OA17041A - Extracting SV shear data from P-Wave seismic data. - Google Patents
Extracting SV shear data from P-Wave seismic data. Download PDFInfo
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Abstract
A system and method of processing seismic data obtained using a surface-based receiver configured to measure vertical movement of the earth includes retrieving seismic data from a storage device, the seismic data comprising P-P data and shear mode data. The P-P data and shear mode data were both received at a surfacebased receiver configured to measure vertical movement of the Earth to generate the seismic data. The system and method further include processing the seismic data to extract the shear mode data and generating a shear mode image based on the extracted shear mode data.
Description
The présent application relates generally to Systems and methods for seismic exploration, induding the acquisition and/or processing of seismic data to estimate properties of the Earth's subsurface.
The principal type of data used to explore for oil and gas resources is seismic reflection data that image subsurface geology. There are three seismic wave modes that can be used for subsurface imaglng - a compressional-wave (P) mode and two shear-wave modes (SV and SH). When geophyslcists acqulre seismic data that hâve ail three of these modes, the data are called full elastic-wavefield data. Full elastic-wavefield data are acquired by deploying three separate orthogonal seismic sources at every source station across a prospect area. One source applies a vertical force vector to the Earth, a second source applies a horizontal force vector In the Inline (X) direction, and a third source applies a second horizontal force vector in the crossline (Y) diredion.
The wavefields produced by each of these three orthogonal-force sources are recorded by 3-component geophones that hâve orthogonal (XYZ) sensing éléments. The resulting data are called 9-component data because they consist of 3-component data produced by three different sources that occupy the same source station In sequence, not simultaneously. Full descriptions and Illustrations of the sources, sensors, and field procedures used to acqulre full elastic-wavefield data can be found in Chapter 2, Multicomponent Seismic Technology, Geophyslcal Références Sériés No. 18, Society of Exploration Geophyslcists, authored by B.A. Hardage, Μ. V. DeAngelo, P. E. Murray, and D. Sava (2011). Vertical, single-component, surface-based geophones are used for the purpose of acquiring P-wave seismic data
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SUMMARY
A System and method of processing seismic data obtained using a surface-based receiver configured to measure vertical movement of the Earth includes retrieving seismic data from a storage device, the seismic data comprising P-P data and shear mode data. The P-P data and shear mode data were both received at a surface-based receiver configured to measure vertical movement of the Earth to generate the seismic data. The System and method further include processing the seismic data to extract the shear mode data and generating a shear mode image based on the extracted shear mode data.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1 is a diagram illustrating a full-elastic, multicomponent seismic wavefield propagatïng in a homogeneous Earth, according to an exempîary embodiment.
FIG. 2 is a diagram showing SH and SV shear wave displacements, according to an exempîary embodiment.
FIG. 3 Is a map view of SH and SV illumination patterns for orthogonal (X and Y) horizontai-displacement sources.
FIG. 4 is a comparison of SH, SV and P velocity behavlor for elastic wave propagation in horizontally layered media.
FIG. 5 is a cross-sectional view of a theoretical calculation of P and SV radiation patterns produced when a vertical force F is applied to the surface of the Earth, shown for two different values of the Poisson's ratio of the Earth layer, according to an exempîary embodiment.
FIGs. 6A and 6B show an S-wave radiation pattern from FIG. 5 displayed as a 3D object, according to an exempîary embodiment.
FIG. 7A is a chart of VSP data acquired using a vertical-displacement source, according to an exempîary embodiment.
FIG. 7B is a chart of VSP data acquired using a vertical-displacement source, according to an exempîary embodiment.
FIG. 8 Is a diagram showing a source-receiver geometry used to analyze P and S radiation patterns emitted by seismic sources, according to an exempîary embodiment.
FIG. 9 Is a diagram Illustrating takeoff angle apertures, according to an exempîary embodiment.
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FIG. 10 Is a diagram illustrating transformation of X, Y, Z receivers to P, SV, SH receivers, according to an exemplary embodiment
FIG. 11 is a set of charts showing example X, Y, Z data acquired with a vertical array from a vertical-impact source, and corresponding data rotated to P, SV and SH data space, s according to an exemplary embodiment.
FIG. 12 is a set of charts showing example X, Y, Z data acquired with a vertical array from a shot hole explosive source, and corresponding data rotated to P, SV and SH data space, according to an exemplary embodiment.
FIG. 13 is a set of charts showing example X, Y, Z data acquired with a vertical array io from a vertical vibrator source, and corresponding data rotated to P, SV and SH data space, according to an exemplary embodiment.
FIG. 14 is an illustration of the principle of data-polarity reversais applied to verticalforce source data to create constant-polarity S-wave data across selsmic Image space, according to an exemplary embodiment.
FIG. 15 illustrâtes a first example of polarities of vertical-force seismic data and the resuit of reversing polarities in the negatîve-polarity domain to convert vertical-force source data to constant-polarity dipole-source data, according to an exemplary embodiment.
FIG. 16 Illustrâtes a second example of polarities of vertical-force seismic data and the resuit of reversing polarities In the negative-polarity domain to convert vertical-force 20 source data to constant-polarity dipole-source data, according to an exemplary embodiment.
FiG. 17 Is a block diagram of a data acquisition and processing System and method for acquiring and processing full elastic waveform data from a vertical-force source using surface-based sensors, according to an exemplary embodiment.
FIG. 18 Is a block diagram of a data acquisition and processing System and method for acquiring and processing full elastic waveform data from a vertical-force source using sub-surface sensors, according to an exemplary embodiment.
FIG. 19 Is a block diagram of a data processing System for processlng full elastic wavefield data, according to an exemplary embodiment.
FIG. 20 Is a flow diagram Illustrating a method of processlng full elastic wave data, according to an exemplary embodiment.
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FIG. 21 Is a raypath diagram illustrating a comparison of P-P and SV-P imaging of subsurface geology, according to an exemplary embodiment.
FIG. 22 is a raypath diagram illustrating an approach direction of upgoing P-P and SV-P raypaths at a receiver station when the top Earth layer is low-velocity unconsolidated sédiment, according to exemplary embodiment
FIG. 23 Is a raypath diagram showing prindples of SV-SV and SV-P imaging, according to an exemplary embodiment.
FIG. 24 Is a raypath diagram showing approach diredion of upgoing P and SV raypaths at a receiver stations when the top Earth layer is hlgh-velocity rock, according to an exemplary embodiment.
FIG. 25 Is a raypath diagram Illustrating a comparison of P-SV and SV-P raypaths, according to an exemplary embodiment.
FIG. 26 is a diagram illustrating size and position of SV-P image space for two 3D Pwave data-acquisition geometries, according to an exemplary embodiment.
FIG. 271s a diagram of a subsurface geology Illustrating positive-offset and negative-offset domains for SV-P data and Fades A and B causing different velodtîes, according to an exemplary embodiment.
FIGs. 28A and 28B are examples of SV-P primary and multiple refiedlons extracted from vertical-geophone P-wave seismic data, according to an exemplary embodiment.
FIG. 29 Is a diagram illustrating SV-P and P-SV CCP Imaging prindples, according to an exemplary embodiment.
FIG. 30 Is a diagram and table Illustrating prestack migration, according to an exemplary embodiment.
FIG. 31 is a tabulation of some similarities and différences between SV-P and P-SV data, according to an exemplary embodiment.
FIG. 32 Is a block diagram of a data processing System for processlng shear wave data from a vertical sensor, according to an exemplary embodiment.
FIG. 33 Is a block diagram of a data acquisition and processing System and method for acqulring and processing shear wave data from a vertical-force source using surfacebased sensors, according to an exemplary embodiment.
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FIG. 34 Is a flow diagram Iliustrating a method of processing shear wave data from a vertical recelver in a situation involving a low-velodty Earth surface, according to an exemplary embodiment.
FIG. 35 Is a flow diagram iliustrating a method of processing shear wave data from a 5 vertical recelver in a situation involving a high-veiodty Earth surface, according to an exemplary embodiment.
FIG. 36 Is a diagram of approach angles of P waves to a vertical geophone, according to an exemplary embodiment.
FIG. 37 Is a diagram of approach angles of SV waves to a vertical geophone, according to an exemplary embodiment.
DETAILED DESCRIPTION OF EXEMPLARY EMBODIMENTS
One or more embodiments described herein may provide a method by which full elastic-wavefield selsmic data (P, SV and SH modes) can be acquîred and processed using only one source, a vertical-force source. The embodiments may be simpler and lower-cost is than using three orthogonal-force sources. The embodiments may be used in oll and gas exploration and exploitation, or any other activity where selsmic reflection data are widely used. The embodiments may remove numerous technical, environmentai, and cost barrière that limit applications of full elastic-wavefield seismlc data.
One or more embodiments described herein may involve departures from conventional seismlc data processing strategy.
One or more embodiments described herein may reduce the cost of acquiring complété elastic-wavefield seismlc data. The daily rate for utilizing a single vertical-force source Is less than the rates of deploying both a vertical-force source and a horizontal-force source to acquire équivalent data. Further, data may be acquîred quicker by deploying a 25 single source at each source station to create full elastic-wavefield data rather than deploying a vertical-force source and a horizontal-force source. The longer a contracter works to acquire data, the greater the cost of the data.
One or more embodiments described herein may provide the ability to acquire elastic-wavefield seismlc data across a wider range of surface conditions, such as swamps, 30 marshes, rugged mountain terrain, dense timber, and agricultural régions. Vertical-force sources can operate in a wide variety of surface terrains. For example, shot h oie explosives can be used in swamps, marshes, heavy timber, or rugged mountains, ail of which are
-517041 places horizontal sources cannot be deployed at ail, or at great cost because of site préparations. Vertical vibrators can be deployed in high-culture and resldential areas without causlng physical damage to buildings and Infra-structure.
One or more embodiments described herein may provide a wider choice of seismic sources. There Is a limited choice of horizontal-force seismic sources - such as heavy, horizontal vibrators or Inclined-lmpact sources. The total number of horizontal vibrators across the worid Is small. The number of inclined-lmpact sources is less. More of each type of source could be manufactured If demand appears. In contrast, there are hundreds of vertical-force sources. The dominating classes of vertlcal-force sources are vertical vibrators (hundreds around the worid) and shot hole explosives (avaîlable anywhere).
Verti cal-impact sources are few, but they too can be manufactured In mass if a market is created. For vertical seismic profile (VSP) data acquisition in remote areas (for example équatorial jungles), an air gun fired In a mud pit would be a vertical-force source. One or more embodiments described herein may allow geoscientists to select from a large menu of 15 vertical-force sources: vertical vibrators, shot-hole explosives, verticai-impactors, or mud pit air guns.
Wave Components
Referring to FIG. 1, a full-elastic, multicomponent seismic wavefield propagating In a simple homogenous Earth Is illustrated. Three Independent, vector-based, seismic wave 20 modes propagate in the Earth: a compressional mode, P, and two shear modes, SV and SH (Fig. 1 ). Each mode travels through the Earth at a different velocity, and each mode distorts the Earth In a different direction as it propagates. Doubie-headed arrows 102 are particledisplacement vectors Indicating the direction in which each mode displaces the Earth. Arrows 104 illustrate a direction of wave propagation. Acquisition of the multicomponent 25 modes results In full elastlc-wavefield data. The orientations of the P, SV, and SH displacement vectors relative to the propagation direction of each mode are illustrated in Figure 1.
The propagation veiocities of the SH and SV shear modes may differ by only a few percent, but both shear veiocities (V$) are slgnificantly less than the P-wave velocity (VP).
The velocity ratio Vp/Vs can vary by an order of magnitude In Earth media, from a value of or more in deep-water, unconsolidated, near-seafloor sédiment to a value of 1.5 in a few dense, well-consolidated rocks.
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Refera ng to FIG. 2, an exemplary distinction between SH and SV shear modes ls illustrated. SH and SV shear modes may be distingulshed by imaglning a vertical plane passing through a source station A and a receiver station B. SV vector displacement occurs in this vertical plane, as indicated at arrow 202; SH vector displacement is normal to the plane, as indicated at arrow 204. This vertical plane passing through the coordinates of a source station A, a receiver station B, and a reflection point C or D produced by that sourcereceiver pair may be called a sagittal plane or propagation plane.
