition operation, in order to acquire deep layer seismic data, the recording time of the seismic data needs to be increased, the gun spacing is increased, the longitudinal coverage frequency is less, and the imaging requirements of underground complex structures and complex reservoirs cannot be met under the conventional acquisition and seismic data recording mode.
2. The method can record deep seismic data, meet production requirements, greatly improve longitudinal coverage times, improve imaging quality of the seismic data, and meet imaging requirements of complex structures and complex reservoirs, is also suitable for shallow water areas, and can be widely applied to the field of energy development and exploration, and the propagation time delta t of the seismic data when the water depth is 2 hours is reduced when the water depth is reduced.
Drawings
FIG. 1 is a schematic diagram of excitation and reception modes of two adjacent shots of a prior art marine seismic acquisition;
FIG. 2 is a schematic illustration of prior art single shot seismic data collected during conventional seismic exploration in offshore deepwater zones;
FIG. 3 is a schematic representation of raw single shot seismic data acquired in a deep water offshore area using the method of the present invention;
FIG. 4 is a schematic diagram of single-shot seismic data after adjacent shot through-wave cancellation using linear interference cancellation.
Detailed Description
The present invention will be described in detail below with reference to the accompanying drawings. It is to be understood, however, that the drawings are provided solely for the purposes of promoting an understanding of the invention and that they are not to be construed as limiting the invention.
The method and the system for recording the partial superposition of the seismic data are used for seismic acquisition in a shallow water-deep water transition zone or a deep water area on the sea, can increase the recording time of the seismic data on the premise of not reducing the longitudinal coverage times and the acquisition efficiency without changing the conventional towing mode of a seismic acquisition operation ship, and do not increase the field acquisition cost while ensuring the acquisition quality of the seismic data.
Example 1
The embodiment provides a seismic data partial superposition recording method, which comprises the following steps:
1) According to the seawater investigation data or the historical seismic data, acquiring the water depth range h of seawater in the whole collection construction area 1 ～h 2 ，h 1 ≤h 2 And dividing the whole collection construction area according to the acquired water depth range to obtain at least one collection area, which specifically can be as follows:
(1) when (h) 2 -h 1 )/2<h 1 When the water depth change in the whole collection area is considered to be small, the whole collection construction area is used as a collection area for collection;
(2) when (h) 2 -h 1 )/2≧h 1 In the process, the water depth in the whole collection construction area is considered to be greatly changed, and the whole collection construction area is divided into two collection areas for collection respectively by taking the average water depth as a boundary, or the collection construction area is divided according to actual requirements.
According to the specific water depth change condition in the field, other division standards can be adopted to divide the collection area.
2) Selecting a certain divided acquisition area, extracting the minimum water depth h in the acquisition area, and calculating the propagation time delta t of the seismic data when the water depth is 2 h:
Δt＝2×h/v water (W) (1)
Wherein v is Water (W) For water velocity, usually v Water (W) ＝1500m/s。
3) Calculating the required recording time t by adopting a single-point model method commonly used in the current seismic acquisition according to the requirement that diffracted waves generated by the deepest stratum interface in the acquisition region can shift and return 0 ', specifically:
3.1 According to the one-dimensional velocity model of a single point, calculating the two-pass reflection time t of the target layer with the deepest acquisition region v 。
3.2 Will calculate the two-way reflection time t v Plus the residual motion correction time t of multiples nmo Obtaining the recording time t 1 ：
t 1 ＝t v +t nmo (2)
3.3 ) the steepest dip α in the range of the target layer on the existing seismic section is considered, according to the recording time t 1 To converge the scattering energy of these steep formations, the recording time is determined to be t 2 ：
3.4 To converge as much scattered energy as possible, a fraction of the recording time dt, typically 1s, is increased, so that the required recording time t is increased 0 ' is:
4) According to the propagation time delta t of the seismic data when the water depth is 2h and the required recording time t 0 ' calculating the recording time t of seismic data acquisition in the acquisition region 0 ：
t 0 ＝t 0 ′-Δt+t c (5)
Wherein, t c Is a small constant or 0 and can be taken as 50ms, 100ms or determined according to actual conditions.
