地电阻率与地下水位,大气降水关系研究

用固定的地面对称四极装置进行的地电阻率观测,是测量地表以下一定深度范围内介质的电性变化。对于定点测量而言,横向不均匀性不是主要矛盾。因此,电测深资料的数值解释是以层状水平延伸介质为理论模型。在垂向不均匀的电性剖面中,任意一层真电阻率的改变,都会使视电...     

粘弹性介质单程波法非零偏移距地震数值模拟与偏移

地震资料分辨率降低,得不到深层介质的精确信息实际上是由于大地吸收效应的影响.同时与双程波动方程相比单程波动方程避免了多次波的干扰并且计算效率高、占用内存少.本文首先基于开尔芬粘弹性介质模型将品质因子与单程波分步傅立叶法波场延拓算子相结合,实现了粘弹性介质波场延拓,从而将单程波弹性介质波场延拓推广到了粘弹性介质.然后在定位原理,数学检波器原理以及等时叠加原理的基础之上实现了粘弹性介质非零偏移距叠前正演模拟.最后将数值模拟得到的正演记录进行弹性偏移和粘弹性偏移并进行对比分析.通过数值算例可以看出,粘弹性介质叠前正演深层的反射波能量减弱,同相轴变粗,频带变窄,主频减小,分辨率降低;粘弹性偏移不但实现了振幅的恢复,而且同时偏移剖面的垂向空间分辨率也得到了提高.     

增强地震数据质量的非CMP叠加技术

阐述一种增强地震数据质量的非CMP叠加技术——零偏移距共反射面(ZO CRS)叠加.文章从分析目前模拟零偏移距(ZO)剖面常规方法存在的问题与ZO CRS叠加方法所具有的优势入手,介绍了ZO CRS叠加基本原理及其实现过程.利用2D人工合成理论模型数据对这种方法进行了验证并将其应用于低覆盖次数陆地实际资料.理论模型及实...     

椭圆展开共反射点叠加方法的应用研究

本文详细介绍了均匀介质条件下椭圆展开共反射点(CRP)叠加原理,并引入双参数(上行波与下行波的速度比和平均速度)来解决非均匀介质条件下的叠加成像,严密论证了所求得的速度是真正的共反射点叠加速度,并结合理论模型计算和地震资料处理证实,利用椭圆展开CRP方法可以对复杂地质剖面求取准确的共反射点叠加速度和正确的零偏移距剖面,得到的成像效果远优于传统共中心点(CMP)方法.     

横向均匀介质中地震走时的正演和反演

横向均匀介质可由若干水平分层足够好地逼近,本文引入零厚度层来描述成层介质,从而建立了回折波、反射波、首波和直达波统一的时距关系以及地震走时随模型参数变化的公式。本文详细讨论了水平分层介质里地震走时曲线的特征,合成地震走时的试验表明了由地震走时,用阻尼最小二乘法可以成功地反演速度模型参数,所反演的模型含有速度梯度层,也可以含有低速层。     

垂向非均匀介质的走时反演

本文提出了一种利用反射波走时曲线计算垂向非均匀介质速度和反射界面深度的方法。当在地球表面没有获得来自地下某一深度范围内介质的任何信息时,可以认为这一深度范围内的地震波速度具有连续性。利用来自其底部反射界面的反射波走时曲线,可以计算出该深度范围的地震波速度结构。对三种模型进行了理论计算,所得反演解与真实值较为一致,其中计算出的反射界面深度最为精确。利用本文提出的方法可以计算两个相邻反射面之间的垂向非均匀速度结构,如低速层等。     

垂向不均匀介质中波传播特点的研究

本文由波传播问题的变分原理导出了垂向不均匀介质中的弹性波波动方程及纵波和横波波动方程。在不同的假设条件下得到了纵、横波波动方程的几种简化形式,其中包括地震勘探中常用的变系数波动方程。利用有限单元法,求得了垂向不均匀介质中波动方程的数值解。通过数值结果对纵、横波之间的耦合程度以及介质的不均匀性对波的衰减作用进行了讨论。     

用反射波时距曲线求静校正值

本文叙述了用反射波时距曲线直接求静校正值的方法,讨论了该方法使用过程中所遇到的具体问题及其应用效果.     

