Key information

Title
Seismic data acquisition for velocity modeling and imaging
Application number
20181128
Case type
National
Status
22.12.2025 Patent meddelt (B1)
Filed
28.08.2018
Priority
29.08.2017 US 62/551,275 and others
Effective date
28.08.2018
Publicly available
01.03.2019
Next annual fee due
31.08.2027
Applicant
PGS GEOPHYSICAL AS (NO)
Owner
PGS GEOPHYSICAL AS (NO)
Inventor
Arvind Sharma (US)
Agent
ZACCO NORWAY AS (NO)
Granted
22.12.2025
Patent number
349365
Expiry date
28.08.2038

Abstract and drawing

Disclaimer: This text has been machine-scanned and may contain errors – please refer to "Publications" for legally binding content.
A method and apparatus for data acquisition including: acquiring a first set of data for a survey area with streamer receivers on a streamer spread; and simultaneously acquiring a second set of data for the area with ocean bottom receivers, the first and second sets of data together forming a complete dataset for velocity modeling and imaging. A method including: navigating a first propulsion source along a first path in the area, wherein a streamer spread and a first seismic source are coupled to the first propulsion source; navigating a second propulsion source along a second path in the area, wherein a second seismic source is coupled to the second propulsion source; while navigating the first and second propulsion sources, activating at least one of the first and second seismic sources; and acquiring data with receivers on the streamer spread and with ocean bottom receivers distributed throughout the area.

Publications

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 02.01.2026 12-01 Saksbehandling 20181128(349365) UT PT Registreringsbrev nasjonal patent (15) (PT20181128)
10.11.2025 11-01 Saksbehandling 20181128 UT Intention to grant ZACCO NORWAY AS
 14.10.2025 10-05 Saksbehandling 20181128 INN Response to Office Action ZACCO NORWAY AS
 14.10.2025 10-04 Saksbehandling 20181128 INN Norwegian claims ZACCO NORWAY AS
 14.10.2025 10-03 Saksbehandling 20181128 INN Amended description and claims - for grant - marked ZACCO NORWAY AS
 14.10.2025 10-02 Saksbehandling 20181128 INN Amended description and claims - for grant - clean ZACCO NORWAY AS
 14.10.2025 10-01 Saksbehandling 20181128 INN Korrespondanse (Hovedbrev inn) ZACCO NORWAY AS
 18.08.2025 09-01 Saksbehandling 20181128 UT Substantive examination ZACCO NORWAY AS
 10.06.2025 08-04 Saksbehandling 20181128 INN Response ZACCO NORWAY AS
 10.06.2025 08-03 Saksbehandling 20181128 INN Amended description and claims - Marked ZACCO NORWAY AS
 10.06.2025 08-02 Saksbehandling 20181128 INN Amended description and claims - Clean ZACCO NORWAY AS
 10.06.2025 08-01 Saksbehandling 20181128 INN Korrespondanse (Hovedbrev inn) ZACCO NORWAY AS
 07.01.2025 07-02 Saksbehandling 20181128 UT PT report 12:46:53
07.01.2025 07-01 Saksbehandling 20181128 UT General letter patent ZACCO NORWAY AS
 13.11.2024 06-04 Saksbehandling 20181128 INN Response to Office Action ZACCO NORWAY AS
 13.11.2024 06-03 Saksbehandling 20181128 INN Claim amendments - 1st OA - marked-up ZACCO NORWAY AS
 13.11.2024 06-02 Saksbehandling 20181128 INN Claim amendments - 1st OA - clean ZACCO NORWAY AS
 13.11.2024 06-01 Saksbehandling 20181128 INN Korrespondanse (Hovedbrev inn) ZACCO NORWAY AS
 05.09.2024 05-01 Saksbehandling 20181128 UT General letter patent ZACCO NORWAY AS
 23.03.2021 06-01 Protest 2021/00090 INN Korrespondanse (Hovedbrev inn) Jeroen Hoogeveen
 17.03.2021 05-01 Protest 2021/00090 INN Korrespondanse (Hovedbrev inn) Jeroen Hoogeveen
 26.02.2021 04-01 Protest 2021/00090 UT Informasjon til innvender Jeroen Hoogeveen
26.02.2021 03-04 Protest 2021/00090 UT SBX press release 2011
26.02.2021 03-03 Protest 2021/00090 UT RE SV PATENT APPLICATION 201811282021371 - official protest
26.02.2021 03-02 Protest 2021/00090 UT obnobc2017-03
26.02.2021 03-01 Protest 2021/00090 UT Melding til søker ZACCO NORWAY AS
 26.02.2021 01-01 Protest 2021/00090 INN Nytt overprøvningskrav (OP) Jeroen Hoogeveen
25.02.2021 02-03 Protest 2021/00090 INN SBX press release 2011 Jeroen Hoogeveen
 25.02.2021 02-02 Protest 2021/00090 INN RE SV PATENT APPLICATION 201811282021371 - official protest Jeroen Hoogeveen
25.02.2021 02-01 Protest 2021/00090 INN obnobc2017-03 Jeroen Hoogeveen
 30.06.2020 04-01 Saksbehandling 20181128 UT PT Varsel om betaling av første årsavgift (3317) (PT20181128)
30.11.2018 03-02 Saksbehandling 20181128 INN Fullmakt ZACCO NORWAY AS
 30.11.2018 03-01 Saksbehandling 20181128 INN Korrespondanse (Hovedbrev inn) ZACCO NORWAY AS
 31.08.2018 02-01 Saksbehandling 20181128 UT Formal Examination 1 ZACCO NORWAY AS
 28.08.2018 01-04 Saksbehandling 20181128 INN Beskrivelse ZACCO NORWAY AS
 28.08.2018 01-03 Saksbehandling 20181128 INN Patenttegninger ZACCO NORWAY AS
 28.08.2018 01-02 Saksbehandling 20181128 INN Overdragelsesdokument ZACCO NORWAY AS
 28.08.2018 01-01 Saksbehandling 20181128 INN Søknadsskjema Patent ZACCO NORWAY AS