Horlzontal-Force Sources and SH/SV Illumination
Referring to FIG. 3, a map viewof theoretical SH and SV radiation patterns produced by orthogonal horizontal-displacement sources 302, 304 will be described. Mathematical expressions that describe the geometrical shape of P, SV, and SH radiation patterns produced by seismlc sources in an isotropie Earth are described by White (1983). Viewed from directly above the horizontal-displacement source, SV and SH modes propagate away from the source stations 302, 304 as expanding drcles or ellipses. To simplify the graphie description, the patterns will be shown as drcles. Because SV radiation from a horizontal-displacement source 302, 304 is more energetic than SH radiation, SV radiation drcles are drawn larger than SH radiation cirdes. These drcles indicate which parts of the image space each mode affects and the magnitude of the mode illumination that reaches each Image coordïnate. The relative slzes of these drdes are qualitative and are not intended to be accurate in a quantitative sense.
A horizontal source-displacement vector 306 oriented in the Y direction (left slde of figure) causes SV modes to radiate in the +Y and -Y directions and SH modes to propagate in the +X and -X directions. A horizontal source-displacement vector 310 oriented In the X direction (right side of figure) causes SV modes to radiate In the +X and -X directions and SH modes to propagate in the +Y and -Y directions. If a line is drawn from the source station 302, 304 to Intersect one of these radiation drcles, the distance to the intersection point indicates the magnitude of that particular mode displacement in the azimuth direction of that line. The orientation of the particle-displacement vectors 308 and 312 remains constant across the image space, but the magnitude of the SH and SV partidedisplacement vectors vary with azimuth as shown by the SH and SV radiation drcles on FIG. 3.
Referring to FIG. 4, velocity behavior of SH and SV modes propagating through a layered Earth hâve been described by Levin, F., 1979, Selsmic velocities in transversely
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Isotropie media I: Geophysics, 44,918-936 and Levin, F., 1980, Seismic velocities in transversely Isotropie media II: Geophysics, 45, 3-17. The layered Earth Is horizontally layered, vertical transverse isotropie (VTI) media. Note that at ail take-off angles (except angle 402) SV and SH propagate with different velocities, with SH having a significantly 5 faster velodty at shallow take-off angles (such as angle 404) from a source station 406.
This wave physics will be useful when examining seismic test data described later.
Vertlcal-Force Sources and Dlrect-S Illumination
One type of source used In onshore seismic data acquisition applies a vertical displacement force to the Earth. Among these vertical-force sources are vertical weight 10 droppers and thumpers, explosives In a shot hole, and vertical vibrators. Such sources are traditionally vlewed as only P-wave sources, but they also produce robust S wavefields.
Referring to FIG. 5, an Illustration of a theoretical calculation, In cross-sectional views, Is presented to lllustrate how energy Is distributed between P-wave and SV-shear mode radiation patterns when a vertical force is applied to an elastic half-space 502 from a 15 vertical force source or vertical displacement source. See Miller, G., and H. Pursey, 1954,
The field and radiation impédance of mechanical radiators on the free surface of a semlInfinite isotropie solid: Proc. Royal Soc. London, Sériés A, v. 223, p. 521-541 and White, J. E., 1983, Underground sound—applications of seismic waves: Elsevier Science Publishers. Calculations are shown for two different values of the Poisson’s ratio of the Earth layer, with 20 the first Image 500 representing a Poisson’s ratio of 0.44 and the second Image 502 representing a Poisson’s ratio of 0.33. This analysis focuses only on body waves and Ignores horizontally traveling energy along the Earth-air Interface. The semi-circles Indicate the relative strength of the radiation. Radial fines define the take-off angle relative to vertical. In each model, more SV energy is generated than P energy.
The calculation of FIG. 5 shows that a vertical-force source 504 produces more SV energy 506 than P energy 508, and that at take-off angles of 20-degrees and more thls direct-SV mode is significantly stronger than the P mode. Thls particular SV radiation may not resuit In a robust Illumination of geology directly below the source station; whereas, Its companlon P radiation does. In order to take advantage of the direct-SV mode produced by 30 vertical displacement onshore sources, two features can be Implemented In data acquisition
Systems. First, three component (3C) geophones are used rather than singie-component geophones. Second, longer recording times are used to accommodate the slower propagation velocity of the downgoing and upgoing direct-SV mode. For example, P-wave
-817041 recording times of four seconds to six seconds may be extended to at least eight seconds or at least 12 seconds. Recording times for large offsets between source and receiver may be at least three times or at least four times the vertical travel time to the deepest target of Interest. Modem seismic data acquisition Systems can accommodate the long data6 acquisition times required to Image deep targets at far-offset receiver stations. A processing circuit within the data acquisition System may be configured to control the geophones or other receîvers or sensors to listen or record received seismic data for at least a minimum recording time.
A definitive way to ïllustrate the P and direct-SV radiation produced by a vertïcalio displacement source Is to analyze Its downgolng wavefield using vertical seismic profile (VSP) data. One example of VSP data acquired In the Delaware Basin of New Mexico with a vertical vibrator used as a source is provided as FIG. 7A. The downgolng mode labeled SV Is not a tube wave because It propagates with a velocity of approxlmately 2400 m/s (8000 ft/s), which Is almost twlce the velocity of a fluid-bome tube wave. The downgolng P 15 and SV lllumlnating wavelets produced immediately at the point where this vibrator applies a vertical force to the Earth surface are labeled and extended back to the surface source station 700 to ïllustrate that an SV mode Is produced directly at the source. The absence of data coverage across the shailowest 3000 ft of strata leaves some doubt as to where downgolng event SV Is created, so a second example of VSP data produced by a vertical 20 vibrator in a South Texas well is iîîustrated on FIG. 7B. Again this vertical-displacement source créâtes a robust direct-SV wavefield in addition to the customary P wavefield. In this example, the downgolng SV mode can be extended back to the source station at the Earth surface with confidence. In the case of FIG. 7B, the source was offset only 100 ft from the VSP well. The top diagram shows a vertical geophone response. The bottom diagram 25 shows the response of a horizontal geophone.
The VSP data examples of FIGs. 7A and 7B show that a vertical vibrator is an efficient producer of direct-SV radiation and créâtes an SV-SV mode that can be utilized. An explosive shot also applies a vertical-displacement force to the Earth and generates a direct-SV mode.
The SV mode exhibited by the data In FIGS. 7A and 7B Is produced at the same
Earth coordinate as the P mode and is a source-generated direct-SV wave. The propagation medium at this location has unusually low VP and V$ velocities. The SV mode produces a large population of upgoing SV reflections that are observable In these raw, unprocessed data.
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The term “SV is used above to describe the S-wave radiation. However, as will be seen below, the term “SV should be replaced with the broader term S, meaning the radiated S-wave energy is both SV and SH when the radiation is considered in a 3D context rather than as a single vertical profile.
To illustrate the principle that S-wave radiation produced by a vertical-force source consists of both SV and SH modes, the pattern displayed on the right of FIG. 5 Is converted to a 3D object and displayed as FIGS. 6A and 6B. For ease of understanding, the 3D radiation pattern is simplified to contain only the major S lobe 512, 514 shown in FiG. 5. Both the P-wave component 516 and the smaller secondary S lobe 518 seen on FiG. 5 are omitted. The solid is further altered by removing a 90-degree section 602 to aliow better viewing of the 3D geometry by which S energy spreads away from the vertical-force source station VFS.
in FiG. 6A, SV and SH planes and displacement vectors are shown relative to a receiver station RA. In FiG. 6B, SV and SH planes and displacement vectors are drawn relative to a receiver station Rb. These two arbitrary receiver stations RAand Rb, separated by an azimuth of 90 degrees, are positioned on the Earth surface around a station VFS where a vertical-force source is deployed. Oblique views and map views are shown of a vertical plane passing through the source station and each receiver station. As discussed for FIG. 2, this source-receiver plane is the SV plane for each receiver station. For each receiver, an SH plane is also shown perpendicular to each SV plane. The SH plane for receiver Ra is the SV plane for receiver Re, and Inversely, the SH plane for receiver Rb Is the SV plane for receiver RA. Regardless of where a receiver station is positioned in azimuth space away from a vertical-force station, both SV and SH modes wili propagate to that station. SH shear Information Is available as is SV shear information when verticalforce source data are acquired.
Fleld Test
The Exploration Geophysics Laboratory (EGL) at the Bureau of Economie Geology initiated a field-test program to quantify the geometrical shapes and relative strengths of compressional (P)-wave and shear (S)-wave modes produced by a variety of seismic sources. The first test program was done at the Devine Test Site owned by The University of Texas at Austin and managed by EGL researchers. Sources deployed tor this initial test were: 1-kg package of explosive positioned at a depth of 20 ft, a horizontal vibrator, a
-1017041 vertical vibrator, and an accelerated-weight that Impacted the Earth verticatly and at Inclined angles.
Source-Receiver Geometry
Referring to FIG. 8, an Illustration of the source-receiver geometry is shown. The source-receiver geometry used to evaluate P and S source radiation patterns combined the concepts of horizontal wave testing (involving onty a horizontal receiver array) and vertical wave testing (involving only a vertical receiver array) as described by Hardage, B.A., 2009, Horizontal wave testing: AAPG Explorer, v. 30, no. 12, p. 26-27 and Hardage, B.A. 2010, Vertical wave testing: AAPG Explorer, v. 31, no. 1, p. 32-33. A 24-station vertical array of three-component geophones was deptoyed ln a selected test well, with receiver stations spanning a depth Interval extending from 500 to 1632 ft (Fig. 8). Three-component (3C) geophones are configured to acqulre ail three dimensions of a full elastic wave. Several 25station horizontal arrays of 3C sensors spaced 10 ft apart spanned the offset range 0 to 250 ft immediately next to the receiver well. Source stations were offset from the well at Intervals of 250 ft, the linear dimension of the horizontal surface-recelver arrays.
Vertical Aperture
Referring to FIG. 9, an approximation of the aperture range created by the sourcereceiver geometry Is shown. Downgoing P and S modes were recorded over a wide aperture of vertical takeoff angles (14 degrees to 81 degrees In this example) from the surface source stations to define the geometrical shape of P and S radiation patterns in section view. The shallowest takeoff angle involved data generated at source station 9 (offset 1920 ft) and recorded at downhole receiver station 24 (depth of 500 ft). The steepest takeoff angle involved source station 2 (offset 250 ft) and downhole receiver station 1 (depth of 1632 ft). A fîrst approximation of the aperture range created by the source-receiver geometry can be created by assumlng stralght raypaths from source to downhole receiver, which yietds the resuit shown in FIG. 9. ln actual wave propagation, raypaths are curved as dictated by refractions at Interfaces between velocity layers. Raypaths refract (bend) when they advance from an Earth layer having velocity V1 Into a layer having velocity V2. Raypath curvature can be calculated if velocity layering is known. Stralght raypath assumptlons are used to explain the prindples described with référencé to FIG. 9.
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Transformlng VSP Data to Wave-Mode Data ln a vertical well, azimuth orientations of X,Y horizontal geophones deployed by twisted-wire cable differ at each downhole station because of receiver-module spin. As a resuit, phase shifts and amplitude variations introduced into data by station-to-station variations in receiver orientation do not allow Individual events or distinct wave modes to be recognized, particularty S-wave events that tend to dominate horizon tal-sensor responses. In this case, receivers are mathematically oriented to spécifie azimuths and inclinations to define downgoing and upgoing P and S modes.
Referring to FIG. 10, a graphical description ofthe transformation of receivers from X, Y, Z data space to P, SV, SH data space Is shown. Transformations of borehole receivers from ln situ X, Y, Z orientations to a data space where receivers are oriented to emphasize P, SV, and SH events hâve been practiced in vertical seismlc profilîng (VSP) technology. DiSiena, J.P., Gaiser, J.E., and Corrigan, D., 1981, Three-component vertical seismic profiles - orientation of horizontal components for shear wave analysis: Tech. Paper S5.4, p. 1990-2011, 51rt Annual Meeting of Society of Exploration Geophysicists. Hardage, B.A., 1983, Vertical seismic profilîng. Part A, prindples: Geophysical Press, 450 pages (The VSP Polarization Method for Locating Reflectors, pages 307 - 315). Examples of this receiver orientation procedure applied to vertical-lmpact, shot-hole explosive, and vertical-vibrator sources at selected source stations are illustrated on FIGs. 11,12, and 13, respectively. Data Windows spanning 100 ms immediately following the onset of interpreted P-wave direct arrivais were used to détermine azimuth and inclination angles 6 and Φ (FIG.10) at each receiver station
Figure 10 illustrâtes a 2-step rotation of coordinate axes to détermine directional angles from a subsurface receiver to a surface-positioned seismic source. When a 3component sensor is lowered several hundreds of feet down a well, the azimuth orientations of horizontal sensors are not known because the receiver package rotâtes on the twisted wire cable used for deployment. As a conséquence, P, SH, and SV modes are intermingled on each sensor response because sensors are not oriented in the directions of P, SV, and SH partide dispiacements. Therefore, each subsurface receiver is mathematically oriented so that one sensor points directly along the raypath ofthe downward traveling P wave from a surface source. Once such rotation Is done, the sensor pointing at the source is dominated by P data, the second sensor in the same vertical plane as the P sensor (this vertical plane passes through the source and receiver stations) is dominated by SV, and the third sensor (perpendlcular to this vertical plane) is dominated by SH. Two angles - a
-1217041 horizontal rotation angle Θ and a vertical rotation angle Φ - hâve to be determined to achieve this sensor orientation.