5) According to the recording time t of seismic data acquisition in the acquisition area 0 Determining the range of the time interval t and the shot spacing x between two adjacent excitations of the seismic source excited by the seismic data, and determining the minimum shot spacing x according to the binning requirement in the seismic data processing min The method specifically comprises the following steps:
5.1 Based on the time recorded during seismic data acquisition within the acquisition areat 0 Determining the time interval t between two adjacent excitations of the seismic source excited by the seismic data:
t≥t 0 (6)
5.2 Based on the recording time t of seismic data acquisition within the acquisition area 0 And determining the range of shot spacing x between two adjacent excitations of the seismic source excited by the seismic data according to the time interval t between two adjacent excitations of the seismic source excited by the seismic data:
x＝v ship with a detachable cover ×t≥v Ship with a detachable cover ×t 0 (7)
Wherein v is Ship with a detachable cover Which is the boat speed, typically 4.5 knots.
5.3 ) determining the minimum shot spacing x based on the binning requirements and the determined range of shot spacings x in seismic data processing min 。
6) Streamer length L and minimum shot spacing x from seismic data acquisition min Determining the number of longitudinal (along the cable direction) coverage times N of the acquisition area:
N＝L/(2×x min ) (8)
7) Entering the step 2) to reselect a certain divided acquisition region until the acquisition parameters of all the acquisition regions are determined, wherein the acquisition parameters comprise the time interval t between two adjacent excitations and the minimum shot spacing x between two adjacent excitations min And the number of vertical coverage times N.
8) And according to the determined acquisition parameters of each acquisition area, carrying out seismic acquisition operation in the field to obtain seismic data of different acquisition areas, and processing and analyzing the acquired seismic data indoors to complete partial superposition recording of the seismic data.
In field acquisition, the detector starts to record received seismic data immediately after each shot of a seismic data excitation source is excited, and in the invention, the time delta t-t passes after each shot is excited c The back detector starts to record the seismic data, and the recording time length is t 0 The time length of the effective seismic data recorded in the mode is t 0 + Δ t, the effective length of time increased over the current conventional approach is Δ t. Thus, the direct wave signal excited by the n +1 th shot of the seismic source excited by the seismic data is transmittedAnd recording the direct wave signal into the nth shot, wherein the direct wave signal is a linear interference signal and needs to be removed in the processing. Current processing methods easily remove this signal. As shown in FIG. 3, the position indicated by 8-10S in the single-shot seismic data acquired in the offshore deep water area by the invention is the direct wave excited by the next shot. As shown in fig. 4, for the single-shot seismic data after the next shot-direct wave is eliminated indoors by the linear interference elimination method, the direct wave is eliminated from the figure, and the effective wave is not damaged.
The method for recording the partial superposition of seismic data is explained in detail by taking the construction area acquired in the deep water area of south China sea as a specific embodiment:
1) According to the seawater investigation data, the water depth range of the acquisition construction area in the deep water area of south China sea is 500-2500 m, namely h 1 ＝500m，h 2 =2500m, in this case (h) 2 -h 1 )/2＞h 1 And the water depth in the acquisition construction area is greatly changed, according to the method, the acquisition construction area is divided into two acquisition areas for acquisition, the water depth of an acquisition area 1 is 500-1500 m, the water depth of an acquisition area 2 is 1500-2500 m, and acquisition parameters of the two acquisition areas are respectively calculated below.
2) Extracting the minimum water depth h =500m in the acquisition area 1, and calculating the propagation time delta t =2 xh/v when the water depth of the seismic data is 2h Water (W) =0.67s, wherein v Water (W) ＝1500m/s。
3) Calculating the required recording time t by adopting a single-point model method according to the requirement that diffracted waves generated by the deepest stratum interface in the acquisition region can shift to return 0 ′＝10s。
4) According to the propagation time delta t of the seismic data when the water depth is 2h and the required recording time t 0 ' calculating the recording time t of seismic data acquisition in the acquisition area 0 =10-0.67+0.05=9.38s, wherein t is selected c ＝50ms。
5) According to the recording time t of the seismic data acquisition in the acquisition region 1 0 Determining the time interval t between two adjacent excitations of the seismic source excited by the seismic data to be more than or equal to 9.38S and the distance between two adjacent excitations of the seismic source
According to the requirement of face element division in seismic data processing, the shot spacing x can be 18.75m, 25m, 50m and the like, and in order to improve the covering times, the minimum value x of the shot spacing is selected min Is 25m. Since the recording time is 9.38s and 10s, the corresponding minimum value x of the shot distance min May be 25m, in which case the recording time t is usually chosen 0 ＝10s。
6) When streamer length L =7200m for acquiring seismic data, based on streamer length L and determined minimum shot spacing x min Determining the number of longitudinal (along the cable) coverages of the acquisition area 1
Through the steps, the acquisition parameters of the acquisition area 1 in the deep water area of south China sea can be obtained, and the acquisition parameters comprise recording length time of 10s, shot spacing of 25m, covering times of 144 times and the like.