Description, claims and drawings

Disclaimer: This text has been machine-scanned and may contain errors – please refer to "Publications" for legally binding content. Description
3493651SEISMIC DATA ACQUISITION FOR VELOCITY MODELING AND IMAGINGBACKGROUND[0001] This disclosure is related generally to the field of marine surveying. Marine surveying can include, for example, seismic and/or electromagnetic surveying, among others. For example, this disclosure may have applications in marine surveying in which one or more sources are used to generate energy (e.g., wavefields, pulses, signals), and geophysical sensors or receivers—either towed or ocean bottom—receive energy generated by the sources and possibly affected by interaction with subsurface formations. Geophysical sensors may be towed on cables referred to as streamers. Some marine surveys locate geophysical sensors on ocean bottom cables or nodes in addition to, or instead of, streamers. The geophysical sensors thereby collect survey data which can be useful in the discovery and/or extraction of hydrocarbons from subsurface formations.[0002] Data acquired during a marine survey may be interpreted according to a number of techniques. For example, marine survey data, especially wide-azimuth marine survey data, may be used to generate a velocity model, which may describe the spatial distribution of acoustic wave velocity through the subsurface. A velocity model may include constant-velocity units (layers), through which raypaths obeying Snall’s law can be traced. A velocity model may be further used in data interpretation, for example in depth migration, which may be used to generate an image of the subsurface. Migration typically transforms seismic data, which may be acquired and/or recorded as a function of arrival time, into images of scaled features that are located at proper depth and location within the subsurface. Imaging may benefit from a dense set of narrowazimuth/long-offset data.[0003] Many data processing and/or interpretation techniques may generate and/or amplify noise in the acquired data. Robust and/or redundant datasets help to improve signal-to-noise ratios. However, acquiring additional data to form robust and/or redundant datasets can be costly and time consuming. For example, ocean bottom receivers may be densely-spaced (e.g., typically about 400 m between adjacent 3493652receivers) to provide better data quality. However, operating costs increase with the number of receivers. Historically, towed-streamer surveys have struggled to match the repeatability of ocean bottom receiver surveys, being subject to variable current or wind conditions and surface obstructions. It would be beneficial to optimally acquire data while managing data acquisition costs.[0004] The prior art includes US 2015346368 A1, which describes a system and method of seismic data collection for land and marine data that utilizes narrowband to monochromatic low-frequency non-impulsive sources designed to optimize the ability of migration/inversion algorithms to image the subsurface of the Earth, in particular, fullwaveform inversion.[0005] It is thus provided a method of seismic data acquisition, characterized by: - acquiring, with a first seismic source comprising an air gun, a first set of seismic data for a survey area with a first plurality of streamer receivers on a first streamer spread, wherein acquiring the first set of seismic data comprises: - navigating a first propulsion source along a first sail line in the survey area, wherein the first seismic source and the first streamer spread are coupled to the first propulsion source;- activating the first seismic source while navigating the first propulsion source; - while navigating the first propulsion source, navigating a second propulsion source along a second sail line in the survey area, wherein a second seismic source is coupled to the second propulsion source; and - activating the second seismic source while navigating the second propulsion source, wherein the first sail line is orthogonal to the second sail line; - simultaneously acquiring, with the first seismic source, a second set of seismic data for the survey area with a plurality of ocean bottom receivers, wherein the first set of seismic data and the second set of seismic data together form a complete dataset for velocity modeling and imaging; and - simultaneously acquiring a third set of seismic data for the survey area with a second plurality of streamer receivers on a second streamer spread, wherein the second streamer spread is coupled to the second propulsion source. 3493653BRIEF DESCRIPTION OF THE DRAWINGS[0006] So that the manner in which the features of the present disclosure can be understood in detail, a more particular description of the disclosure may be had by reference to embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only exemplary embodiments and are therefore not to be considered limiting of its scope, may admit to other equally effective embodiments.[0007] Figure 1 illustrates an exemplary data acquisition configuration.[0008] Figure 2 illustrates a source vessel from the exemplary data acquisition configuration of Figure 1.[0009] Figure 3 illustrates a streamer vessel from the exemplary data acquisition configuration of Figure 1.