To détermine horizontal azimuth angle Θ (Fig. 10), data are analyzed In a short time wlndow spanning only the downgoing P-wave first arrivai from the source. Only responses of the two horizontal sensors X and Y are analyzed in this first rotation step. Data acquîred by sensors X and Y are mathematically transformed to responses that would be observed if these two orthogonal sensors were rotated to new coordinate axes that are successively Incremented by one-degree of azimuth. This rotation is done 180 times to croate sensor responses that allow the sensor axes to point over an azimuth range of 180 degrees from the unknown azimuth In which the sensors actually point. When sensor X Is positioned In the vertical plane passing through the recelver and the source, the response of the X sensor will be a maximum, and the response ofthe Ysensorwill be a minimum. When this maximum-X and minlmum-Y response is found, the angle between the in situ sensor axes and the desired rotated axes that isolate P, SV, and SH wave modes is Θ.
To détermine inclination angle Φ (Fig. 10), the sensor responses after transforming the data to coordinate axes oriented In azimuth Θ are then analyzed in the short data wlndow spanning only the downgoing P-wave first arrivai, as defined In this new datacoordinate space. Data from only sensor Z (vertical) and from the new X sensor that has been rotated into the vertical source-recelver plane are used in this second rotation, in this second axis rotation, these two sensor responses are mathematically transformed to responses that would be observed if these two sensors were tiited In successive Inclinations of one degree of tilt over a tilt range of 90 degrees. When the Z recelver is pointing in the direction of the Incoming P-wave first arrivai, its response will be a maximum, and the companion sensor In the same vertical plane (the new rotated and tiited X sensor) response will be a minimum. When this condition is found, angle Φ has been defined.
Data transformed to this second coordinate System defined by an azimuth rotation of Θ and an inclination angle of Φ hâve optimal séparation of P, SV, and SH modes, with P, SV, and SH being the dominant data on the rotated and tiited Z, X, and Y sensors, respectively.
Refemng to FIG. 11, charts 1100,1102 and 1104 illustrate X, Y, Z data acquîred at the Devine Test Site with the vertical receiver array when a vertical-impact source was positioned at source station 9, offset 1920 fi from the receiver array. Charts 1106,1108 and 1110 Illustrate the same data rotated to P, SV, SH data space. No P or SV events appear
-1317041 on the SH data panel. Because SH dîsplacement Is orthogonal to both P and SV displacements, the absence of P and SV events defines SH data. SV events appearing on the P data panel such as the event shown at 1112 are downgoing P-to-SV conversions. Downgoing P-to-SV conversions are caused only by non-normal Incidence of a P wave on an Impédance contrast interface. P and SV modes exchange energy freeiy when reflecting and refracting at interfaces because the displacement vectors of these two modes are in the same vertical plane. Nelther P nor SV can convert energy to SH, and conversely SH can not convert into P or SV, because SH dîsplacement is orthogonal to the vertical plane in which P and SV propagate. To confirm that a data panel is an SH mode, we search for evidence of P and SV events embedded in the data panel. If no P or SV events can be identified, the mode is pure SH, by définition. Note at shallow take-off angles (top 4 or 5 recelver stations), SH waves travel fasterthan SV waves as predicted by Levin (1979, 1980), supra, and measured by Robertson, J.D. and D. Corrigan, 1983, Radiation patterns of a shear-wave vibrator in near-surface shale: Geophysics, 48,19-26.
SV waves produced directly at the source means SV waves are generated exactly at the point where a vertical force Is applied to the Earth. There does not hâve to be an impedance-contrast Interface close to the source to cause SV to corne into existence. SV will propagate away from a vertical-force source even in a thlck, homogeneous medium in which there are no interfaces.
In contrast, P-to-SV conversions occur only at interfaces where there is an Impédance contrast. Any time a P-wave arrives at an interface at any Incident angle other than 0 degrees (normal to the Interface), some ofthe llluminating P energy converts Into reflected and refracted P, and some converts into reflected and refracted SV. Thus P-to-SV conversion occurs at Interface coordinates remote from a source, not directly at the source point. A converted SV mode requires two conditions be présent: 1) an interface across which there is a contrast In acoustic impédance, and 2) a P-wave raypath arriving atthat Interface at an angle that is not normal to the interface. When the incident angle Is 0 degrees (raypath perpendicularto the Interface), the P-to-SV reflection coefficient Is zéro. At other Incident angles, the P-SV reflection coefficient is non-zero.
Referring to FIG. 12, charts 1200,1202 and 1204 lllustrate actual X, Y, Z data acquired at the Devine Test Site with the vertical receiver array when a shot-hole explosive source was positioned at source station 5, offset 1250 ft from the array. Charts 1206,1208 and 1210 lllustrate the same data rotated to P, SV, SH data space. No P or SV events appear on the SH data panel. SV events appearing on the P data panel are weaker than Is -1417041 the case for a vertical-impact source, perhaps due to more accurate receiver rotations. Note at shallow take-off angles (top 4 or 5 receiver stations), SH waves travel faster than SV waves as predicted by Levin (1979,1980), supra, and measured by Roberson and Corrigan (1983), supra.
Referring to FIG. 13, charts 1300,1302 and 1304 ilîustrate actual X, Y, Z data acquired at the Devine Test Site with the vertical receiver array when a verticai-vibrator source was positioned at source station 6, offset 1500 ft from the array. Charts 1206,1208 and 1210 ilîustrate the same data rotated to P, SV, SH data space. No P or SV events appear on the SH data panel. Measurements made at shallow take-off angles hâve larger io amplitudes than measurements made with vertical-impact and explosive sources (FIGs. 11 and 12).
A constant plot gain Is applied to each data panel on each of FIGs. 11-13. Thus, within Individual figures, P, SV, and SH amplitudes can be compared visually to judge relative energy levels of P and S modes. Such comparisons confirm SV and SH modes 15 radiating away from a vertical-force source hâve amplitudes greater than the associated P mode. Data-display gains differ for each source, so P and S amplitudes produced by explosives should not be visually compared with P and S amplitudes produced by verticalimpact or verticai-vibrator sources.
According to theory, SH data do not convert to either P or SV modes as an elastic 2o wavefield propagates through a layered Earth, and conversely, P and SV modes do not convert to SH modes. No SH data panel contains P or SV events, which Indicate the wavefield séparations displayed on FIGs. 11 through 13 are properly done. Theory also establishes energy Is freely exchanged between P and SV modes as they propagate through layered media. Ail SV data panels on Figures 11-13 show P-to-SV conversion 25 events 1114,1214, and 1314, which again indicate correct wave physics. Although minor amounts of SV energy remain on the P data panels, we consider our wave-mode séparation to be sufficiently accurate to establish the fundamental principle that both SH and SV shear modes are produced by a vertical-force source In addition to the expected P-wave mode.
Another plece of evidence confirming the two S modes shown on FIGs. 11 to 13 are 30 SV and SH is the fact the wavefront labeled SH traveis faster at shallow (near horizontal) takeoff angles than does the wavefront labeled SV. This distinction In SH and SV velocity behavior is emphasized by the theory documented by Levin (FIG. 4). The différences in SH
-1517041 and SV velodties Is best seen by comparing the arrivai times of S wavefronts on FIGs. 11 and 12 at shallow receivers positioned over the depth interval 500 to 700 ft.
Data Processing
There is a différence between S-wave source displacement vectors produced by vertical-force sources and conventional horizontal-force sources. The S-wave displacement applied to the Earth by a horizontal-force source Is shown on Figure 3. That displacement Is oriented In a fîxed azimuth direction (e.g., Indicated by arrow 306), and Earth displacements around the point of application all point In the same direction (e.g., as Indicated by arrows 308) as the direction of the applied force. In contrast, the S displacement created by a vertical-force source points In every azimuth direction around Its point of application, and the corresponding Earth displacement vectors likewise point In all azimuth directions away from the source station (see FIG. 6). The effect seen in seismlc reflection data Is that S-wave data produced by a dipole source (FIG. 3) hâve the same polarity In every azimuth quadrant surrounding a source station, but S-wave data produced by a vertical-force source hâve different polarities when vlewed In azimuth directions that differ by 180 degrees.
S-wave data-processing strategies a cross the seismlc Industry are based on the assumption that data polarities are constant across the entirety of seismlc Image space. Thus the polarities of S-wave data acquired with a vertical-force source can be adjusted to look like constant-polarity data produced by a dipole source via a data-polarity adjustment.
Referring to FIG. 14, a process of data-polarity adjustment will be described. FIG. 14 shows a map view of a vertical-force source station VFS positioned In a 3D seismlc dataacqulsition grid 1400. In seismlc pariance, the direction receiver lines are deployed Is called “inline, and the direction source lines are oriented Is called “crossline. In most 3D seismlc data-acquisition designs, Inline and crossline directions are perpendicular to each other.
The azimuth direction of positive polarity in crossline and Inline directions Is arbltrary. However, once a data processor selects certain Inline and crossline directions as being positive polarities, he/she has automatically divided Inline and crossline seismic image space around a vertical-force source station Into two polarity domains - a positive-poiarity domain and a negative-polarity domain. FIG. 14 illustrâtes the principle of data-polarity reversais applied to vertical-force source data to croate constant-polarity S-wave data across seismic Image space. An exemplary 3D seismic data-acqulsition geometry called orthogonal geometry Is shown In which source line and receiver lines are orthogonal to each
-1617041 other. VFS is a vertical-force station on one source line. A positive-polarity direction Is selected (arbitrarily) for both the crossline (source line) direction and the inline (receïver line) direction. This decision divides seismlc Image space into two domains - a positive-polarity domain and a negative-polarity domain.
A real-data example of this data-polarity principle 1s Illustrated In FIGs. 15 and 16.
These 3D selsmic data were acquired using a vertical vibrator. The data-acquisitïon grid is shown between each pair of data panels to define the position of a fixed source station and various receïver stations where data produced by this vertical-force source were recorded. The positive inline (IL) and crossline (XL) directions assigned to the grid are Indicated at 10 each receïver station. The wiggle trace displays on the left show the polarities of the recorded data. Wiggle trace displays on the right show the data after polarity reversais hâve been applied as described in FIG. 14. After these polarity fiips, ali data hâve consistent polarity across the entirety of selsmic Image space and can be processed by standard selsmic software.
The data processing for SV and SH wave modes produced directly at the point of application of a vertical-force source diffère from that of processing converted-SV data. With direct-source data, data poiarities are revereed in the negative-offset domain, and once this data-polarity correction Is done, data In the two offset domains are processed as a single data set, not as two separate data sets. Direct-source S-wave data can be processed with common-midpoint (CMP) strategies; whereas, P-SV data are processed with common-convereion-point (CCP) strategies. Velocity analyses of data are done differently in these two data-processing domains - common midpoint versus common conversion point.
FIG. 15 Illustrâtes a first example of polarities of vertical-force seismic data recorded 25 In azimuth directions that differ by 180 degrees away from a source station (left). On the right, FiG. 15 illustrâtes the resuit of revereing polarities in the negative-polarity domain to convert vertical-force source data to constant-polarity dipole-source data.
FIG. 16 Illustrâtes a second example of polarities of vertical-force seismic data recorded In azimuth directions that differ by 180 degrees away from a source station (left).
On the right, FIG. 16 illustrâtes the resuit of revereing polarities In the negative-polarity domain to convert vertical-force source data to constant-polarity dipole-source data.