7) Extracting the minimum water depth h =1500m in the acquisition area 2, and calculating the propagation time delta t =2 xh/b when the water depth of the seismic data is 2h Water (W) =2s, wherein b Water (I) ＝1500m/s。
8) Calculating the required recording time t by adopting a single-point model method according to the requirement that diffracted waves generated by the deepest stratum interface in the acquisition region can shift to return 0 ′＝10s。
9) According to the propagation time delta t of the seismic data when the water depth is 2h and the required recording time t 0 ' calculating the recording time t of seismic data acquisition in the acquisition area 0 =10-2+0.05 + 8.05s, wherein t is selected c =50ms. The recording time of 2s in seawater is increased during treatment, and the obtained seismic recording time is still 10s.
10 Based on the recording time t at the time of seismic data acquisition within the acquisition region 2 0 DeterminingThe actual time interval t between two adjacent excitations of the seismic source excited by the seismic data is more than or equal to 8.05S and the distance between two adjacent excitations of the seismic source
According to the requirement of face element division in seismic data processing, the shot spacing x can be 18.75m, 25m, 50m and the like, and in order to improve the covering times, the minimum value x of the shot spacing is selected min And was 18.75m.
11 When streamer length L =7200m for acquiring seismic data, based on streamer length L and determined minimum shot spacing x min Determining the number of longitudinal (along the cable) coverages of the acquisition area 2
Through the steps, the acquisition parameters of the acquisition area 2 in the deep water area of south China sea can be obtained, wherein the acquisition parameters comprise actual recording time of 8.05s (the acquired seismic recording time is 10 s), shot spacing of 18.75m, covering times of 192 and the like.
12 Respectively, performing seismic acquisition operations in the field to obtain seismic data of the two acquisition regions according to the acquisition parameters of the acquisition region 1 and the acquisition region 2, and processing and analyzing the acquired seismic data indoors.
If the method in the seismic acquisition production in the prior art is adopted, the acquisition parameters in the acquisition area of the deep water area in south China sea are as follows: the recording time is 10s, the shot distance x needs to satisfy the condition that x is larger than or equal to 23.15m, the shot distance x =25m is selected, and the longitudinal covering times are 144. By adopting the method, the longitudinal coverage frequency of seismic data acquisition can reach 192 times and is improved by 48 times. Therefore, by adopting the method, in an acquisition area 1 with the water depth of 500-1500 m, the acquisition parameters are recording the length time of 10s, the shot spacing of 25m and the covering times of 144 times; in an acquisition area 2 with the water depth of 1500-2500 m, the acquisition parameters are 8.05s of actual recording time (10 s of acquired seismic recording time), 18.75m of shot spacing, 192 times of coverage and the like, and the longitudinal times of coverage of seismic data are improved by 48 times. Therefore, by adopting the method, the deep seismic data can be recorded, the production requirement is met, the longitudinal coverage times can be greatly improved, the imaging quality of the seismic data is improved, and the imaging requirements of complex structures and complex reservoirs can be met. Meanwhile, the method does not change the field acquisition mode, does not reduce the acquisition efficiency and hardly increases the acquisition cost.
Example 2
The present embodiment provides a seismic data partial superposition recording system, including:
the collection area dividing module is used for acquiring the water depth range of seawater in the whole collection construction area, and dividing the whole collection construction area according to the acquired water depth range to obtain at least one collection area;
the recording time calculation module is used for selecting one divided acquisition area and determining the recording time of seismic data acquisition in the acquisition area;
the acquisition parameter determining module is used for determining acquisition parameters of the acquisition region according to recording time during acquisition of the seismic data in the acquisition region, the requirement of face element division in seismic data processing and the length of a towing cable for acquiring the seismic data;
the seismic data acquisition, processing and analysis module is used for carrying out seismic acquisition operation in the field according to the acquisition parameters of each acquisition area to obtain seismic data of different acquisition areas and processing and analyzing the acquired seismic data indoors.