[0010] Figures 4A - 4E illustrate representations of datasets that may be acquired by exemplary data acquisition configuration of Figure 1.DETAILED DESCRIPTION[0011] It is to be understood the present disclosure is not limited to particular devices or methods, which may, of course, vary. It is also to be understood that the terminology used herein is for the purpose of describing particular embodiments only, and is not intended to be limiting. As used herein, the singular forms “a”, “an”, and “the” include singular and plural referents unless the content clearly dictates otherwise. Furthermore, the words “can” and “may” are used throughout this application in a permissive sense (i.e., having the potential to, being able to), not in a mandatory sense (i.e., must). The term “include,” and derivations thereof, mean “including, but not limited to.” The term “coupled” means directly or indirectly connected. The word “exemplary” is used herein to mean “serving as an example, instance, or illustration.” Any aspect described herein 3493654as “exemplary” is not necessarily to be construed as preferred or advantageous over other aspects. The term “substantially” means within about -10% variation. The term “nominal” means as planned or designed in the absence of variables such as wind, waves, currents, or other unplanned phenomena. “Nominal” may be implied as commonly used in the field of marine surveying.[0012] The term “simultaneous” does not necessarily mean that two or more events occur at precisely the same time or over exactly the same time period. Rather, as used herein, “simultaneous” means that the two or more events occur near in time or during overlapping time periods. For example, the two or more events may be separated by a short time interval that is small compared to the duration of the surveying operation. As another example, the two or more events may occur during time periods that overlap by about 40% to about 100% of either period.[0013] If there is any conflict in the usages of a word or term in this specification and one or more patent or other documents that may be incorporated herein by reference, the definitions that are consistent with this specification should be adopted for the purposes of understanding this disclosure.[0014] The present disclosure generally relates to marine surveying methods and apparatuses, and, at least in some embodiments, to novel data acquisition configurations, and their associated methods of use.[0015] One of the many potential advantages of the embodiments of the present disclosure is that multiple datasets may be acquired simultaneously. For example, in some embodiments, seismic data acquisition may simultaneously generate datasets with one or more long-offset towed streamer systems, one or more source vessel systems, and an ocean bottom receiver system. The simultaneously-acquired multiple datasets may together provide a collective dataset that can be used for both velocity modeling and for imaging. For example, data acquired with the ocean bottom receiver system may be useful for velocity modeling, and data acquired with receivers on the towed streamers may be useful for imaging. As used herein, a “complete dataset” refers to a set of seismic data that has sufficient information to be used for both velocity 3493655modeling and for imaging. Another potential advantage includes saving operational costs by acquiring the multiple datasets simultaneously. Another potential advantage includes saving operational costs by operating the various systems independently. For example, operation of each of the towed streamer systems independently of the other allows each tow vessel to navigate more efficiently in response to local sea conditions, survey plan, crew availability, etc. Embodiments of the present disclosure can thereby be useful in the discovery and/or extraction of hydrocarbons from subsurface formations.[0016] Figure 1 illustrates an exemplary acquisition configuration 100. As illustrated, the survey area 101 of acquisition configuration 100 has a length 106 and a width 108. For example, the length 106 may be between about 50 km and about 200 km. The width 108 may be between about 10 km and about 100 km. In some embodiments, the length 106 and the width 108 may be substantially equal. A plurality of ocean bottom receivers 110 are distributed throughout the survey area 101. For example, the ocean bottom receivers 110 may be on ocean bottom nodes or ocean bottom cables. Each ocean bottom receiver 110 may be, for example, a hydrophone, a geophone, a pressure sensor, a particle velocity sensor, another type of seismic data receiver, and/or an array or combination thereof. It should be understood that the ocean bottom receivers 110 may be at or near the seafloor, for example within about 10 m of the seafloor. As illustrated, the ocean bottom receivers 110 can be distributed in a regular-rectangular pattern throughout the survey area 101. It should be understood that other distribution patterns may be utilized, including any distribution pattern that is applicable to marine surveying with ocean bottom receivers. As illustrated, the distribution pattern of the ocean bottom receivers 101 has a major axis 102 and a minor axis 104, each defining lines of symmetry in the distribution pattern of the ocean bottom receivers 110. In some embodiments, the major axis 102, the minor axis 104, and/or any other line of symmetry of the distribution pattern of the ocean bottom receivers 110 may be skewed relative to length 106 and/or width 108. In some embodiments, the ocean bottom receivers 110 may be spaced in a sparse-node distribution pattern. For example, the spacing between adjacent ocean bottom receivers 110 may be between about 0.5 km and about 3 km. In some embodiments, the spacing between adjacent ocean bottom receivers 110 parallel 3493656to major axis 102 may be the same as the spacing between adjacent ocean bottom receivers 110 parallel to minor axis 104. For example, the spacing between adjacent ocean bottom receivers 110 may be about 2 km in each direction. As another example, the spacing between adjacent ocean bottom receivers 110 parallel to major axis 102 may be about 2 km, while the spacing between adjacent ocean bottom receivers 110 parallel to minor axis 104 may be about 1 km.