Although vertical-force source data do not produce the same S-wave data polarities as conventional horizontal-force sources, data polarity reversais, corrections, inversions or
-1717041 adjustments In appropriate portions of seismic image space transfonm vertical-force polarities to horizontal-force polarities. After these polarity adjustments, vertical-force source data can be processed just as horizontal-force source data are, using known algorithme.
Flndlngs
The EGL test data show that vertical-force sources, commonly perceived as P-wave sources, generate more S energy directly at the force application point than they do P energy. In one embodiment, the S energy is generated directly at the force application point of the source, rather than through applications of P-to-SV mode conversions at sub-surface interfaces.
In addition, fieid tests show vertical-force sources produce a high-energy, high-quality SH mode directly at the source station in addition to an SV mode. This statement Is confirmed by.
• The mode claimed to be SH produces an Earth displacement normal to the SV mode, and • Has a velocity greater than the SV mode at shallow takeoff angles.
Thus, the EGL source test program évidences that full-elastic-wavefield data (P, SV, SH) can be acquired using vertical-force sources.
The existence of SV mode data directly at the source station can be contrasted with SV data which is converted at impedance-contrast Interfaces in the Earth from P to SV mode by some layers of media below the Earth’s surface, which can be referred to as near the source. There are only two ways to generate an SV shear mode: 1) use a source that produces an SV displacement directly at the source station, or 2) use a source that generates a robust P wave and utilize the converted SV modes that P wave produces when It illuminâtes an interface at any Incident angle other than 0 degrees.
As explalned above, SH data are observed In data produced by the three general types of vertical-force sources (vertical vibrator, vertical impact, shot hole explosive), which means an SH displacement occurs directly at the point where a vertical-force source applies its force vector to the Earth.
Data Acquisition and Processing
Referring nowto FIG. 17, a diagram of a data acquisition and processing System 1700 and method for acquiring and processing full elastic waveform data from a vertical-force source using surface-based sensors will be described. A vertical-force seismic source 1702 -I817041 is disposed on, near, or within a shallow recess of the Earth’s surface 1704. Source 1702 is configured to impart a vertical-force to surface 1704 to provide seismic waves into Earth media 1706. Source 1702 may comprise a vertical vibrator, shot-hole explosive, verticalimpactor, air gun, vertical weight-dropper or thumper, and/or other vertical-force sources. In this example, vertical-force source 1702 produces compressional P mode and both fondamental shear modes (SH and SV) in Earth 1706 directly at a point of application 1708 of the vertical-force source. In this embodiment, at least some of the SH and SV shear waves are generated at source 1702 and not by subsurface conversion caused by portions of Earth media 1706. The frequency waves may be provided In a frequency sweep or a single broadband Impulse. A vertical-force source may be used without any horizontal-force sources.
A seismic sensor 1710 is along the Earth’s surface, which may include being disposed on, near, or within a recess of the Earth’s surface 1704. For example, in one embodiment, shallow holes may be drilled and sensors 1710 deployed in the holes to avoid wind noise, noise produced by rain showers, etc. Sensor 1710 ls configured to detect or sense upgoing wave modes, reflected from subsurface sectors, formations, targets of Interest, etc. In this embodiment, sensor 1710 comprises a muiti-component geophone, for exemple a threecomponent geophone configured to sense compressional P mode and both fondamental shear modes (SH and SV). As described In FIGs. 1-14, various arrays and configurations of sources 1702 and sensors 1710 may be Implemented in different embodiments. For example, two-dimenslonal or three-dimensional acquisition templates may be deployed across Earth’s surface 1704. As another example, a plurality of sources 1702 (e.g., at least two, at least five, at least ten, etc.) may be disposed along a line and be configured to transmit seismic waves together or simultaneously. Vertical seismic profiling may be used In one embodiment. In an alternative embodiment, a reverse vertical seismic profiling arrangement may be used, in which one or more sources ls disposed in a hole or well and one or more 3-component sensors or receivers are disposed along the Earth's surface. In another alternative embodiment, an Interwell arrangement may be used, in which sources are disposed In one well or hole and 3-component receivers or sensors are disposed In another well or hole. An in-hole source may be a wall-locked mechanical vibrator in an aîrfiiled or fluid-filled weli, or an air gun, water gun, or high-energy piezo-ceramic transducer freely suspended In a fluid coiumn, or other source.
A seismic recording system 1712 ls configured to receive seismic data sensed by sensor(s) 1710 via a wired or wireiess communication link and to store the data In a
-1917041 database. System 1712 may comprise any type of computing device. System 1712 may be configured to acquire and/or process the received data. For example, processing may comprise polarity-reversai as previousiy described, the processing steps of FIG. 18 below, or other seismlc data processing algorithms.
A digital media output device 1714 may be coupled to System 1712, or data may be transferred to device 1714 from System 1712 using any of a variety of technologies, such as a wired or wîreless network, memory device, etc. Device 1714 may comprise one or more of a display device, a printer, a speaker, and/or other output devices.
According to one embodiment, System 1712 can be configured to acquire or capture SH-SH mode data with surface-based sensors. According to another embodiment, System 1712 can be configured to acquire both SV and SH mode data with surface-based sensors.
Referring now to FIG. 18, a diagram of a data acquisition and processing System 1800 and method for acquiring and processing fui! elastic waveform data from a vertical-force source using sub-surface sensors will be described. A vertical-force selsmic source 1802 is disposed on, near, or within a shallow recess of the Earth’s surface 1804. Source 1802 is configured to impart a vertical-force to surface 1804 to provide seismic waves into Earth media 1806. In this example, vertical-force source 1802 produces compresslonal P mode and both fundamental shear modes (SH and SV) In Earth 1806 directly at a point of application 1808 of the vertical-force source. In this embodiment, at least some of the SH and SV shear waves are generated at source 1802 and not by subsurface conversion caused by portions of Earth media 1806. Contamination of S data produced directly at a source station by converted-SV data produced at interfaces remote from the source station may occur. A data processing System may be configured to résolve, remove, reduce or Identify this converted-SV data (and/or other noise modes, such as P events, P and S multiples, reverberating surface waves, wind noise, etc.) and to emphaslze, amplify, or identify the target signal.
A plurality of seismic sensors 1810 are disposed at a plurality of locations within each of one or more shallow or deep holes drilled at any déviation angle. Sensors 1810 may be deployed permanently (e.g., by cementing or otherwise securing them in place) or they may be retrievable via wireiine or coil tubing. Sensors 1810 are configured to detect or sense upgoing wave modes, reflected from subsurface sectors, formations, targets of interest, etc. In this embodiment, sensors 1810 each comprise at least one multi-component geophone, for exampie a three-component geophone configured to sense compresslonal P mode and
-2017041 both fundamental shear modes (SH and SV). As described In FIGs. 1-14, various arrays and configurations of sources 1802 and sensors 1812 may be implemented In different embodiments.
Sensor deployment equipment and seismic recording System 1812 may be configured to position sensors 1810 within hole 1809, provide power to sensors 1810, and provide other functions needed to depioy sensors 1810. System 1812 comprises a computing System configured to reçoive seismic data sensed by sensors 1810 via a wired or wireless communication link 1813 and to store the data in a database. System 1812 may be configured to acquire and/or process the received data. For example, processing may to comprise polarity-reversal as previously described, the processing steps of FIG. 18 below, or other seismic data processing algorithms.
A digital media 1815 may be coupled to System 1812 using any of a variety of technologies, such as a wired or wireless network, etc. Media 1815 may be configured to store and transfer the sensed and/or processed to data to other computing devlces.
Referring now to FIG. 19, a data processing System for processing full eiastic wavefield data will be described. System 1900 comprises a digital computation System 1902, such as a personal computer, UNIX server, single workstation, hlgh-end cluster of workstations, or other computing System or Systems. System 1902 comprises sufficient processing power to process large quantifies of complex seismic data. A mass storage device 1904 or other memory is coupled to digital computation System 1902, which is configured to receive data from the field recorders or sensors stored on a digital media 1906, such as a memory card, hard drive, or other memory device. Mass storage device 1904 Is configured to download or receive the multi-component seismic data from digital media 1906 and to store the data in a database.
A user Interface 1908, such as a keyboard, display, touch screen display, speaker, microphone, and/or other user interface devices may be coupled to System 1902 for twoway communication between System 1902 and a user. According to one exemplary embodiment, multiple user terminais 1910 may access data processing System 1902 through a user Interface using a network of computers, terminais, or other input/output devlces (e.g., a wide-area network such as the Internet).
A software iibrary 1912 is coupled to data processing System 1902 and comprises one or more non-transitory computer-readable media programmed to perform one or more processing algorithms. The processing algorithms may comprise any of a number of known
-2117041 seismic data processing algorithms or algorithms described herein or which may be developed In the future. The algorithms can comprise algorithms In two categories: (1) algorithms required to process data acquired by surface-based 3-component sensors, and (2) algorithms required to process data acquired with 3-component sensors positioned In deep wells.
Surface-Based Sensors
For surface-based sensors, data computation System 1902 may be programmed with existing code, both proprietary code and public commercial code. System 1902 may be programmed with new code to optimize data handiing and Image construction. System 1902 may be programmed to extract P, SH, and SV modes from recorded data, as described herein with référencé to FIGS. 1-14.
Deep Well Sensors
When data are acquired with sensors in deep wells, the procedure is called vertical seismic profiling (VSP). VSP data-processing Systems are not as widely distributed as are Systems for processing surface-sensor data. VSP data may be processed using dataprocessing Systems made or used by VSP contractors, such as Schlumberger, Halliburton, Baker Atlas, READ, and/or other companies. The data processing Systems may be configured to extract P, SH, and SV modes from recorded data, by looking for SV and SH radiating directly from a surface source station.
System 1900 may further comprise one or more output devices 1914 coupled to digital computation system 1902. Output devices 1914 may comprise piotters, tape drives, dise drives, etc. configured to receive, store, display and/or présent processed data In a useful format.
Referring now to FIG. 20, a flow diagram illustratlng a method 2000 of processing full elastlc wave data will be described. The method may be opérable on one or more processing dreuits, such as digital computation system 2002. At a block 2002, a processing circuit Is provided with mlxed P, SH and SV modes In field-coordinate data space (inline and crossline) from acquisition steps described previously. At block 2004, the processing dreuit Is configured to or programmed to segregate, separate or otherwise remove P mode data by applylng velodty filters to reject or filter out SH and SV modes.
A velodty filter is any numerical procedure applied to seismic data that emphasizes events that propagate with a certain targeted velodty behavior and atténuâtes events that propagate with velodties different from this targeted velodty. There are numerous
-2217041 algorithme availabie to selsmlc data processors that perform velocity filtering. Some of these filters operate in the frequency-wavenumber (f-k) domain, some in the time-slowness (tau.p) domain, some are médian filters In the time-depth domain, etc. Velocity filters allow primary P reflections to be segregated from P multiples, and S events to be Isolated from P 5 events.
Converted SV events hâve a faster velocity than do direct-S events because a converted SV invoives a downgolng P wave; whereas, the downgoing raypath for a direct-S event Is S (much slower than P). Velocity filters can be designed that pass the slow veloaties associated with an S-S event (downgoing S and upgolng S) and reject the faster 10 veloaties of P-SV events (downgoing P and upgolng SV).
At a block 2006, the processing circuit is configured to reverse polaritles of inline and crossline horizontal-sensor data acqulred at négative offsets, as described above with référencé to FIGS. 10-14. At a block 2008, the processing circuit is configured to transform horizontal sensor data from Inline/crossline data space to radialAransverse data space, as 15 described above with référencé to FIGS. 10-14. As a resuit, the SH and SV modes (SH=transverse data; SV = radiai data) are segregated and proœssed separately.
At a block 2010, radial sensor data are set aside as an SV data base, and transverse sensor data are set aside as an SH data base. This ségrégation of SV and SH modes allows the modes to be Individually introduced (e.g., as separate data sets) into the data20 processing stream starting at block 2012.
At a biock 2012, any one of numerous velocity analysis procedures availabie In the seismic data-processing industry may be appiied to each wave mode, P, SV, and SH, separately. Popular velocity-analysis options are sembiance stacking, frequencywavenumber analysis, and time-slowness analysis. This step Identifies an optimal velocity 25 fonction for each wave mode that wiil emphasize primary reflection events for that wave mode and attenuate noise, interbed multiples, and spurious events from competing wave modes.