华北平原中部地区深部构造背景及邢台地震（一）

为了研究华北平原中部地区的深部地壳结构,进行了地壳测深的剖面工作。该剖面西起河北省元氏县,东至山东省济南市郊,全长达270余公里。 全线分布九个爆炸点,构成了相遇和追逐的连续观测系统。根据波的运动学和动力学特点记到了很多一次反射波和一次首波,同时亦存在着多次波。该区地壳分为七个层次,且由高低速相间的介质组成。地壳的平均厚度为35-36公里,上覆介质的平均速度为6.0公里/秒,上地幔顶部介质的层速度为8.1公里/秒。 该区地壳为不均匀的多层结构,并存在着高速梯度夹层。 文中最后给出了地壳和上地幔顶部的综合速度分布和地壳模型。     

煤矿陷落柱的地震响应特征与识别

根据煤矿陷落柱的地质特征,设计了两类非均匀陷落柱模型,通过有限差分法模拟陷落柱的地震波场.通过对模拟波场叠加剖面和偏移剖面的对比,得出了大、小陷落柱的地震响应特征,并指导了实际地震剖面的陷落柱识别.结果表明:大的陷落柱的地震响应在时间剖面上特征表现为标准反射波的中断;而较小的陷落柱的地震响应在时间剖面上特征表现为弱反射能量异常.     

Moveout approximation for horizontal transversely isotropic and vertical transversely isotropic layered medium. Part I: 1D ray propagation‡

Anisotropy in subsurface geological models is primarily caused by two factors: sedimentation in shale/sand layers and fractures. The sedimentation factor is mainly modelled by vertical transverse isotropy (VTI), whereas the fractures are modelled by a horizontal transversely isotropic medium (HTI). In this paper we study hyperbolic and non‐hyperbolic normal reflection moveout for a package of HTI/VTI layers, considering arbitrary azimuthal orientation of the symmetry axis at each HTI layer. We consider a local 1D medium, whose properties change vertically, with flat interfaces between the layers. In this case, the horizontal slowness is preserved; thus, the azimuth of the phase velocity is the same for all layers of the package. In general, however, the azimuth of the ray velocity differs from the azimuth of the phase velocity. The ray azimuth depends on the layer properties and may be different for each layer. In this case, the use of the Dix equation requires projection of the moveout velocity of each layer on the phase plane. We derive an accurate equation for hyperbolic and high‐order terms of the normal moveout, relating the traveltime to the surface offset, or alternatively, to the subsurface reflection angle. We relate the azimuth of the surface offset to its magnitude (or to the reflection angle), considering short and long offsets. We compare the derived approximations with analytical ray tracing.     

Radar determination of the spatial structure of hydraulic conductivity

Spatial variability of hydraulic conductivity exerts a predominant control on the flow of fluid through porous media. Heterogeneities influence advective pathways, hydrodynamic dispersion, and density-dependent dispersion; they are, therefore, a key concern for studies of ground water resource development, contaminant transport, and reservoir engineering. Ground-penetrating radar contributes to the remote, geophysical characterization of the macroscale variability of natural porous media. On a controlled excavation of a glacial-fluvial sand and gravel deposit in the Fanshawe Delta area (Ontario, Canada), the hydraulic conductivity field of a 45 x 3 m vertical exposure was characterized using constant-head permeameter measurements performed on undisturbed horizontal sediment cores. Ground-penetrating radar data were collected along the excavation face in the form of both reflection and common midpoint surveys. Comparison of geostatistical analyses of the permeameter measurements and the radar data suggests thatthe horizontal correlation structure of radar stack velocity can be used to directly infer the horizontal correlation structure of hydraulic conductivity. The averaging nature of the common midpoint survey is manifest in the vertical correlation structure of stack velocity, making it less useful. Radar reflection data do not exhibit a spatial structure similar to that of hydraulic conductivity possibly because reflections are a result of material property contrasts rather than the material properties themselves.     

A METHOD TO DETERMINE THE VELOCITIES OF THE SEAFLOOR AND NEAR-SURFACE SEDIMENTS*

Shotpoint gathers from conventional reflection seismic surveys contain both reflected and refracted waves. In this study shot records were processed and analyzed, and the data were modeled with reflected, refracted, and reflected-refracted waves to fit the recorded data. The result is a detailed velocity model. The inverse problem for refracted waves was solved by using the Wiechert-Herglotz inversion. A 500-km-long 26-fold reflection seismic line from the Barents Sea, north of Norway, has been investigated. The data show high velocities, multiple reflections, and various types of noise. To test the method a total of 34 shot gathers were analyzed along this line. The aim of the interpretation was to determine the velocity in the seafloor and the near-surface sediments. It is possible to map the vertical as well as the lateral velocity distribution in detail. Depending on the length of the streamer and the velocity gradient in the sediments, the calculated depth varies between 300 and 500 m below the seafloor. These velocities were also compared to the stacking velocities obtained from the reflection seismic data to see how the velocities determined by different methods were related. The velocity distribution in the sediments is one of the key factors in seismic interpretation. The technique discussed in this paper can contribute to velocity information both in the processing and interpretation of seismic data.     