[0017] As illustrated in Figure 1, acquisition configuration 100 also includes a pair of source vessels 120. Figure 2 illustrates source vessels 120 in more detail. Each source vessel 120 includes a propulsion source 222, such as a boat or a remotely operated vehicle, and a seismic source 224. For example, the seismic source 224 may be one or more air guns, marine vibrators, and/or combinations and arrays thereof. For example, in some embodiments, seismic source 224 may include, or be configured to act as, two independently-activated sources of seismic energy. (It should be appreciated that multiple independent sources of seismic energy on a vessel may allow for more closelyspaced source activations. For example, while one air gun is resetting, another may be firing.) Source vessel 120 may include additional equipment (not shown) to provide navigation, source control, data recording, and/or communications (e.g., with other components of acquisition configuration 100). Source vessel 120 may be capable of navigating along a nominal survey path under power of propulsion source 222 while activating seismic source 224 according to a nominal survey plan. Source vessel 120 may also be capable of recording locations of propulsion source 222 and/or timing of the activations of seismic source 224. Source vessel 120 may also be capable of communicating with other components of acquisition configuration 100, including communications regarding navigation and/or source activation. Although illustrated as being directly coupled in a fixed spatial relationship, seismic source 224 may be towed from propulsion source 222 (e.g., on a flexible source cable).[0018] As illustrated in Figure 1, acquisition configuration 100 also includes a pair of streamer vessels 130. Figure 3 illustrates streamer vessel 130 in more detail. Each streamer vessel 130 includes a source vessel 320, configured similarly to source vessel 120 (i.e., having a propulsion source 322 and a seismic source 324). Each streamer 3493657vessel 130 also includes a streamer spread 340. Streamer spread 340 includes a plurality of streamers 341 towed behind source vessel 320. As illustrated, the streamer spread 340 has a length 346 and a width 348. For example, the length 346 may be between about 6 km and about 12 km. The width 348 may be between about 1 km and about 2 km. Each streamer 341 may include a plurality of streamer receivers (not shown). Each streamer receiver may be, for example, a hydrophone, a geophone, a pressure sensor, a particle velocity sensor, another type of seismic data receiver, and/or an array or combination thereof. Streamer vessel 130 may include additional equipment (not shown) to provide navigation, source control, data recording, and/or communications (e.g., with other components of acquisition configuration 100). Streamer vessel 130 may be capable of navigating along a nominal survey path while activating its seismic source 324 and/or acquiring streamer receiver data according to a nominal survey plan. Streamer vessel 130 may also be capable of recording locations of its propulsion source 322, timing of the activations of its seismic source 324, and/or location, timing, and measurements from streamer receivers on streamers 341. Streamer vessel 130 may also be capable of communicating with other components of acquisition configuration 100, including communications regarding navigation, source activation, and data acquisition. Although illustrated as being closely coupled, streamer spread 340 may be towed at a distance from source vessel 320. Although illustrated as forming a simple, planar rectangle, it should be understood that streamer spread 340 may include one or more streamer receivers at a variety of depths and/or one or more streamers 341 following various curves or fanning angles, either by design or as a consequence of operational conditions (e.g., water currents).[0019] As illustrated in Figure 1, the pair of source vessels 120 may operate along substantially orthogonal nominal survey paths. As used herein, a survey path may be made up of one or more sail lines. Typically, sail lines will substantially cross the survey area (e.g., from top to bottom, or from side to side), and the multiple sail lines of a survey path may be substantially parallel to one another. Some survey paths include end-turns that directly connect adjacent sail lines, while other survey paths interleave the sail lines (e.g., adjacent sail lines are separated by two or more end-turns). When the pair of source vessels 120 operate along substantially orthogonal nominal survey 3493658paths, each of the sail lines of one of the source vessels 120 will be substantially orthogonal to each of the sail lines of the other source vessel 120.[0020] Also as illustrated in Figure 1, the pair of streamer vessels 130 may operate along substantially orthogonal nominal survey paths. In some embodiments, one of the source vessels 120 may operate along a substantially parallel (or anti-parallel) nominal survey path with one of the pair of streamer vessels 130. In some embodiments, one of the source vessels 120 may operate along a skewed nominal survey path (i.e., neither substantially orthogonal nor substantially parallel) relative to one of the pair of streamer vessels 130. In some embodiments, the nominal survey paths of one of the source vessels 120 and one of the streamer vessels 130 may be substantially parallel to the length 106 of the survey area 101 and/or the major axis 102 of the distribution pattern of the ocean bottom receivers 110. In some embodiments, the nominal survey paths of one of the source vessels 120 and one of the streamer vessels 130 may be substantially parallel to the width 108 of the survey area 101 and/or the minor axis 104 of the distribution pattern of the ocean bottom receivers 110. In some embodiments, the nominal survey paths of source vessels 120 and streamer vessels 130 may be coordinated. For example, when one of the source vessels 120 operates along a substantially parallel (or anti-parallel) nominal survey path with one of the pair of streamer vessels 130, the nominal survey path of the source vessel 120 may be staggered between adjacent sail lines of the nominal survey path of the streamer vessel 130. In some embodiments, the nominal survey path of the source vessel 120 may be symmetrically staggered in the middle of the nominal survey path of the streamer vessel 130, such that a sail line of the source vessel 120 may be substantially equidistant from each of two adjacent sail lines of the streamer vessel 130.