At a block 2014, static corrections are applied to Improve reflector alignment. These corrections invoive time shifts of data acqulred at each source and receiver station.
Because these time shifts are appiied to an entire data trace, they are termed static corrections to differentiate them from dynamic time adjustments done by other processes. One static correction removes timing différences caused by variations In station élévations by adjusting time-zero on each data trace to mathematically move ali source and receiver
-2317041 stations to a common datum plane. A second static correction removes timlng différences cause by different velocities being local to different source and receiver stations. The end resuit of these static corrections is an improvement In reflection continuity.
At a block 2016, any one of many noise rejection procedures may be applied to the data s to Improve the slgnal-to-nolse ratio. Some noise rejection options may be simple frequency filters. Others may be more sophlsticated tau-p, f-k, or deconvolution procedures.
At a block 2016, the data are stacked (or summed) to create an Initial Image. Embedded in this step is a dynamic time adjustment of reflection events called a moveout correction that is applied to flatter» reflection events to the same time coordinate at ail 10 source-receiver offsets. A data-acquisitïon geometry may cause many source-receiver pairs to produce reflection events at the same subsurface coordinate. In stacking, the fiattened reflections from ail source-receiver pairs that image the same subsurface coordinate are summed to make a single image trace at that image-space coordinate. When this stacking process is extended a cross the entire selsmic image space, a single 15 image trace with high signal-to-noise character is produced at each image point in the image space. It is at this step that a data processor gets his/her first look at the quality of the velocity analysis and static corrections that hâve been applied to the data (e.g., by display ng the data on an electronic display, printing the data using a printer, etc.).
At a block 2020, the data processor has to décidé if the image is satisfactory or if the 20 data processing should be repeated to improve the accuracy of the velocity analyses that perform the dynamic moveout corrections of reflection events and to improve the accuracies of the static corrections that time shift reflection events at each source and receiver station. If the decision is to repeat the Imaglng process, the procedure retums to block 2012 and proceeds to block 2020 again. If the Earth consists of fiat horizontal layers, these stacked 25 data are a good image of the subsurface geology. If Earth layers are dipping or faulted, these stacked data are not a true image of the geology, but they still Indicate the quality of the true image that will be created when the data are migrated (Block 2022).
At a block 2022, the data are migrated. Migration is a procedure that utilizes a seismicderived velocity model of the Earth to move reflection events from their coordinate positions 30 In offset-vs-time image space to their correct subsurface positions in the Earth. Numerous migration algorithme are availabie in the seismic data-processing industry. Some algorithms are proprietary to data-processing companles; others are availabie as commerdally leased software or as shared freeware.
-2417041
The position of the data migration step on Figure 20 is a post-stack migration procedure. The migration step can be moved to be positioned between blocks 2016 and 2018 to do pre-stack migration. Pre-stack migration is often more désirable than post-stack migration but Is more computer intensive. Both time migration and depth migration can be displayed so that the vertical coordinate axis of the image is either depth or time, depending on the data processor preference.
The teachlngs herein may be implemented by selsmlc contractors, oil and gas companîes, and others. The teachlngs herein may be used in other industries as well, such as geothermal energy, CO2 séquestration, etc.
Extant Data
The Systems and methods described herein may be applïed to processing of extant or pre-existing or legacy sets of seismic data. According to one example, a memory comprises selsmlc data which may be raw, unprocessed or partially processed. The seismic data may hâve been generated months or years prior to the processing of the data. A processing circuit may be configured to process the seismic data to generate, provide, or achieve full elastic waveform data. For example, the processing circuit may be configured to reverse polarities of horizontal sensor data acquîred at négative offsets as described herein to generate S mode data, such as SH mode and SV mode data. The processing circuit may further be configured to extract P, SH, and SV modes from the prevtously recorded data, ln one embodiment, the seismic sensors will hâve been receiving data for a suffident period of time, such as at least ten seconds or at least twelve seconds, in order to receive ail of the slower-moving SH and SV modes in addition to the P mode data.
According to one embodiment, sources other than explosive sources (I.e. non-explosive sources, such as vertical vibrators and vertlcal-lmpact sources) may be used to construct Smode images, such as SV and SH images. The advantages of non-explosive sources indude that they are acceptable sources in environments where explosive sources are prohibited or impractical. Exemplary advantages include:
• Explosives cannot be used ln urban environments. ln contrast, vibrators can operate down streets, alleys, and in dose proximlty to buildings.
• Explosives cannot be used along road right-of-ways. County roads and public highways are popular profile locations for vibrators.
ln areas contaminated by mechanical noise (road traffic, gas-line pumplng stations, oil well pump jacks, active drilling rigs, etc.), the compact Impulsive wavelet (typlcally -2517041 spanning only 100 to 200 ms) produced by an explosive shot can be overwhelmed by short noise bursts from noise sources local to one or more receiver stations. In contrast, a vibrator créâtes a wavelet by inserting a long (10 to 12 seconds) chirp Into the Earth in which frequencies vary with a known time dependence. Unless mechanical noise has exactly the same frequency variation over a 10-second or 12-second time duration as does a vibrator chirp signal, the cross corrélation procedure used to Identify vlbrosels reflection events suppresses the noise. Explosive sources are less practical than vibrators in high-noise environments.
Vertical Impact sources hâve appeal because they are lower cost than explosive sources (and usuaily lower cost than vibrators). Operators often choose the lowest cost source even if the source has some technical shortcomings.
While non-expiosive sources are used in some embodiments described herein, explosive sources may be used In other embodiments described herein.
S data can be acquired in the widest possible range of environments when vertlcalforce sources are utiiized. Explosive sources can be used in swamps, mountains, etc. where non-explosive sources are not feasible or practical, and vibrators and vertical impact sources can be used in high-culture areas (cities, roads, etc) where explosives are prohibited, and when budget constraints limit source options.
The Systems and methods described with référencé to FIGs. 17-20 may implement any of the features or principles described with référencé to FIGs. 1-16.
Extractlng SV Shear Data from P-Wave Seismic Data
Referring now to FIGs. 21-35, system and methods for extractîng SV shear-wave data from P-wave seismic data will be described.
Systems and methods are described for extracting SV shear-wave data from P-wave seismic data acquired with a vertical-force source and vertical geophones. The P-wave seismic data may comprise legacy P-wave data (e.g., P-wave data acquired at some time days, months, or years, such as at least one year, In the past), P-wave data acquired in the présent day, two dimensional data, three dimensional data, single-component sensor data, and/or three-component sensor data acquired across a wide variety of Earth surface conditions.
These Systems and methods are based on the use and application of the SV-P mode produced by a vertical-force seismic source. The SV component of this seismic mode
-2617041 provides valuable rock and fluid information that cannot be extracted from P-wave seismic data. The Systems and methods may produce an S-wave image from seismic data acquired with surface-based vertical geophones.
According to some embodiments, vertical, single-component, surface-based seismic 5 sensors are used to acquire SV shear data.
Systems and methods are described for extractlng SV-SV data from P-wave seismic data acquired with a vertical-force source and vertical geophones in situations where Pwave data are acquired across areas of exposed high-velocity rocks.
Systems and methods are described for extractlng P-SV data from P-wave seismic 10 data acquired with a vertical-force source and vertical geophones in situations where Pwave data are acquired across areas of exposed high-velocity rocks.
The principal seismic reflection data that are acquired to evaluate geological conditions across onshore areas are compressional-wave (P-wave) data. From a hlstoricat perspective, numerous large libraries of legacy seismic data exist, with the âges of these 15 data extending back into the 1950’s and 1960's. Most legacy seismic data are P-wave data.
The term land-based seismic data refers to any seismic data acquired in nonmarine environments, which would include data acquired across swamps, marshes, and shallow coastai water, as well as data acquired across exposed land surfaces. Land-based P-wave data are generated using vertical-force sources. This term “vertical-force source 20 includes any seismic source that applies a vertical force to the Earth. Included in the broad range of vertical-force seismic sources are vertical vibrators, vertical impacts, and shot-hole explosives.
P-wave land-based seismic data are recorded using vertical geophones or other vertically oriented seismic sensors. When acquiring P-wave seismic data, the sensor 25 deployed at each receiver station can be either single-component or three-component as long as sensor éléments in each receiver package measure vertical movement of the Earth.
One or more embodiments described herein may allow SV shear-wave data to be extracted from P-wave data acquired with vertical-force sources and vertical sensors. One or more embodiments may apply whether a sensor package is single-component or three30 component. One or more embodiments may appty to legacy P-wave seismic data as well as to P-wave data acquired in the présent day.
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One or more embodiments described herein may allow SV shear-wave data to be extracted from either 2D or 3D P-wave data.
SV-to-P Seismic Mode
The embodiments that are configured to extract SV shear-wave data from P-wave data use the SV-to-P converted seismic mode. The notation SV-P will be used to deslgnate this wave mode. In this notation, the first term identifies the downgoing seismic wave (SV) that Illuminâtes géologie targets, and the second term désignâtes the upgoing reflected wave (P) from those targets. To maintain consistent notation, standard P-wave data will be labeled as P-P data, meaning the downgoing illuminating wavefield is a P-wave, and the 10 upgoing reflected wavefield is also a P-wave.
Raypath diagrams comparing SV-P Imaging of subsurface geology and conventional P-P Imaging are iilustrated on Figure 21. The bold arrows 2100,2102 drawn at the source station 2104 and receiver station 2106 are vertical to illustrate: (1) the seismic source applies a vertical force vector to the Earth, and (2) each sensing geophone is oriented 15 vertically or otherwise configured to sense or measure vertical movement of the Earth.
Receiver 2102 may be a vertical geophone, a vertical component of a muiti-component geophone, or another single- or muiti-component geophone configured to sense, measure or detect vertical movement of the Earth (e.g., a 54 degree’ geometry geophone or Gal'perin geophone). As described hereinabove, a vertical-force seismic source produces 20 not only P waves but also SV and SH shear waves. Consequently, both downgoing P and downgoing SV raypaths are shown propagating away from the vertical-force source station 2104 on Figure 21. Segments of downgoing and upgoing raypaths are labeled either P or SV to Indicate the spécifie wave mode that travels along each segment of each raypath. Cirded arrows on each raypath segment Identify the direction in which the wave mode 25 acting on that raypath segment displaces the Earth. The data polarities indicated by these particle displacement vectors agréé with the polarity conventions defined by Akl and Richards (1980).
•Common-midpoint imaging may be used to produce P-P stacked Images of the Earth's subsurface. In a flat-iayered Earth, when the velocity of the downgoing wavefield 30 that illuminâtes a géologie target is the same as the velocity of the upgoing reflected wavefield from that target, as it Is for P-P data, the reflection point (image point) is half way between the source and the receiver. Therefore, the terms common midpoint or “CMP are used to describe this imaging concept.
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When seismlc Images are made using a downgoing illuminating wavefield that has a velocity that différa from the velocity of the upgoing reflected wavefield, a different concept called “common-conversion-point imaging is used to construct stacked Images of géologie targets. The abbreviation ‘CCP* is used to indicate this seismlc Imaging strategy. CCP imaging techniques are used to construct stacked images from SV-P data because the downgoing SV mode has a velocity that différa from the velocity of the upgoing P mode (Fig. 21).
As shown on Figure 21, the upgoing events that arrive at a receiver station are Pwave events for both P-P and SV-P modes. A concept not illustrated In this simplified, 10 straight-raypath mode! Is that a P raypath curves to become aimost true-vertical when It entera an unconsolidated, low-velocity layer 2100 that covers most ofthe Earth’s surface. This principle is illustrated on Figure 22. When upgoing P raypaths 2200,2202 bend to aimost true-vertical as they approach a receiver station 2106, their particle dispiacement vectors 2204, 2206 align with vertically oriented geophones at receiver station 2106 and 15 induce a strong response in a vertical geophone. Because both legacy P-wave seismlc data and present-day P-wave data are recorded with vertical geophones, these P-wave data contain not oniy P-P modes, but also SV-P modes, such as raypath 2200 illustrated in Figure 22.
