CN112987084A - Seismic data partial superposition recording method and system - Google Patents
Seismic data partial superposition recording method and system Download PDFInfo
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- CN112987084A CN112987084A CN202110214773.XA CN202110214773A CN112987084A CN 112987084 A CN112987084 A CN 112987084A CN 202110214773 A CN202110214773 A CN 202110214773A CN 112987084 A CN112987084 A CN 112987084A
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- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/24—Recording seismic data
- G01V1/247—Digital recording of seismic data, e.g. in acquisition units or nodes
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/24—Recording seismic data
- G01V1/26—Reference-signal-transmitting devices, e.g. indicating moment of firing of shot
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- G—PHYSICS
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- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/38—Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
- G01V1/3808—Seismic data acquisition, e.g. survey design
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 ship-borne navigation, a seismic data excitation source and seismic data recording equipment, wherein a seismic exploration ship generally drags 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 a stratum interface to generate an upward transmitted reflection signal, the upward transmitted reflection signal is finally transmitted to the sea surface, the upward transmitted reflection signal is detected by each sensor on the towing cables and recorded by the recording equipment, and as shown in fig. 1, the longer the time taken for the signal reflected by the deeper stratum interface is, the required recording time t is0The 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 time 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 t is the relation x/v. After seismic data acquisition, the stratum below the seawater is deduced through indoor processing and analysis of recorded signalsThe structure, composition and whether oil gas is contained.
In the exploration of reserves of global marine 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. The exploration degree of the deep water area is often low, and deep seismic data need to be acquired so as to carry out research 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 prolonged to meet the production demand. 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 t0. 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 8 s. 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, i.e. the gun spacing x is equal to v × t, and the gun spacing needs to satisfy x ≧ 4.5 (knots) × 1.852 × 1000/3600 × 8(s) ═ 18.52 m. Therefore, if the recording length of seismic data required in production is 8S, the gun spacing needs to be greater than 18.52m when the voyage speed is 4.5 knots. The distance between the cannons 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. Longitudinal of streamer acquisitionThe number of times of coverage is equal to the cable length/(2 × the shot pitch), i.e., the smaller the shot pitch, the higher the number of times of coverage, and therefore, 18.75m is used as the minimum shot pitch. When the cable length is 7200m, the number of 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 12 s. When the 10s navigation speed recorded by the earthquake is 4.5 knots, the distance between the cannons needs to satisfy the condition that x is more than or equal to 4.5 knots multiplied by 1.852 multiplied by 1000/3600 multiplied by 10 knots multiplied by 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 25 m. 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 t0When the distance between the guns is 18.75m for 10s, the sailing speed needs to be reduced to be below 3.65 knots to meet the requirement, so that the field cable is uneven, and the field production is difficult to realize. 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/vwater (W)
Wherein v isWater (W)The water speed is adopted;
2.2) 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 2.3) calculating the recording time 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.
Further, the specific process of step 2.2) is as follows:
2.2.1) calculating the two-pass reflection time t of the deepest target layer of the acquisition area according to the one-dimensional velocity model of the single pointv；
2.2.2) will calculate the two-way reflection time tvPlus the residual motion correction time t of multiplesnmoObtaining the recording time t1：
t1＝tv+tnmo
2.2.3) taking into account the steepest stratigraphic dip angle alpha within the range of the target layer on the existing seismic section according to the recording time t1Determining the recording time as t2：
2.2.4) increasing the partial recording time dt to obtain the required recording time t for as much convergence of the scattered energy as possible0' is:
further, the recording time t of the seismic data acquisition in the acquisition area in the step 2.3)0Comprises the following steps:
t0＝t0′-Δt+tc
wherein, tcIs constant or 0; t is t0' 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) during seismic data acquisition from the acquisition areaRecording the time t0Determining 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 processingmin；
3.2) streamer length L and minimum shot spacing x from seismic data acquisitionminDetermining the number of longitudinal (along the cable) coverage times N of the acquisition area:
N＝L/(2×xmin)。
further, the specific process of step 3.1) is as follows:
3.1.1) recording time t according to seismic data in the acquisition area0Determining the time interval t between two adjacent excitations of the seismic source excited by the seismic data:
t≥t0
3.1.2) recording time t according to seismic data in the acquisition area0And 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＝vship with a detachable hull×t≥vShip with a detachable hull×t0
Wherein v isShip with a detachable hullThe ship speed;
3.1.3) determining the minimum shot spacing x according to the binning requirement in seismic data processing and the determined range of shot spacing xmin。
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 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 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 middle and deep layer seismic acquisition operation, in order to acquire deep layer seismic data, the recording time of the seismic data needs to be increased, under the existing conventional acquisition and seismic data recording mode, 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.