[0021] As would be appreciated by one of ordinary skill in the art with the benefit of this disclosure, narrow-azimuth and/or long-offset data may be acquired by streamer receivers in a streamer spread 340 in response to activations of seismic source 324 on the same source vessel 320 that tows the streamer spread 340 (as illustrated in Figures 4A and 4B). As would be appreciated by one of ordinary skill in the art with the benefit of this disclosure, random-azimuth and/or variable-offset data may be acquired by 3493659streamer receivers in a streamer spread 340 in response to activations of one or more seismic sources 224 on source vessels 120 and/or seismic source 324 on a different source vessel 320 than that which tows the streamer spread 340 (as illustrated in Figures 4C and 4D).[0022] Figures 4A-4E illustrate representations of datasets that may be acquired by acquisition configuration 100. Figure 4A illustrates a representation of a narrow-azimuth and/or long-offset dataset 551 generated by activations of seismic source 324 and measurements by streamer receivers in streamer spread 340 while source vessel 320 tows streamer spread 340. The streamer vessel 130 in Figure 4A follows a nominal survey path that is parallel to width 108 of survey area 101. Figure 4B illustrates a representation of another narrow-azimuth and/or long-offset dataset 552 generated by activations of another seismic source 324 and measurements by streamer receivers in another streamer spread 340 while the source vessel 320 tows the streamer spread 340. The streamer vessel 130 in Figure 4B follows a nominal survey path that is orthogonal to width 108 of survey area 101. Figure 4C illustrates a representation of a random-azimuth and variable-offset dataset 553 generated by activations of two seismic sources 224 (on two different source vessels 120) and one seismic source 324 (on a non-towing source vessel 320) and measurements by streamer receivers in streamer spread 340 while towing source vessel 320 (remote from the seismic source 324) tows streamer spread 340. The streamer vessel 130 in Figure 4C follows a nominal survey path that is parallel to width 108 of survey area 101. Figure 4D illustrates a representation of another random-azimuth and variable-offset dataset 554 generated by activations of the two seismic sources 224 (as in Figure 4C) and one other seismic source 324 (on another non-towing source vessel 320) and measurements by streamer receivers in another streamer spread 340 while another towing source vessel 320 (remote from the other seismic source 324) tows another streamer spread 340. The streamer vessel 130 in Figure 4D follows a nominal survey path that is orthogonal to width 108 of survey area 101. It should be appreciated that datasets 553 and 554 will have about three-times more source activations than datasets 551 and 552. It should be appreciated that datasets 551, 552, 553, and 554 may be well-suited, individually or collectively, to generating an image of the subsurface below survey area 101. Figure 4E 34936510illustrates a representation of a dataset 555 that is generated by activations of any of the seismic sources 224, 324 (as shown in Figures 4C and 4D) at a plurality of shot points 425 and measurements by any of the ocean bottom receivers 110 (only one shown for clarity). It should be appreciated that dataset 555 may be well-suited to generating a velocity model of the subsurface below survey area 101.[0023] Acquisition configuration 100 provides an example of a Complete Velocity Modeling and Imaging Acquisition (CVMIA) survey configuration. CVMIA survey configurations may optimally acquire data across a survey area 101 while managing data acquisition costs. CVMIA survey configurations may result in at least five datasets, including: two different narrow-azimuth and long-offset datasets 551, 552 (as illustrated in Figures 4A and 4B), two different random-azimuth and variable-offset datasets 553, 554 (as illustrated in Figures 4C and 4D), and one full-area/time dataset 555 (as illustrated in Figure 4E). In some embodiments, the two different narrow-azimuth and long-offset datasets are generated by simultaneously operating two streamer vessels 130 along orthogonal nominal survey paths, one of which is parallel to a length 106 of the survey area 101. In some embodiments, the two different random-azimuth and variable-offset datasets are generated by simultaneously operating a first source vessel 120 along a nominal survey path parallel to that of one of the streamer vessels 130, and also simultaneously operating a second source vessel 120 along a nominal survey path parallel to that of the other streamer vessel 130. In some embodiments, the fullarea/time dataset is generated by deploying a plurality of ocean bottom receivers 110 across the survey area 101 in a distribution pattern having at least one axis of symmetry, and operating at least one propulsion source 222, 322 with a seismic source 224, 324 along a nominal survey path that is parallel to a length 106 of the survey area 101. In some embodiments, the length 106 of the survey area 101 may be parallel to the axis of symmetry of the distribution pattern of the plurality of ocean bottom receivers 110. To optimally acquire seismic data, each of the at least five datasets of a CVMIA survey configuration may be acquired simultaneously. For example, a single activation of any one of the seismic sources 224, 324 in the CVMIA survey configuration may generate data in at least three of the at least five datasets. As another example, a single receiver (either an ocean bottom receiver 110 or a streamer receiver) may measure 34936511energy resulting from activation of each of the seismic