CRS-stack-based seismic imaging considering top-surface topography

In this case study we consider the seismic processing of a challenging land data set from the Arabian Peninsula. It suffers from rough top‐surface topography, a strongly varying weathering layer, and complex near‐surface geology. We aim at establishing a new seismic imaging workflow, well‐suited to these specific problems of land data processing. This workflow is based on the common‐reflection‐surface stack for topography, a generalized high‐density velocity analysis and stacking process. It is applied in a non‐interactive manner and provides an entire set of physically interpretable stacking parameters that include and complement the conventional stacking velocity. The implementation introduced combines two different approaches to topography handling to minimize the computational effort: after initial values of the stacking parameters are determined for a smoothly curved floating datum using conventional elevation statics, the final stack and also the related residual static correction are applied to the original prestack data, considering the true source and receiver elevations without the assumption of nearly vertical rays. Finally, we extrapolate all results to a chosen planar reference level using the stacking parameters. This redatuming procedure removes the influence of the rough measurement surface and provides standardized input for interpretation, tomographic velocity model determination, and post‐stack depth migration. The methodology of the residual static correction employed and the details of its application to this data example are discussed in a separate paper in this issue. In view of the complex near‐surface conditions, the imaging workflow that is conducted, i.e. stack – residual static correction – redatuming – tomographic inversion – prestack and post‐stack depth migration, leads to a significant improvement in resolution, signal‐to‐noise ratio and reflector continuity.     

SINGLE-TRACE PROCESSING USING ITERATIVE CDP-STACKING*

The use of conventional CDP-stacking in the processing of reflection data imposes restrictions on the horizontal and vertical resolution. Ideally, the final seismic section should consist only of short offset or, in practice, near-trace primary energy. Through the use of the iterative stacking algorithm, the signal-to-noise ratio on a single trace in the CDP-gather may be improved to an extent comparable to what occurs on a conventional stacked trace. By using this approach and treating the near-trace section after iterative stacking as the final section, the seismic resolution can be improved.     

Anisotropic P-wave attenuation measured from a multi-azimuth surface seismic reflection survey

A system of aligned vertical fractures produces azimuthal variations in stacking velocity and amplitude variation with offset, characteristics often reported in seismic reflection data for hydrocarbon exploration. Studies of associated attenuation anisotropy have been mostly theoretical, laboratory or vertical seismic profiling based. We used an 11 common‐midpoint‐long portion of each of four marine surface‐seismic reflection profiles, intersecting each other at 45° within circa 100 m of a common location, to measure the azimuthal variation of effective attenuation, Q⁻¹_eff and stacking velocity, in a shallow interval, about 100 m thick, in which consistently orientated vertical fracturing was expected due to an underlying salt diapirism. We found qualitative and quantitative consistency between the azimuthal variation in the attenuation and stacking velocity, and published amplitude variation with offset results. The 135° azimuth line showed the least apparent attenuation (1000 Q⁻¹_eff= 16 ± 7) and the fastest stacking velocity, hence we infer it to be closest to the fracture trend: the orthogonal 45° line showed the most apparent attenuation (1000Q⁻¹_eff= 52 ± 15) and slowest stacking velocity. The variation of Q⁻¹_eff with azimuth φ is well fitted by 1000Q⁻¹_eff = 34 − 18cos[2(φ+40°)] giving a fracture direction of 140 ± 23° (±1SD, derived from ‘bootstrapping’ fits to all 11⁴ combinations of individual common‐midpoint/azimuth measurements), compared to 134 ± 47° from published amplitude variation with offset data. The effects of short‐window spectral estimation and choices of spectral ratio bandwidth and offset ranges used in attenuation analysis, individually give uncertainties of up to ±13° in fracture direction. This magnitude of azimuthal variation can be produced by credible crack geometries (e.g., dry cracks, radius 6.5 m, aspect ratio 3 × 10⁻⁵, crack density 0.2) but we do not claim these to be the actual properties of the interval studied, because of the lack of well control (and its consequences for the choice of theoretical model and host rock physical properties) and the small number of azimuths available here.     