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 wavefronts are eliminated by linear interference elimination.
Detailed Description
The present invention is described in detail below with reference to the attached 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 seismic data partial superposition recording method and system provided by the embodiment of the invention are used for seismic acquisition in offshore shallow water-deep water transition zones or deep water areas, the conventional towing mode of a seismic acquisition operation ship is not changed, the recording time of seismic data is prolonged on the premise of not reducing the longitudinal coverage times and the acquisition efficiency, the acquisition quality of the seismic data is ensured, and meanwhile, the field acquisition cost is not increased.
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 area1～h2，h1≤h2And dividing the whole collection construction area according to the acquired water depth range to obtain at least one collection area, which can be specifically as follows:
is when (h)2-h1)/2<h1When the water depth change in the whole collection area is small, the whole collection construction area is used as a collection area for collection;
② when (h)2-h1)/2≧h1When it is, consider the wholeThe water depth in the collection construction area changes greatly, 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/vwater (W) (1)
Wherein v isWater (W)At the speed of water, usually vWater (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 return0', specifically:
3.1) calculating the two-pass reflection time t of the deepest target layer of the acquisition region according to the one-dimensional velocity model of the single pointv。
3.2) will calculate the two-pass reflection time tvPlus the residual motion correction time t of multiplesnmoObtaining the recording time t1：
t1＝tv+tnmo (2)
3.3) taking into account the steepest stratigraphic dip angle alpha within the range of the target layer on the existing seismic section according to the recording time t1To converge the scattering energy of these steep formations, the recording time is determined to be t2：
3.4) increasing a portion of the recording time dt, typically by 1s, in order to converge as much scattered energy as possible, so that the required recording time t0' is:
4) according to the propagation time delta t of the seismic data when the water depth is 2h and the required recording time t0' calculating the recording time t of seismic data acquisition in the acquisition area0：
t0＝t0′-Δt+tc (5)
Wherein, tcIs a smaller constant or 0 and can be generally 50ms, 100ms or determined according to actual conditions.
5) According to the recording time t of seismic data acquisition in the acquisition area0Determining 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 processingminThe method specifically comprises the following steps:
5.1) according to the recording time t of the seismic data in the acquisition area during acquisition0Determining the time interval t between two adjacent excitations of the seismic source excited by the seismic data:
t≥t0 (6)
5.2) according to the recording time t of the seismic data in the acquisition area during acquisition0And 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＝vship with a detachable hull×t≥vShip with a detachable hull×t0 (7)
Wherein v isShip with a detachable hullThe boat speed is usually 4.5 knots.
5.3) determining the minimum shot spacing x according to the binning requirement in the seismic data processing and the determined range of the shot spacing xmin。
6) Streamer length L and minimum shot spacing x from seismic data acquisitionminDetermining the number of longitudinal (along the cable) coverage times N of the acquisition area:
N＝L/(2×xmin) (8)
7) entering the step 2) to reselect a certain divided acquisition area untilDetermining the acquisition parameters of all acquisition regions, including the time interval t between two adjacent excitations and the minimum shot distance x between two adjacent excitationsminAnd 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 excitedcThe back detector starts to record the seismic data, and the recording time length is t0The time length of the effective seismic data recorded in the mode is t0+ 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 recorded into the nth shot, and 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 figure is the direct wave excited by the next gun, which is the single-gun seismic data acquired in the offshore deep water area by adopting the method. 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 seismic data partial superposition recording method of the invention is explained in detail by taking the construction area of 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 construction area of the deep water area of south China sea is 500-2500 m, namely h1＝500m，h22500m, when (h)2-h1)/2＞h1According to the method, the collection construction area is divided into two collection areas for collection, the water depth of a collection area 1 is 500-1500 m, the water depth of a collection area 2 is 1500-2500 m, and two collections are calculated below respectivelyCollection parameters of the collection area.