sources 224, 324 in the CVMIA survey configuration, thereby acquiring data for multiple datasets simultaneously or near-simultaneously. To optimally acquire seismic data, each of the seismic sources 224, 324 of a CVMIA survey configuration may be activated individually and/or independently. For example, the planned and/or actual timing of activation of one seismic source 224, 324 of a CVMIA survey configuration may be independent of the planned and/or actual timing of activation of each of the other seismic sources 224, 324 of the CVMIA survey configuration. In some embodiments, activation of each of the seismic sources 224, 324 of a CVMIA survey configuration may be coordinated, either according to a coordinated nominal survey plan or coordinated by communications between the seismic sources 224, 324 during the survey. To optimally acquire seismic data, each of the propulsion sources 222, 322 of a CVMIA survey configuration may be navigated individually and/or independently. For example, the planned and/or actual navigation of one propulsion source 222, 322 of a CVMIA survey configuration may be independent of the planned and/or actual navigation of each of the other propulsion sources 222, 322 of the CVMIA survey configuration. It should be understood that operational conditions may dictate brief periods of coordinated source activation and/or propulsion source 222, 322 navigation (e.g., avoidance of marine mammal disturbance, avoidance of vessel collisions, etc.).[0024] In some embodiments, each of the vessels (source vessels 120 and streamer vessels 130) may follow an independent nominal survey plan. Each of the nominal survey plans may include nominal survey paths starting at different locations and/or include different navigational inputs. Each of the vessels (source vessels 120 and streamer vessels 130) may operate at different speeds and or headings based on its nominal survey plan and/or navigational inputs. In some embodiments, each of the nominal survey plans may include a sail line spacing S, which may be about half of the width 348 of the streamer spread 340. In some embodiments, each of the nominal survey plans may include a source-activation spacing s, which may be a function of sail line spacing. (As used herein, source-activation spacing is the distance a seismic source travels along a sail line between consecutive activations.) In some embodiments, wherein the nominal survey plan of a source vessel 120 has a nominal 34936512survey path parallel to that of a streamer vessel 130, the nominal survey plans may include a nominal survey path for the source vessel 120 that is staggered in the middle of the nominal survey path of the streamer vessel 130, creating a shot patch of half the sail line spacing (S/2) in both directions. In some embodiments, each of the nominal survey plans may include starting locations and/or navigation speeds that are selected to improve and/or maximize the data generated by activation of seismic sources 224 on the source vessels 120.[0025] In some embodiments, each of the vessels (source vessels 120 and streamer vessels 130) may follow a coordinated nominal survey plan. In some embodiments, each of the vessels 120, 130 may be capable of communicating with other components of acquisition configuration 100, including communications regarding navigation and/or source activation. Each of the vessels 120, 130 may operate at coordinated speeds and or headings based on its nominal survey plan and/or navigational inputs. In some embodiments, navigation of each of the vessels 120, 130 may be coordinated, either according to a coordinated nominal survey plan or coordinated by communications between the vessels during the survey.[0026] The methods and systems described herein may be used to manufacture a geophysical data product indicative of certain properties of a subterranean formation. The geophysical data product may include, for example, geophysical data such as pressure data, particle motion data, particle velocity data, particle acceleration data, and any seismic image that results from using the methods and systems described above. The geophysical data product may include, for example, measurements made by the streamer receivers and/or ocean bottom receivers 110, navigation and/or source activation records, and/or datasets 551-555. The geophysical data product may be stored on a non-transitory computer-readable medium as described above. The geophysical data product may be produced offshore (i.e., by equipment on the streamer vessel 130) or onshore (i.e., at a computing facility on land) either within the United States or in another country. When the geophysical data product is produced offshore or in another country, it may be imported onshore to a data-storage facility in the United 34936513States. Once onshore in the United States, geophysical analysis may be performed on the geophysical data product.[0027] While the foregoing is directed to embodiments of the present disclosure, other and further embodiments of the disclosure may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
Claims