In a preferred embodiment, the recording time calculation module includes:
the propagation time calculation unit is used for selecting a certain divided acquisition area, extracting the minimum water depth h in the acquisition area, and calculating the propagation time of the seismic data when the water depth is 2 h;
the single-point model unit is used for calculating the required recording time by adopting a single-point model method according to the requirement that diffracted waves generated by the deepest stratum interface in the acquisition region can shift to return;
and the recording time calculation unit is used for calculating the recording time of seismic data acquisition in the acquisition area according to the propagation time when the depth of water of the seismic data is 2h and the required recording time.
Example 3
The present embodiment provides a processing device corresponding to the seismic data partial superposition recording method provided in embodiment 1, where the processing device may be a processing device for a client, such as a mobile phone, a laptop, a tablet computer, a desktop computer, etc., to execute the method of embodiment 1.
The processing equipment comprises a processor, a memory, a communication interface and a bus, wherein the processor, the memory and the communication interface are connected through the bus so as to complete mutual communication. The memory stores a computer program that can be executed on the processor, and the processor executes the seismic data partial superposition recording method provided in embodiment 1 when executing the computer program.
In some implementations, the Memory may be a high-speed Random Access Memory (RAM), and may also include a non-volatile Memory, such as at least one disk Memory.
In other implementations, the processor may be various general-purpose processors such as a Central Processing Unit (CPU), a Digital Signal Processor (DSP), and the like, and is not limited herein.
Example 4
The seismic data partial fold record method of this embodiment 1 may be embodied as a computer program product that may include a computer readable storage medium having computer readable program instructions embodied thereon for performing the voice recognition method described in this embodiment 1.
The computer readable storage medium may be a tangible device that retains and stores instructions for use by an instruction execution device. The computer readable storage medium may be, for example, but not limited to, an electronic storage device, a magnetic storage device, an optical storage device, an electromagnetic storage device, a semiconductor storage device, or any combination of the foregoing.
The above embodiments are only used for illustrating the present invention, and the structure, connection manner, manufacturing process and the like of each component can be changed, and equivalent changes and improvements made on the basis of the technical scheme of the present invention should not be excluded from the protection scope of the present invention.
Claims (7)
1. A seismic data partial superposition recording method is characterized by comprising the following steps:
1) Acquiring the water depth range of seawater in the whole acquisition construction area, and dividing the whole acquisition construction area according to the acquired water depth range to obtain at least one acquisition area;
2) Selecting a certain divided acquisition area, and determining the recording time of seismic data acquisition in the acquisition area, wherein the specific process comprises the following steps:
2.1 Selecting a certain divided acquisition area, extracting the minimum water depth h in the acquisition area, and calculating the propagation time delta t of the seismic data when the water depth is 2h as follows:
Δt＝2×h/v water (W)
Wherein v is Water (I) The water speed is adopted;
2.2 Adopting a single-point model method, calculating the required recording time according to the requirement that the diffracted wave generated by the deepest stratum interface in the acquisition region can shift to return, and the specific process is as follows:
2.2.1 According to the one-dimensional velocity model of a single point, calculating the two-pass reflection time t of the target layer with the deepest acquisition region v ；
2.2.2 Will calculate the two-way reflection time t v Plus the residual motion correction time t of multiples nmo Obtaining the recording time t 1 ：
t 1 ＝t v +t nmo
2.2.3 Considering the steepest dip α in the range of the target zone on the existing seismic section, according to the recording time t 1 Determining the recording time as t 2 ：
2.2.4 To converge as much scattered energy as possible, the partial recording time dt is increased to obtain the desired recording time t 0 ' is:
2.3 Calculating the recording time t of seismic data acquisition in the acquisition area according to the propagation time of the seismic data when the water depth is 2h and the required recording time 0 Comprises the following steps:
t 0 ＝t 0 ′-Δt+t c
wherein, t c Is constant or 0; t is t 0 ' is the desired recording time; delta t is the propagation time of the seismic data when the water depth is 2 h;
3) Determining acquisition parameters of the acquisition region according to recording time during acquisition of the seismic data in the acquisition region, requirements of surface element division in seismic data processing and the length of a streamer for acquiring the seismic data;
4) Entering the step 2) to reselect a certain divided acquisition area until the acquisition parameters of all the acquisition areas are determined;
5) According to the acquisition parameters of each acquisition area, carrying out seismic acquisition operation in the field to obtain seismic data of different acquisition areas, and processing and analyzing the acquired seismic data indoors to complete partial superposition recording of the seismic data.