2) Extracting the minimum water depth h in the acquisition area 1 to be 500m, and calculating the propagation time delta t of the seismic data when the water depth is 2h to be 2 x h/vWater (W)0.67s, wherein vWater (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 return0′＝10s。
4) According to the propagation time delta t of the seismic data when the water depth is 2h and the required recording time t0' calculating the recording time t of seismic data acquisition in the acquisition area010-0.67+ 0.05-9.38 s, where t is selectedc＝50ms。
5) According to the recording time t of the seismic data acquisition in the acquisition region 10Determining 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 selectedminIs 25 m. Since the recording time is 9.38s and 10s, the corresponding minimum value x of the shot distanceminMay each be 25m, in which case the recording time t is usually chosen0＝10s。
6) When the streamer length L for acquiring seismic data is 7200m, the minimum shot spacing x is determined according to the streamer length LminDetermining 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 in the acquisition area 2 to be 1500m, and calculating the propagation time delta t of the seismic data when the water depth is 2h to be 2 x h/bWater (W)2s, wherein bWater (W)＝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 return0′＝10s。
9) According to the propagation time delta t of the seismic data when the water depth is 2h and the required recording time t0' calculating the recording time t of seismic data acquisition in the acquisition area010-2+0.05 ═ 8.05s, where t is chosenc50 ms. The recording time of 2s in seawater is increased during treatment, and the obtained seismic recording time is still 10 s.
10) According to the recording time t of the seismic data in the acquisition region 20Determining the actual time interval t between two adjacent excitations of the seismic source excited by the seismic data to be 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 selectedminAnd 18.75 m.
11) When the streamer length L for acquiring seismic data is 7200m, the minimum shot spacing x is determined according to the streamer length LminDetermining 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 10s), shot spacing of 18.75m, covering times of 192 and the like.
12) And respectively carrying out seismic acquisition operation in the field according to acquisition parameters of the acquisition area 1 and the acquisition area 2 to obtain seismic data of the two acquisition areas, 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 that x is larger than or equal to 23.15m, the shot distance x is 25m, 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 that the actual recording time is 8.05s (the obtained seismic recording time is 10s), the shot spacing is 18.75m, the coverage times are 192 and the like, and the longitudinal coverage times of the 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 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.
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 superposition recording method of embodiment 1 may be embodied as a computer program product, which may include a computer readable storage medium having computer readable program instructions embodied thereon for performing the voice recognition method described in 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 memory device, a magnetic memory device, an optical memory device, an electromagnetic memory device, a semiconductor memory device, or any combination of the foregoing.
The above embodiments are only used for illustrating the present invention, and the structure, connection mode, manufacturing process, etc. of the components may be changed, and all equivalent changes and modifications performed on the basis of the technical solution of the present invention should not be excluded from the protection scope of the present invention.
Claims (10)
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 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.
2. A seismic data partial superposition recording method according to claim 1, wherein the specific process of step 2) is:
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/vwater (W)
Wherein v isWater (W)The water speed is adopted;
2.2) 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 2.3) calculating the recording time 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.
3. A seismic data partial superposition recording method according to claim 2, wherein the specific process of step 2.2) is:
2.2.1) calculating the two-pass reflection time t of the deepest target layer of the acquisition area according to the one-dimensional velocity model of the single pointv；
2.2.2) will calculate the two-way reflection time tvPlus the residual motion correction time t of multiplesnmoObtaining the recording time t1：
t1＝tv+tnmo
2.2.3) taking into account the steepest stratigraphic dip angle alpha within the range of the target layer on the existing seismic section according to the recording time t1Determining the recording time as t2：
2.2.4) increasing the partial recording time dt to obtain the required recording time t for as much convergence of the scattered energy as possible0' is:
4. a method for partial-overlap recording of seismic data as claimed in claim 2 wherein in step 2.3) the time t of recording of seismic data within the acquisition zone is determined0Comprises the following steps:
t0＝t0′-Δt+tc
wherein, tcIs constant or 0; t is t0' is the desired recording time; and delta t is the propagation time of the seismic data when the water depth is 2 h.
5. 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 laps.
6. A seismic data partial superposition recording method according to claim 5, wherein the specific process of step 3) is:
3.1) according to the recording time t of the seismic data in the acquisition area during acquisition0Determining 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 processingmin；
3.2) streamer length L and minimum shot spacing x from seismic data acquisitionminDetermining the number of longitudinal (along the cable) coverage times N of the acquisition area:
N＝L/(2×xmin)。
7. a seismic data partial superposition recording method according to claim 6, wherein the specific process of step 3.1) is as follows:
3.1.1) recording time t according to seismic data in the acquisition area0Determining the time interval t between two adjacent excitations of the seismic source excited by the seismic data:
t≥t0
3.1.2) recording time t according to seismic data in the acquisition area0And 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＝vship with a detachable hull×t≥vShip with a detachable hull×t0
Wherein v isShip with a detachable hullThe ship speed;
3.1.3) determining the minimum shot spacing x according to the binning requirement in seismic data processing and the determined range of shot spacing xmin。
8. 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 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 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.
9. 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 to 7.
10. 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 1-7.
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