34936514Claims:1. A method of seismic data acquisition, characterized by:acquiring, with a first seismic source (324) comprising an air gun, a first set of seismic data (551) for a survey area (101) with a first plurality of streamer receivers (341) on a first streamer spread (340), wherein acquiring the first set of seismic data (551) comprises:navigating a first propulsion source (322) along a first sail line in the survey area, wherein the first seismic source (324) and the first streamer spread (340) are coupled to the first propulsion source (322);activating the first seismic source (324) while navigating the first propulsion source (322);while navigating the first propulsion source (322), navigating a second propulsion source (322) along a second sail line in the survey area (101), wherein a second seismic source (324) is coupled to the second propulsion source (322); andactivating the second seismic source (324) while navigating the second propulsion source (322), wherein the first sail line is orthogonal to the second sail line;simultaneously acquiring, with the first seismic source, a second set of seismic data (555) for the survey area with a plurality of ocean bottom receivers (110), wherein the first set of seismic data (551) and the second set of seismic data (555) together form a complete dataset for velocity modeling and imaging; and simultaneously acquiring a third set of seismic data (552) for the survey area with a second plurality of streamer receivers (341) on a second streamer spread (340), wherein the second streamer spread (340) is coupled to the second propulsion source (322).2. The method of claim 1, wherein the first seismic source (324) comprises two independently-activated sources of seismic energy.3. The method of claim 1, wherein the first propulsion source (322) is navigated independently of the second propulsion source (322).349365154. The method of claim 1, wherein the first seismic source (324) is activated independently of the second seismic source (324).5. The method of claim 1, further comprising:while navigating the first propulsion source (322), navigating a third propulsion source (222) in the survey area, wherein a third seismic source (224) is coupled to the third propulsion source (222);activating the third seismic source (224) while navigating the third propulsion source (222) in the survey area;while navigating the first propulsion source (322), navigating a fourth propulsion source (222) in the survey area, wherein a fourth seismic source (224) is coupled to the fourth propulsion source (222),activating the fourth seismic source (224) while navigating the fourth propulsion source (222) in the survey area, wherein neither the third propulsion source (222) nor the fourth propulsion source (222) is coupled to a streamer spread.6. The method of claim 5 wherein the first set of seismic data comprises:a first subset of seismic data acquired with the first plurality of streamer receivers (341) and the first seismic source (324);a second subset of seismic data acquired with the first plurality of streamer receivers (341) and the second seismic source (324); anda third subset of seismic data acquired with the first plurality of streamer receivers (341) and at least one of: the second seismic source (324), the third seismic source (224), and the fourth seismic source (224).34936516Patentkrav:1. Fremgangsmåte ved seismisk datainnsamling, karakterisert ved: innsamling, med en første seismisk kilde (324) omfattende en luftkanon, av et første sett av seismiske data (551) for et undersøkelsesområde (101) med et første flertall streamermottakere (341) på en første streamerkonfigurasjon (340), hvor innsamlingen av det første settet av seismiske data (551) omfatter å: navigere en første fremdriftskilde (322) langs en første navigeringslinje i undersøkelsesområdet, hvor den første seismiske kilden (324) og den første streamerkonfigurasjonen (340) er koblet til den første fremdriftskilden (322);aktivere den første seismiske kilden (324) mens den første fremdriftskilden (322) navigeres;mens den første fremdriftskilden (322) navigeres, navigere en andre fremdriftskilde (322) langs en andre navigeringslinje i undersøkelsesområdet (101), hvor en andre seismisk kilde (324) er koblet til den andre fremdriftskilden (322); ogaktivere den andre seismiske kilden (324) mens den andre fremdriftskilden (322) navigeres, hvor den første navigeringslinjen er ortogonal på den andre navigeringslinjen;samtidig innsamling, med den første seismiske kilden, av et andre sett av seismiske data (555) for undersøkelsesområdet med et flertall havbunnsmottakere (110), hvor det første settet av seismiske data (551) og det andre settet av seismiske data (555) sammen danner et fullstendig datasett for hastighetsmodellering og avbildning; ogsamtidig innsamling av et tredje sett av seismiske data (552) for undersøkelsesområdet med et andre flertall streamermottakere (341) på en andre streamerkonfigurasjon (340), hvor den andre streameroppstillingen (340) er koblet til den andre fremdriftskilden (322).349365172. Fremgangsmåte ifølge krav 1, hvor den første seismiske kilden (324) omfatter to uavhengig aktiverte kilder for seismisk energi.3. Fremgangsmåte ifølge krav 1, hvor den første fremdriftskilden (322) navigeres uavhengig av den andre fremdriftskilden (322).4. Fremgangsmåte ifølge krav 1, hvor den første seismiske kilden (324) aktiveres uavhengig av den andre seismiske kilden (324).5. Fremgangsmåte ifølge krav 1, videre omfattende å:mens den første fremdriftskilden (322) navigeres, navigere en tredje fremdriftskilde (222) i undersøkelsesområdet, hvor en tredje seismisk kilde (224) er koblet til den tredje fremdriftskilden (222);aktivere den tredje seismiske kilden (224) mens den tredje fremdriftskilden (222) navigeres i undersøkelsesområdet;mens den første fremdriftskilden (322) navigeres, navigere en fjerde fremdriftskilde (222) i undersøkelsesområdet, hvor en fjerde seismisk kilde (224) er koblet til den fjerde fremdriftskilden (222),aktivere den fjerde seismiske kilden (224) mens den fjerde fremdriftskilden (222) navigeres i undersøkelsesområdet, hvor hverken den tredje fremdriftskilden (222) eller den fjerde fremdriftskilden (222) er koblet til en streamerkonfigurasjon.6. Fremgangsmåte ifølge krav 5 hvor det første settet av seismiske data omfatter: en første delmengde av seismiske data samlet inn med det første flertallet streamermottakere (341) og den første seismiske kilden (324);en andre delmengde av seismiske data samlet inn med det første flertallet streamermottakere (341) og den andre seismiske kilden (324); ogen tredje delmengde av seismiske data samlet inn med det første flertallet streamermottakere (341) og minst én av: den andre seismiske kilden (324), den tredje seismiske kilden (224) og den fjerde seismiske kilden (224).
Drawings