As illustrated In Figure 36, If a P-wave is traveiing in a true horizontal direction when 20 it arrives at a vertical geophone, the P-wave will not generate any response in the geophone. If a P-wave Is traveiing in a true vertical direction when it arrives at a vertical geophone, the P-wave will induce a maximum geophone response (A). At any Intermediate angle of approach, the geophone response produced by an arriving P-wave will be A cos(0), where Φ is the approach angle measured relative to true vertical, and A is the 25 maximum response the P-wave produces when It travels in a true vertical direction. At some non-vertical approach angle Φχ, a P-wave will still hâve a small vertical component that will produce a small response In a vertical geophone, but not a “usabie signal. The exact value of cutoff angle Φ„ varies from location to location, and varies day to day at any given location, depending on the level of background noise that is présent. Background so noise Indudes wind-generated shaking of local végétation, mechanical vibrations from nearby machinery or véhiculer traffic, water drops falling from the sky or dripping from doseby trees and bushes, and other factors that induce disturbances dose to a geophone station.
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An additional Imaging option Is illustrated on Figure 23. In this scénario, the raypath labeling acknowledges a vertical-force source 2104 causes an SV-SV mode 2300 which arrives at a receiver station 2106 just as does a P-P mode 2108 (Figure 21). However, when the principle Is applied that, In most Earth surface conditions, raypaths approach a surface receiver in an aimost or substantially vertical direction, the orientation of the particle displacement vector 2302 associated with an upgoing SV raypath 2301 does not activate a vertical geophone (as the upgoing P waves do In Figure 22). Thus for some P-wave data acquired with vertical geophones, It may not be possible to extract SV-SV reflection events (or P-SV reflection events) from the response of vertical-geophone data.
An exception to the principle described on Figure 23 occurs when vertical geophones are deployed across an Earth surface where the top Earth layer is a hard, highvelocity material, as in layer 2400 in Figure 24. In this type of surface condition, an SV raypath 2400 will arrive at a receiver station 2106 along a substantially nonvertical trajectory, and the vertical component of an SV particle displacement vector 2402 will activate a vertical geophone 2106 (Figure 24). Thus, when P-wave data are acquired across high-velocity surfaces with vertical geophones, data having an upgoing SV mode are recorded by vertical geophones in addition to SV-P data. As a resuit, both P-SV and SV-SV data, which both hâve upgoing SV modes, are recorded by vertical geophones In situations where geophones are deployed across a high-velocity surface layer. Both upgoing P and SV raypaths in Figures 24 approach receiver station 2106 from a direction that différa signlficantly from near-vertical.
As illustrated In Figure 37, where the upgoing mode is SV, the response that an SV arrivai Induces In a vertical geophone Is A sin(O), rather than Acos(O) as it is for an upgoing P mode. The larger Φ is, the stronger the SV response Is. As S velocity Increases in the topmost Earth layer, Φ Increases. How big Φ should be, and how large S velocity should be to ensure there Is an appréciable value of Φ, dépend again on the magnitude of the background noise at the receiver station.
One or more embodiments described herein may acqulre P-SV data without the use of three-component geophones and without extracting the upgoing SV mode from horizontal-geophone responses. One or more embodiments described herein allows P-SV data to be acquired with slngle-component vertical geophones, for example In situations where the top Earth layer Is high-velodty rock. One or more embodiments described herein may acqulre P-SV data without the use of a receiver configured to sense, detect or measure horizontal movement of the Earth.
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P-SV and SV-P raypaths are compared on Figure 25. Because upgoing raypaths become near-vertical In a low-velodty surface layer (Fig. 22), the orientation of particle displacement associated with the upgoing SV segment 2500 of a P-SV mode 2502 fails to activate a vertical geophone in many Earth surface environments. Thus, in some verticalgeophone P-wave data, there will be no usable P-SV data. However, P-SV data will be recorded by a vertical geophone In cases where the top Earth layer has high velocity (Figure 24).
SV-P Image Space
The imaging principles of P-SV and SV-P modes 2502, 2504 illustrated on Figure 25 emphasize an SV-P mode images geology 2506 doser to a source station 2508 than to a receiver station 2510. When P-wave data are acquired with a source-receiver geometry in which receivers occupy an area that differs significantly from the area occupied by sources, it Is useful to understand how the image space spanned by SV-P data differs from the image space spanned by the P-SV mode.
Figures 26A and 26B show two options in which P-wave data are acquired across the same image space using vertical-force sources and vertical geophones. The figures illustrate source-receiver geometries from an aerial view looking downward, showing the size and position of SV-P image space (11,12,13,14) for two three-dimensional P-wave dataacquisition geometries. With the source-receiver geometry shown on Figure 26A, the area spanned by source stations 2600 Is larger than the area spanned by receiver stations 2602. In the option shown as Figure 26B, the reverse is true, and receivers span an area 2604 larger than the area spanned by sources 2610. The CMP P-wave Image space will be the same for both geometries because the same number of source-receiver pairs is involved, and these station pairs occupy the same Earth coordinates in both geometries. To avoid graphie dutter, the boundaries of P-P Image space are not shown on the drawings, but If drawn, the boundaries of P-P image space would be half-way between the boundaries of receiver area R1-to-R4 and the boundaries of source area S1-to-S4 In both Figures 26A and 26B, reflectîng the midpoint aspect of the CMP method.
The size and position of SV-P Image space resuiting from these two distinct dataacquisition geometries of Figures 26A and 26B differ. SV-P Image space covers a large area 2608 when the geometry option of Figure 26A Is used and a relatively smaller area 2606 when the geometry option of Figure 26B Is used. For both geometries, SV-P Image points are positioned doser to source stations than to receiver stations. Because of the
-3117041 reciprocal relationships between the image coordinates of SV-P and P-SV modes (Figure 25), the image space spanned by P-SV data when the geometry of Figure 26A is used would be the image space spanned by SV-P data in Figure 26B. If the geometry of Figure 26B is used, then P-SV data would span the SV-P image space drawn on Figure 26A.
Because the same number of source-receiver pairs is involved in each data-acquisition geometry ln this exemplary embodiment, SV-P stacking fold across the larger area (Fig. 26A) will be lower than SV-P stacking fold across the smaller area (Fig. 26B). Each geometry offers advantages for the SV-P mode, depending on the signal-to-noise ratio of SV-P data. If the SV-P signal-to-noise ratio is rather high, then the option of Figure 26A 10 extends good-quality SV information over a larger area than what is imaged by P-SV data.
If the SV-P signai-to-noise ratio is low, then increasîng SV-P fold over a smaller area as in Figure 26B should croate better quatity SV information than what is provided by P-SV data that extend over a larger area with reduced fold.
SV-P Data Processing - Data Polarlty
As explained with référencé to the embodiments of Figures 1-20, to extract SV-SV and SH-SH modes from data generated by a vertical-force source, the processing reverses the polarity of data acquired by horizontal geophones stationed in the negative-offset direction relative to the polarity of data acquired by horizontal geophones deployed in the positive-offset direction. That data polarity adjustment does not apply to SV-P data in this embodiment because the SV-P wave mode is recorded by vertical geophones, not by horizontal geophones.
Raypaths involved ln positive-offset and negative-offset SV-P imaging are illustrated on Figure 27. ln this diagram, SV-P data generated at vertical source A and recorded at vertical receiver A are iabeled SVA for the downgoing SV mode and PA for the upgoing P 25 mode. The offset direction from vertical source A to vertical receiver A is arbltrarily defined as positive offset. When the positions of source and receiver are exchanged, creating vertical source B and vertical receiver B, the offset direction reverses and is defined as négative offset. The raypath for negative-offset SV-P data is iabeled SVb for the downgoing SV mode and PB for the upgoing P mode. The poiarities shown for the downgoing SV 30 particle-displacement vector conform to the polarity convention established by Aki and
Richards (1980) and documented by Hardage et ai. (2011). Note that for both positiveoffset data and negative-offsetdata, the vertical componentofthe particle-displacement vectors for the upgoing P modes are ln the same direction (pointing up), hence there is no change in SV-P data polarity between positive-offset data and negative-offset data.
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If the SV-SV mode Is extracted from P-wave data In situations where a high-velocity Earth surface allows the upward traveling SV mode to energize a vertical geophone (Fig. 24), it likewise is not necessary to adjust the polarity of the vertical-geophone data In either offset-direction domain. Adjusting the polarity of upward traveling SV modes In the negative-offset domain to agréé with the polarity In the positive-offset domain is used when the SV mode is recorded by horizontal geophones, not when they are acqulred by vertical geophones.
SV-P Data Processing - Velocity Analysis
The embodiments described herein may be configured to perform a velocity analysis as a data-processing step when constructing seismic Images. When CMP data are processed, It Is not necessary to be concemed about which offset domain (positive or négative) data résidé In when performing velocity analyses. If the velodties of downgoing and upgoing wave modes are the same (CMP data processing), the same velocity behavior occurs In both offset directions. However, when converted modes are involved, the method may comprise two velocity analyses—one analysis for positive-offset data and a second analysis for negative-offset data.
The reason for this dual-domain velocity analysis is illustrated on Figure 27, which shows two distinct rock faciès between two surface-based source and receïver stations. Laterally varying rock conditions such as shown on this diagram can be found in many areas. For purposes of Illustration, assume the P and S velodties In Fades A are signifîcantly different from the P and S velodties In Fades B. The travel time required for a positive-offset SV-P event to travel raypath SVA-PA is not the same as the travel time for a negative-offset SV-P event to travel raypath SVB-PB. This différence In travel time occurs because the SVA mode is totally In Faciès A, but the SVB mode Is almost en tire ly In Fades B. Likewise, ail of mode PB Is in Fades A, but mode PA has significant travel paths inside Fades A and Fades B. Because travel times differ in positive-offset and negative-offset directions, one velodty analysis Is done on positive-offset data, and a separate velodty analysis is done for negative-offset data.
Examples of SV-P reflection events extracted from P-wave data by velodty analysis are displayed as Figures 28A and 28B. Figures 28A and 28B lllustrate SV-P reflections extracted from vertical-geophone P-wave seismic data. The seismic source was a shothole explosive (a vertical-force source). Two shot signal gathers or acquisitions generated at source stations 1007 and 1107 are displayed after velodty filtering. For each shot gather,
-3317041 velodty analyses were done separately for posîtive-offset data and negative-offset data. In these examples, there 1s not a large différence between posîtive-offset and negative-offset velodties. As a resuit, the curvatures of negative-offset SV-P reflections are approximately the same as the curvatures of posîtive-offset SV-P reflections.
Only reflectîon events having curvatures coindding with downgoing Vs velodties and upgoîng VP velodties appropriate for the rock sequence where these data were acquired are accepted. Other velodties are rejected. These examples corne from a seismlc survey for which the energy sources were vertical-force sources, and the analyzed data were recorded by vertical geophones. Analyses for two common-shot trace gathers are shown. For each shot gather, positive-offset data were subjected to velodty analysis separately from negative-offset data. Each velodty analysis rejected reflectîon events having velodties that differed by more than 20-percent from the velodties used to create high-quality P-SV images across the same image space. The resuit is that high-quality SV-P reflections are extradée! from vertical geophone data for both positive-offset P-wave data and negativeoffset P-wave data. The prindpal différence In P-SV and SV-P velodty analyses In this exemplary embodiment Is that P-SV velodty analyses are done on data recorded by horizontal geophones; whereas, SV-P velodty analyses are done on data recorded by vertical geophones.
To make seismic images from the reflectîon events shown in FIGs. 28A and 28B, reflectîon events for a number of source stations in the survey (e.g., at least 10, at least 100, at least 1000, etc.) wouid be generated. The reflectîon event data then would be binned, stacked and migrated. For example, the reflectîon event data may be binned using CCP or ACP binning strategies to define those coordinates. The reflectîon event data may then be stacked and then migrated after stack to generate an image. Migration physlcaliy moves refledions from where they are in reflectîon time to where they should be in image time.
The reflectîon events shown in FiGs. 28A and 28B comprise primary reflectîon events and multiple reflectîon events. Multiple refledlon events resuit from multiple reflections of seismic waves caused by réverbérations between interfaces of layers of the Earth. Multiple reflectîon events can cause an Image to not be positioned correctiy in travel time space. Multiple reflections may be filtered out of the reflectîon events in subséquent processing.
The reflectîon events shown in FiGs. 28A and 28B comprise an interpreted primary reflectîon at a point where reflectîon events In négative offset and positive offset domains
-3417041 meet, such as point 2800. The reflection events comprise an interpreted multiple reflection at a point where reflection events in négative offset and positive offset domains do not meet, such as point 2802.