2. A method for partial superposition recording of seismic data according to claim 1, wherein the acquisition parameters for the acquisition region in step 3) include the time interval between two adjacent shots, the minimum shot spacing between two adjacent shots and the number of longitudinal coverage.
3. A method for partially overlapping and recording seismic data according to claim 2, wherein the specific process of step 3) is:
3.1 Based on the time of acquisition of seismic data within the acquisition areaRecording time t 0 Determining the range of a time interval t and a shot spacing x between two adjacent excitations of a seismic source excited by seismic data, and determining the minimum shot spacing x according to the binning requirement in the seismic data processing min ；
3.2 Streamer length L and minimum shot spacing x based on seismic data acquisition min Determining the longitudinal coverage times N of the acquisition area:
N＝L/(2×x min )。
4. a seismic data partial superposition recording method according to claim 3, wherein the specific process of step 3.1) is:
3.1.1 Based on the recording time t of seismic data acquisition within the acquisition area 0 Determining the time interval t between two adjacent excitations of the seismic source of seismic data excitation:
t≥t 0
3.1.2 Based on the recording time t of seismic data acquisition within the acquisition area 0 And determining the range of shot spacing x between two adjacent excitations of the seismic source excited by the seismic data according to the time interval t between two adjacent excitations of the seismic source excited by the seismic data:
x＝v ship with a detachable hull ×t≥v Ship with a detachable hull ×t 0
Wherein v is Ship with a detachable hull The ship speed;
3.1.3 ) determining the minimum shot spacing x based on the binning requirements and the determined range of shot spacings x in seismic data processing min 。
5. A seismic data partial coincidence recording system, comprising:
the collection area dividing module is used for acquiring the water depth range of seawater in the whole collection construction area, and dividing the whole collection construction area according to the acquired water depth range to obtain at least one collection area;
the recording time calculation module is used for selecting a divided acquisition area and determining the recording time of seismic data acquisition in the acquisition area, and the specific process is as follows:
selecting a certain divided acquisition area, extracting the minimum water depth h in the acquisition area, and calculating the propagation time delta t of the seismic data when the water depth is 2h as follows:
Δt＝2×h/v water (W)
Wherein v is Water (W) The water speed is adopted;
calculating the required recording time by adopting a single-point model method according to the requirement that diffracted waves generated by the deepest stratum interface in the acquisition region can shift to return, wherein the specific process is as follows:
according to the one-dimensional velocity model of the single point, calculating the two-pass reflection time t of the deepest target layer of the acquisition region v ；
Will calculate the two-way reflection time t v Plus the residual motion correction time t of multiples nmo Obtaining the recording time t 1 ：
t 1 ＝t v +t nmo
Considering the steepest stratigraphic dip angle alpha in the range of the target layer on the existing seismic section according to the recording time t 1 Determining the recording time as t 2 ：
To converge as much scattered energy as possible, the partial recording time dt is increased to obtain the desired recording time t 0 ' is:
calculating the recording time t of seismic data acquisition in the acquisition area according to the propagation time of the seismic data when the water depth is 2h and the required recording time 0 Comprises the following steps:
t 0 ＝t 0 ′-Δt+t c
wherein, t c Is constant or 0; t is t 0 ' is the desired recording time; deltat is the propagation time of the seismic data when the water depth is 2 h;
the acquisition parameter determining module is used for determining acquisition parameters of the acquisition region according to recording time during acquisition of the seismic data in the acquisition region, the requirement of surface element division in seismic data processing and the length of a towing cable for acquiring the seismic data;
the seismic data acquisition, processing and analysis module is used for carrying out seismic acquisition operation in the field according to the acquisition parameters of each acquisition area to obtain seismic data of different acquisition areas and processing and analyzing the acquired seismic data indoors.
6. A processor comprising computer program instructions, wherein the computer program instructions, when executed by the processor, are adapted to perform the steps corresponding to the method for partial superposition recording of seismic data according to any of claims 1-4.
7. A computer readable storage medium having computer program instructions stored thereon, wherein the computer program instructions, when executed by a processor, are for performing the steps corresponding to the seismic data partial superposition recording method of any of claims 1-4.
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