HORIZONTAL STACKING AND MULTICHANNEL FILTERING APPLIED TO COMMON DEPTH POINT SEISMIC DATA*

The common depth point method of shooting in oil exploration provides a series of seismic traces which yield information about the substrata layers at one location. After normal moveout and static corrections have been applied, the traces are combined by horizontal stacking, or linear multichannel filtering, into a single record in which the primary reflections have been enhanced relative to the multiple reflections and random noise. The criterion used in optimum horizontal stacking is to maximize the signal to noise power ratio, where signal refers to the primary reflection sequence and noise includes the multiple reflections. It is shown when this criterion is equivalent to minimizing the mean square difference between the desired signal (primary reflection sequence) and the weighted horizontally stacked traces. If the seismic traces are combined by multichannel linear filtering, the primary reflection sequence will have undergone some phase and frequency distortion on the resulting record. The signal to noise power ratio then becomes less meaningful a criterion for designing the optimum linear multichannel filter, and the mean square criterion is adopted. In general, however, since more a priori information about the seismic traces is required to design the optimum linear multichannel filter than required for the optimum set of weights of the horizontal stacking process, the former will be an improvement over the latter. It becomes evident that optimum horizontal stacking is a restricted form of linear multichannel filtering.     

HORIZONTAL STACKING AND MULTICHANNEL FILTERING APPLIED TO COMMON DEPTH POINT SEISMIC DATA*

The common depth point method of shooting in oil exploration provides a series of seismic traces which yield information about the substrata layers at one location. After normal moveout and static corrections have been applied, the traces are combined by horizontal stacking, or linear multichannel filtering, into a single record in which the primary reflections have been enhanced relative to the multiple reflections and random noise. The criterion used in optimum horizontal stacking is to maximize the signal to noise power ratio, where signal refers to the primary reflection sequence and noise includes the multiple reflections. It is shown when this criterion is equivalent to minimizing the mean square difference between the desired signal (primary reflection sequence) and the weighted horizontally stacked traces. If the seismic traces are combined by multichannel linear filtering, the primary reflection sequence will have undergone some phase and frequency distortion on the resulting record. The signal to noise power ratio then becomes less meaningful a criterion for designing the optimum linear multichannel filter, and the mean square criterion is adopted. In general, however, since more a priori information about the seismic traces is required to design the optimum linear multichannel filter than required for the optimum set of weights of the horizontal stacking process, the former will be an improvement over the latter. It becomes evident that optimum horizontal stacking is a restricted form of linear multichannel filtering.     

Moveout approximation for horizontal transversely isotropic and vertical transversely isotropic layered medium. Part II: effective model‡

We use residual moveouts measured along continuous full azimuth reflection angle gathers, in order to obtain effective horizontal transversely isotropic model parameters. The angle gathers are generated through a special angle domain imaging system, for a wide range of reflection angles and full range of phase velocity azimuths. The estimation of the effective model parameters is performed in two stages. First, the background horizontal transversely isotropic (HTI)/vertical transversely isotropic (VTI) layered model is used, along with the values of reflection angles, for converting the measured residual moveouts (or traveltime errors) into azimuthally dependent normal moveout (NMO) velocities. Then we apply a digital Fourier transform to convert the NMO velocities into azimuthal wavenumber domain, in order to obtain the effective HTI model parameters: vertical time, vertical compression velocity, Thomsen parameter delta and the azimuth of the medium axis of symmetry. The method also provides a reliability criterion of the HTI assumption. The criterion shows whether the medium possesses the HTI type of symmetry, or whether the azimuthal dependence of the residual traveltime indicates to a more complex azimuthal anisotropy. The effective model used in this approach is defined for a 1D structure with a set of HTI, VTI and isotropic layers (with at least one HTI layer). We describe and analyse the reduction of a multi‐layer structure into an equivalent effective HTI model. The equivalent model yields the same NMO velocity and the same offset azimuth on the Earth's surface as the original layered structure, for any azimuth of the phase velocity. The effective model approximates the kinematics of an HTI/VTI layered structure using only a few parameters. Under the hyperbolic approximation, the proposed effective model is exact.     

接收函数的克希霍夫２D偏移方法

本文将地震反射资料成像的Kirchhoff偏移方法引入到接收函数成像研究，提出了一种接收函数的Kirchhoff偏移方法，以适应介质速度的横向变化，提高接收函数成像的精度和分辨率. 模型检验表明，与传统的水平分层的共转换点偏移叠加方法相比，Kirchhoff偏移方法能够实现转换波的有效归位，消除水平分层共转换点偏移叠加造成的假象. 一个很重要的现象是，倾斜或弯曲界面的成像明显受控于远震的入射方向，其成像精度的提高有赖于不同方向接收函数的联合成像.