SV-P Data Processing: Constructing SV-P Images
The processing of SV-P data for generating Images can be done in a number of ways, such as: (1) by CCP blnning and stacking of SV-P reflections, followed by post-stack migration of the stacked data, or (2) by Implementing prestack migration of SV-P reflections. Each method has Its own benefits. For example, method 2 (prestack migration) Is a more rigorous approach; method 1 (CCP binnlng/stacking and post-stack migration) Is lower cost.
To perform CCP blnning and migration of SV-P data, CCP coordinates of SV-P image points are mirror images of CCP image points associated with P-SV data, as illustrated on Figure 29. The SV-P data-processing strategy may be based on this mlrror-lmage symmetry of CCP image-point profiles for P-SV and SV-P modes.
Because positive-offset and negative-offset SV-P data hâve different veiocity is behaviors, two separate CCP binnlng/stacking steps are done to create an SV-P stacked
Image. In a first step, positive-offset data are binned and stacked into an image using velodties determined from positive-offset data, and in a second step, negative-offset data are binned and stacked into a second Image using velodties determined from negativeoffset data. The final SV-P image is the sum of these two images. This same dual-image 20 strategy may be implemented when binning and stacking P-SV data. The three stacked images (negative-offset Image, positive-offset Image, and summed image) can be migrated and used in geological applications. As documented by Hardage et al. (2011) relative to PSV imaging, some géologie features are sometimes bette r seen in one of these three images than in its two companlon images. Thus ali three stacked and migrated images may 25 be used In geological interprétations.
SV-P Data Processing: Method 1—CCP Blnning, Stacking, and Post-Stack Migration
Some commerdal seismlc data-processing software that can be purchased or leased by the geophyslcal community can calculate converted-mode image coordinates 30 called asymptotic conversion points, which are abbreviated as ACP. Two examples are
Vista seismlc data processing software, sold by Geophyslcal Exploration & Development Corporation, Alberta, Canada and ProMAX seismlc data processing software, sold by Halliburton Company, Houston, Texas. An ACP Is an image coordinate where the trend of
-3517041 correct CCP image points for a spécifie source-receiver pair becomes quasi-vertical (Figure 29). Deep geology is correctly Imaged using P-SV data binned using ACP coordinates, and would also be correctly imaged by SV-P data binned using ACP concepts that are adjusted for SV-P data. However, shallow geology is not correctly imaged for either P-SV data or SV-P data when ACP binnlng methods are used. True CCP binning can produce correct stacked images of both shallow and deep geology for converted modes appropriate for post-stack migration. On Figure 29, the asymptotic conversion point for the P-SV mode Is labeied ACP1, and the asymptotic conversion point for the SV-P mode Is labeled ACP2. Neither image point is correct except where their associated CCP binning profile Is quasivertical (i.e., for deep targets). As emphasized above, these two Image points are mirror images of each other relative to the common midpoint (point CMP on Figure 29) for any source-receiver pair involved in a seismic survey.
One exempiary method of produclng SV-P CCP/ACP binning comprises adjusting software that performs CCP binning for P-SV data so that the coordinates of sources and receivers are exchanged when determining image-point coordinates. Referring to the source-receiver pair drawn on Figure 29, an exchange of station coordinates has the effect of moving the receiver station to the source station and the source station to the receiver station. Software used to process P-SV data will then calculate the image point trend labeled CCP2 ratherthan the trend labeled CCP1. Using coordinates specified by profile CCP2 to bin SV-P reflections extracted from vertical-geophone data can produce SV-P images. The SV-P images should be equai In quality to what is now achieved with P-SV data.
Curve CCP1 shows the trend of oommon-conversion points for P-SV data. Curve CCP2 shows the trend of common-conversion points for SV-P data. ACP1 and ACP2 are asymptotic conversion points for trends CCP1 and CCP2, respectively. CCP1 and CCP2 are mirror images of each other relative to the common midpoint CMP for this sourcereceiver pair.
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SV-P Data Processing: Method 2—Prestack Migration
According to an alternative embodiment, prestack migration can be done so as to create a time-based seismic image or a depth-based seismic Image. Referring to Figure 30, prestack migration may be done by numericaliy propagating a spécifie seismic wavefield downward from each source station to iliuminate géologie targets, and then numericaliy propagating a spécifie seismic wavefield upward from reflecting interfaces to each receiver station.
The spécifie wavefields used in prestack migration may be created by applying velocity filtera to data recorded by vertical geophones so that reflection events having only a predetermlned velocity behavior remain after velocity fiitering. The predetermlned velocity behaviors of interest are those associated with the following seismic modes: P-P, P-SV, SVSV, and SV-P. If 3C geophones are used in combination with a vertical-force source, a fifth velocity fiitering option is to extract SH-SH reflection events. However, for this latter option, the fiitering action is applied to data recorded by transverse horizontal geophones. The resuit ls an Image of géologie interfaces seen by each spécifie seismic mode. For simplicity, only one source station and only one receiver station are shown on Figure 30.
The table on Figure 30 considéra oniy wave modes produced by a vertical-force source as described herelnabove with reference to Figures 1-20 (P, SV, SH) and the responses of only vertical geophones. For an Earth with Isotropie velocity layers, there are five possible combinations of downgoing (D) and upgoing (U) modes. These possibilities are labeled Option 1 through Option 5 In the figure table.
As Indicated by the table on Figure 30, prestack migration software can create an SV-P image if the velocity of the downgoing wavefield is that for a propagating SV wavefield and the velocity of the upgoing wavefield ls that for a P wavefield. Examples of SV-P data that wouid be used for pre-stack migration Option 3 iisted on Figure 30 (SV-P imaging) are exhiblted on Figure 28. For a 3D P-wave seismic survey, velocity fiitering similar to that done to produce these two example shot-gathera wouid be done for ail shot gathera across a survey area. If a survey involves 1000 source stations, then 1000 velodty-filtered shotgathera similar to those on Figure 28 wouid be created. Ail 1000 sets of SV-P reflectîons wouid be pre-stack migrated downward through an Earth model having layers of SV velocities and then migrated upward through an Earth model having layers of P-wave velocities.
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In Figure 30, a time-space distribution of velocities for a spécifie seismic mode is defined so that a spécifie downgoing wavefield (D) can be propagated through thls Earth velodty model from every source station to illuminate targets. A second time-space distribution of veiodties for a second spécifie seismic mode is then Imposed to propagate 5 that spedfic reflected upgoing wavefield (U) to every receiver station. The combinations of downgoing and upgoing veiodties that can be Implemented for a vertical-force source and vertical geophones are iisted in the table of Figure 30.
SV-P Data Processing - Determinlng S-Wave Velodty
To calculate either of the CCP binning profiles shown on Figure 29, the processing system Is configured to détermine the S-wave velodty within the geology that is being imaged. if the altemate option of creating converted-mode images with prestack migration techniques is used (Fig. 30), the processing system is configured to generate reliable estimâtes of S-wave velocities within the rocks that are illuminated by the seismic data. Determinlng the S-wave velodty for calculatlng SV-P Image points can be done In the same way that S-wave imaging veiodties are determined for P-SV data. Methods for determinlng
S-wave velodty for calculatlng converted-mode image points comprise:
Use 3-component vertical seismic profile (VSP) data acquired local to the seismic image area to calculate interval values of VP and Vs veiodties.
Use dipole sonie log data acquired local to the seismic image space to détermine Vp and Vs 20 veiodties.
Combine laboratory measurements of Vp/Vs velodty ratios for rock types like those being Imaged with selsmic-based estimâtes of P-wave veiodties to calculate S-wave velocities.
Calculate CCP binning profiles for a variety of Vp/Vs velodty ratios, make separate stacks of converted-mode data for each CCP trend, and examine the sériés of stacked data to détermine which CCP profile produces the best quality Image.
Any of these methods will provide reliable S-wave veiodties to use for binning SV-P data. Altemate methods may be used.
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Comparison of SV-P data to P*SV data
This application shows there are several similarities between SV-P data and P-SV data, according to some exemplary embodiments. There are also différences between the two wave modes, according to some exemplary embodiments. Some of these similarities s and différences are listed in the table shown as Figure 31. Similarities between SV-P and
P-SV data Include items 1,5, and 6 (same energy source, same velocity analysis strategy, and same normal moveout (NMO) velocity behavior). Différences include items 2,3,4, and 7 (different receivers, different image coordinates, different CCP profiles, and different polarity behavior).
SV-P Data Processing Apparatus
Referring now to FIG. 32, a data processing System for processing SV-P data will be described. System 3200 is configured to extract SV shear data from vertical-sensor responses. System 3200 comprises a digital computation System 3202, such as a Personal computer, UNIX server, single workstatlon, high-end cluster of workstations, or other computing System or Systems. System 3202 comprises sufficient processing power to process large quantifies of complex seismic data. A mass storage device 3204 or other memory is coupled to digital computation System 3202, which is configured to receive data from the field recorders or sensors stored on a digital media 3202, such as a memory card, hard drive, or other memory device. Mass storage device 3204 is configured to download or receive the multi-component seismic data from digital media 3206 and to store the data in a database.
tn this embodiment, digital media 3206 comprises data received from a vertical sensor using a field recorder or receiver. The data on digital media 3206 may hâve been acquired recently or days, months, or years in the past. The data may hâve been recorded 25 using a vertical force sensor having a sufficient listening time, for example of at least 5 seconds, at least 8 seconds, at least 10 seconds, or other periods of time. The data may hâve been acquired without the expectation of recovering SV-P data by the entity handling the acquisition of data and without knowledge of the presence of SV-P data in the data acquired from seismic reflections.
The remaining éléments in FIG. 32 may comprise any of the embodiments described hereinabove with référencé to FIG. 19, or other components. Software library 3212 may comprise processing algorithms configured to process the data according to any of the
-3917041 principles described hereinabove, for example with référencé to FIGs. 21-31, and FIGs. 34 and 35 below.
SV-P Data Acquisition
Referring now to Figure 33, a diagram of a data acquisition System 3300 and method for acquiring SV-P data from a vertical-force source using surface-based sensors wili be described. A vertical-force seismic source 3302 is disposed on, near, or within a shallow recess of the Earth’s surface 3304, which may comprise relatively high-velocity layers or portions or relatively low-velocity layers or portions. Source 3302 is configured to impart a vertical-force to surface 3304 to provide seismic waves into Earth media 3306.
Source 3302 may comprise a vertical vibrator, shot-hole explosive, vertical-impactor, air gun, vertical weight-dropper or thumper, and/or other vertical-force sources, in this example, vertical-force source 3302 produces compresslonal P mode and both fundamental shear modes (SH and SV) in Earth 3306 directly at a point of application 3308 of the vertical-force source, in this embodiment, at ieast some of the SH and SV shear waves are generated at source 3302 and not by subsurface conversion caused by portions of Earth media 3306. The frequency waves may be provided in a frequency sweep or a single broadband Impulse. A vertical-force source may be used without any horizontal-force sources.
A seismic sensor 3310 is along the Earth’s surface, which may include being disposed on, near, or within a recess of the Earth’s surface 3304. For example, in one embodiment, shallow holes may be driiled and sensors 3310 deployed in the holes to avoid wind noise, noise produced by rain showers, etc. Sensor 3310 Is configured to detect or sense upgoing wave modes, reflected from subsurface sectors, formations, targets of interest, etc. In this embodiment, sensor 3310 may comprise a vertical-response sensor (either single-component or 3-component package) configured to sense compressions! P modes and, as described herein, other modes such as SV-P (e.g., direct SV-P). In one embodiment, sensor 3310 may comprise a vertical-response sensor without horizontalresponse sensors, for example only a single, vertical-response sensor. Various arrays and configurations of sources 3302 and sensors 3310 may be implemented in different so embodiments.
The remaining éléments in FIG. 32 may comprise any of the embodiments described hereinabove with référencé to FIG. 17, or other components.
Data Processing In Low-Veloclty Earth Surface
-4017041
Referring now to FIG. 34, a flow diagram Iliustrating a method 3400 of processing vertical sensor data for low-velocity Earth surface will be described. The method may be opérable on one or more processing circuits, such as digital computation system 3202. The method 3400 may use similar techniques to those described above with référencé to FIG. 20, which contains further explanation of some ofthe processing procedures described In FIG. 34. At a block 3402, a processing circuit Is provided with mixed P-P and SV-P modes In vertical-sensor data from acquisition steps described prevlously. At block 3404, the processing circuit Is confîgured to or programmed to segregate, separate or otherwise remove P-P and SV-P mode data by applying velocity filters to reject or filter out improper wave-mode propagation velodties.