Priority

29.08.2017 US 62/551,275 14.08.2018 US 16/103,867

Patent classes

IPC classesG01V 1/20G01V 1/38CPC classesG01V 1/3808G01V 1/20G01V 1/189G01V 2210/61

Citations

US 2015346368 A1 (A1)US 2004218470 A1 (A1)US 2015234065 A1 (A1)US 2015293250 A1 (A1)US 2016238730 A1 (A1)US 2012147699 A1 (A1)US 2016187504 A1 (A1)SeaBird Exploration press release, 27 January 2011 [Retreived from the internet 2025.01.06] ()

Applicants, owners and inventors

Owners
PGS GEOPHYSICAL AS
Postboks 251 Lilleaker 0216 OSLO NO (OSLO Municipality, Oslo county)Org. number: 960563085Inventors
Arvind Sharma
2006 Whittington Court S. TX77077 HOUSTON US

Agent

ZACCO NORWAY AS
ZACCO NORWAY AS

Org. number: 982702887

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Open in The Brønnøysund Register Centre
Postboks 488 0213 OSLO NO (OSLO Municipality, Oslo county)
Org. number: 982702887
Reference: P302462NO00

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Oppositions and appeals

ProtestReceived: 25.02.2021 NIPO's case No.: 2021/00090Current status: Avgjort. Patentsaken endelig avgjort, behandling av protest avsluttes
RequestorJeroen Hoogeveen c/o MultiClient Geophysical AS, Skysstasjon 5 1383 ASKER NO

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