At a block 3406, the processing circuit Is confîgured to détermine NMO, stacking and/or migration velodties for P-P and SV-P modes. Separate velodty analyses should be done for positive-offset SV-P data and for négative offset SV-P data. If there Is no latéral variation In P and SV velodties around a source station, there Is no need to do two separate SV-P velocity analyses - one velodty analysis for positive-offset data, and a second velodty for negative-offset data. In such a simple, uniform-velodty Earth, positive-offset SV-P reflections and negative-offset SV-P reflections hâve the same velodty curvatures, and a velodty analysis done In one offset domain can be used for the opposite-azimuth offset domain. However, it Is rare for there to not be latéral variations In P and SV velodties around a source station as illustrated on Figure 27. When layer velodties vary laterally for any reason, positive-offset and negative-offset SV-P data should undergo separate velodty analyses as previously discussed using Figure 27. To ensure latéral velocity variations are accounted for, converted-mode data are processed as two separate data sets. One data set Involves only positive-offset data, and the second data set involves only negative-offset data.
At a block 3408, static corrections are applied to Improve reflector alignment. These corrections Involve time shifts of data acquired at each source and recelver station. Because these time shifts are applied to an entire data trace, they are termed static corrections to differentiate them from dynamic time adjustments done by other processes. One static correction removes timing différences caused by variations In station élévations by adjusting time-zero on each data trace to mathematically move ail source and receiver stations to a common datum plane. A second static correction removes timing différences cause by different velodties being local to different source and receiver stations. The end resuit of these static corrections Is an Improvement in reflection continuity.
-4117041
At a block 3410, any one of many noise rejection procedures may be applied to the data to improve the signal-to-noise ratio. Some noise rejection options may be simple frequency filters. Others may be more sophisticated tau-p, f-k, or deconvolution procedures. At block 3410, multiple atténuation may be applied to attenuate noise s attributable to multiples.
As described, multiple methods are available for processing the data to identify SV-P mode data and use It for generating an image, such as Method 1 and Method 2 described above. if Method 11s used, at a block 3412, the processing drcuit is configured to stack (or sum) P-P, SV-P posltive-offset and SV-P negative-offset data separately using either CCP io coordinates or ACP coordinates. At a block 3414, the processing drcuit is configured to sum SV-P posltive-offset and SV-P négative offset stacks. Block 3414 may use a CCP binning process. At a block 3416, the processing circuit Is configured to migrate post-stack data to make four images: a P-P image, an SV-P positive offset image, an SV-P negativeoffset image and an SV-P summed Image.
If Method 2 Is used, at a block 3420, the processing circuit Is configured to perform separate pre-stack migrations of P-P, SV-P positive offset data and SV-P negative-offset data and, at a block 3422, sum SV-P positive-offset and SV-P negative-offset Images.
At block 3418, an operator views the Images created by either or both of Method 1 and Method 2 and makes a détermination as to whether the image quaiity Is acceptable, if 20 not, the process retums, for example to block 3406 for further processing. An operator may adjust statïc corrections, recalculate velodties, etc. Altematively, block 3418 may be automated to not require a person to make the détermination, but rather to hâve the processing drcuit make the détermination based on certain image goals.
Data Processing in Hlgh-Veloclty Earth Surface
Referring now to FIG. 35, a flow diagram iliustrating a method 3500 of processing vertical sensor data for high-velodty Earth surface will be described. The method 3500 may use similar techniques to those described above with référencé to FIGs. 20 and 34, which contains further expianation of some of the processing procedures described in FIG. 35. As expiained previousiy, In high-velodty Earth surface situations, upgolng SV data can be detected by a vertical-force source, meaning that the data that can be processed into images now Indudes the SV-SV mode and the P-SV mode.
At a block 3502, a processing circuit is provided with mixed P-P, SV-SV, P-SV and SV-P modes In vertical-sensor data from acquisition steps described previously. At block -4217041
3504, the processing circuit is configured to or programmed to segregate, separate or otherwlse remove P-P, SV-SV, P-SV and SV-P mode data by appiying velodty filters to reject or filter out Improper wave-mode propagation velocities.
At a block 3506, the processing circuit Is configured to détermine NMO, stacking and/or migration velocities for P-P, SV-SV, P-SV and SV-P modes. Separate velodty analyses are required for positive-offset P-SV and SV-P data and for négative offset P-SV and SV-P data.
At a block 3508, static corrections are applied to Improve reflector alignment, as described with référencé to block 3408. At a block 3510, any one of many noise rejection procedures may be applied to the data to improve the signal-to-nolse ratio. Some noise rejection options may be simple frequency filters. Others may be more sophisticated tau-p, f-k, or deconvolution procedures. At block 3510, multiple atténuation may be applied to reduce noise attributable to multiples.
As described, multiple methods are availablefor processing the data to Identify SV-P mode data and use It for generating an Image, such as Method 1 and Method 2 described above. If Method 11s used, at a block 3512, the processing circuit Is configured to stack (or sum) P-P, SV-P positive-offset and SV-P negative-offcet data and P-SV positive-offset data and P-SV negative-offset data, each to be stacked separately. At a block 3514, the processing circuit Is configured to sum SV-P positive-offset and SV-P négative offset stacks and separately sum P-SV positive-offset and P-SV negative-offset stades. At a block 3615, the processing circuit Is configured to migrate post-stade data to make eight images: a P-P Image, an SV-P positive offset Image, an SV-P negative-offset Image, an SV-SV image, a P-SV positive offset Image, a P-SV négative offset image, P-SV summed Image and an SVP summed image.
if Method 2 is used, at a block 3520, the processing circuit is configured to perform separate pre-stack migrations of P-P, SV-SV, SV-P and P-SV positive offset data and SV-P and P-SV negative-offset data and, at a block 3522, sum SV-P positive-offset and SV-P negative-offcet Images.
At block 3518, an operator views the images created by either or both of Method 1 and Method 2 and makes a détermination as to whether the Image quaiity Is acceptable, if not, the process retums, for example to block 3506 for further processing. An operator may adjust static corrections, recalculate velocities, etc. Altematively, block 3518 may be
-4317041 automated to not require a person to make the détermination, but rather to hâve the processing circuit make the détermination based on certain image goals.
As IIIustrated in a comparison of Figures 20, 34 and 35, it is not necessary in the methods of Figures 34 and 35 to change the polarity of negative-azimuth data to agréé with 6 the polarity of posivite-azimuth data when dealing with vertical-sensor data. Aiso, it is not necessary to perform two separately velocity analyses when processing converted-mode data as in the methods of Figure 20 because that imaging is based on common-midpoint concepts, not on common-conversion point concepts being used in the methods of Figures 34 and 35. In the methods of Figures 34 and 35, one velocity analysis is done for positive10 azimuth data and a second analysis is done for negative-azimuth data (as explained with reference to Figure 27).
Various embodiments disclosed herein may include or be Implemented in connection with computer-readable media configured to store machine-executable instructions therein, and/or one or more modules, circuits, units, or other éléments that may 15 comprise analog and/or digital circuit components (e.g. a processor or other processing circuit) configured, arranged or programmed to perform one or more of the steps recited herein. By way of example, computer-readable media may indude non-transitory media such as RAM, ROM, CD-ROM or other optical disk storage, magnetic disk storage, flash memory, or any other non-transitory medium capable of storing and providing access to 20 desired machine-executable instructions. The use of circuit or module herein is meant to broadly encompass any one or more of discrète drcuit components, analog and/or digital circuit components, integrated circuits, solid state devices and/or programmed portions of any of the foregoing, Induding microprocessors, microcontrollers, ASICs, programmable logic, or other electronic devices.
While the detailed drawings, spécifie examples and particular formulations given describe exemplary embodiments, they serve the purpose of illustration only. The hardware and software configurations shown and described may differ depending on the chosen performance characteristics and physical characteristics of the computing devices. The Systems shown and described are not limited to the predse details and conditions
3o disdosed. Furthermore, other substitutions, modifications, changes, and omissions may be made in the design, operating conditions, and arrangement of the exemplary embodiments without departing from the scope of the présent disclosure as expressed In the appended daims.
Claims (31)
- WHAT IS CLAIMED IS:1. A method of processing seismic date obtained using a surface-based receiver configured to measure vertical movement of the Earth, comprising:retrieving seismic data from a storage device, the seismic data comprisingP-P data and shear mode data, wherein the P-P data and shear mode data were both received at a surface-based receiver configured to measure vertical movement of the Earth to generate the seismic data;processing the seismic data to extract the shear mode data; and generating a shear mode image based on the extracted shear mode data.
- 2 The method of Claim 1, wherein the shear mode data comprise SV-P data.
- 3. The method of Claim 2, wherein the processing comprises common conversion point binning of the SV-P data.
- 4. The method of Claim 3, wherein the processing comprises stacking the binned SV-P reflections. .
- 5. The method of Claim 4, wherein the binning and stacking are done separately for positive-offset SV-P data and negative-offset SV-P data.
- 6. The method of Claim 4, wherein the processing comprises migration of the SV-P reflections after the stacking.
- 7. The method of Claim 2, wherein the processing comprises generating asymptotic conversion point data based on the SV-P data.
- 8. The method of Claim 2, wherein the processing comprises pre-stack migrating the SV-P data.
- 9. The method of Claim 1, wherein the shear mode data are SV-SV data.
- 10. The method of Claim 1, wherein the shear mode data are P-SV data.
- 11. The method of Claim 1, wherein the P-P data and shear mode data were both received at the surface-based receiver without the use of multi-component geophones.
- 12. The method of Claim 1, wherein the P-P data and shear mode data were both received at the surface-based receiver without the use of geophones configured to measure horizontal movement of the Earth.
- 13. The method of Claim 1, wherein the seismic data represents data received 5 through a high velocity Earth formation near the receiver.
- 14. The method of Claim 1, wherein the seismic data represents data received through a low velocity Earth formation near the receiver.
- 15. The method of Claim 1, wherein the receiver is a vertical receiver.
- 16. A method of generating SV-P reflection data from vertical-geophone P-10 wave seismic data, comprising:retrieving from a storage device seismic data generated by a source and received by the vertical-geophone, the data comprising SV-P mode data;velocity filtering the seismic data, wherein the velocity filtering is done separately for positive-offset data and negative-offset data to create SV-P reflection data;15 ‘ and ' outputting reflection data based on the SV-P reflection data.
- 17. The method of Claim 16, wherein the seismic data was generated by an explosive source.
- 18. The method of Claim 17, wherein the SV-P mode data was received by the 20 vertical geophone without the use of geophones having a horizontal geophone response.
- 19. A System for processing seismic data obtained using a surface-based receiver, comprising:a storage device to store seismic data comprising P-P data and shear mode data, wherein the P-P data and shear mode data were both received at a surface2 5 based receiver to generate the seismic data;a processing circuit configured to process the seismic data to extract the shear mode data and to generate a shear mode image based on the extracted shear mode data.
- 20. The System of Claim 19, wherein the shear mode data comprise SV-P data.
- 21. The System of Claim 20, wherein the processing comprises common conversion point binning of the SV-P data.
- 22. The System of Claim 21, wherein the processing comprises stacking the binned SV-P reflections.
- 23. The System of Claim 22, wherein the binning and stacking are done separately for positive-offset SV-P data and negative-offset SV-P data.
- 24. The System of Claim 22, wherein the processing comprises migration of the SV-P reflections after the stacking.
- 25. The System of Claim 20, wherein the processing comprises generating asymptotic conversion point data based on the SV-P data.
- 26. The System of Claim 20, wherein the processing comprises pre-stack migrating the SV-P data.
- 27. The System of Claim 19, wherein the shear mode data comprise SV-SV data.
- 28. The System of Claim 19, wherein the shear mode data comprise P-SV data.
- 29. The System of Claim 19, wherein the P-P data and shear mode data were both received at the surface-based receiver without the use of multi-component geophones.
- 30. The System of Claim 19, wherein the seismic data was acquired at least one year prior to the processing.
- 31. The System of Claim 19, wherein the seismic data are based on reflections of seismic waves from a vertical-force source only, wherein the vertical-force source is selected from the group consisting of a vertical vibrator, a vertical impact, or explosive source.
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Application Number | Priority Date | Filing Date | Title |
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US13/287,746 | 2011-11-02 |
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OA17041A true OA17041A (en) | 2016-03-04 |
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