由VSP反射波旅行时重建各向异性层速度结构

本文提出-种利用有偏VSP资料反射波旅行时信息重建椭圆各向异性介质中水平向与垂直向速度的方法。其中,地下介质假定为层状椭圆各向异性介质。反射波旅行时间采用射线追踪理论及几何关系计算得到,反演中的线性方程组采用奇异值分解(SVD)技术进行求解。 方法检测时,我们对各向同性介质及椭圆各向异胜介质情况下有限差分法正演模拟的深井有偏移距VSP地震资料分别进行各向同性和各向异性方法反演成像。结果表明,本文所述方法较之各向同性介质模型反演方法对介质类型有很好的适用性,同时也说明了本方法的司行性。最后,我们分别介绍了对实际有偏VSP资料反演得到的地下介质的速度结构图像。     

工程VSP与地震CT联合探测方法及其在岩土工程的应用

垂直地震剖面（Vertical Seismic Profile,简称VSP）和层析成像（Computerized Tomography,简称CT）方法,不仅能够使用统一的数学方法描述（如射线理论）,并且在其勘探实践活动中完全可融为一体而成为优化技术组合下的高分辨工程物探方法.特别是在井间地震CT数据采集现场施工中,充分利用VSP和井间CT数据采集方式的兼容性和优化观测系统参数设计,几乎可以不增加野外工作费用,就能够同时获取井间地震CT数据和施测孔的逆向VSP数据体.如井中排列多点激发,地面各接收点构成多偏移距逆向VSP道集,并可组成关于孔中各炮点的变偏移距逆向VSP道集.这种高分辨技术组合在近地表大中型岩土洞室工程测试环境中更易于实现.本文简述了工程VSP与地震CT数据一体化观测系统,介绍了联合速度反演初始模型的建立与成像处理流程,给出VSP和CT联合成像方法应用于三峡大坝工程物探检测中的一个实例简介,最后得出相关结论并提出建议.     

VSP上下行反射波联合成像方法研究

VSP资料上下行波场发育丰富.本文在分析VSP直达波、上行反射波、下行反射波传播路径及其照明范围的基础上,指出了常规VSP波动方程偏移方法缺陷,进而通过修改波场延拓方式,提出了上下行反射波联合成像方法,并在高频近似下分析了该方法的成像原理.该方法不需要进行VSP上下行反射波场分离,能够同时对VSP资料中的一次反射波、自由表面多次波、层间多次波进行成像,比常规成像剖面具有更宽的成像范围和更好的成像效果.该方法能够对下行一次反射波进行成像,从而可以实现常规偏移方法难以处理的高陡倾角构造成像.模拟资料和实际资料处理证明了本文方法的正确性.     

基于伪谱法的VSP逆时偏移及其应用研究

逆时偏移被认为是对地下复杂构造进行成像的精确偏移方法,尤其是能够有效地对回转波、绕射波、多次波等各种波动现象进行成像.近几年来随着并行计算机和存储设备的快速发展,逆时偏移方法备受关注.本文采用伪谱法实现了VSP逆时偏移,该方法不仅实施简便,而且计算效率高,精度好.并运用反周期扩展法来消除伪谱法中特殊的周期性边界效应问题.对VSP绕射点模型进行试算,分析了因覆盖次数不足在近井区产生的假象问题.对地堑模型和半圆隆起模型也获得了较好的VSP逆时偏移成像效果.并分别对VSP全波波场及分离出的上行波场进行了逆时偏移成像,可明显发现直达波在炮点和检波点位置处收敛成像,也产生了很强的成像噪声.最后对某地区实际观测的VSP资料进行了逆时偏移成像,并与Kirchhoff法VSP偏移结果和地面地震偏移结果进行了对比,显示了VSP逆时偏移在近井区成像上的优势.     

非零偏VSP弹性波叠前逆时深度偏移技术探讨

非零偏VSP地震资料是一种多分量资料,处理非零偏VSP资料,弹性波叠前逆时深度偏移技术无疑是最适合的处理技术.本文从二维各向同性介质的弹性波波动方程出发,研究了对非零偏VSP资料进行叠前逆时深度偏移的偏移算法,讨论了逆时传播过程中的边值问题和数值频散问题及其相应的解决方案;采用求解程函方程计算得到地下各点的地震波初至时间作为成像时间,实现了非零偏VSP资料的叠前逆时深度偏移.最后进行了模型试算和非零偏VSP地震资料的试处理,结果表明该方法不受地层倾角限制,较适用于高陡构造地区或介质横向速度变化较大地区的非零偏VSP地震资料处理.     

局域化相空间中的VSP偏移成像方法(英文)

对VSP资料进行偏移成像可提高井附近地下结构的成像分辨率。本文给出了一种基于局域化相空间波场分解的VSP偏移成像方法。此方法采用了基于Gabor-Daubechies紧标架的延拓算子(G-D延拓算子)及其高频渐近形式对相空间波场进行延拓;基于局部平面假设,提出了一种局部角度域相关成像条件。合成和实际VSP资料的偏移成像结果表明,在满足渐近展开的条件下利用G-D延拓算子的高频近似式能够有效的减少计算时间;采用局部角度域相关成像条件能够在不增加计算量的同时,有效减弱VSP成像剖面上的偏移假象。     

Migration scheme for imaging offset VSP data within local phase space

The imaging of offset VSP data in local phase space can improve the image of the subsurface structure near the well. In this paper, we present a migration scheme for imaging VSP data in a local phase space, which uses the Gabor-Daubechies tight framebased extrapolator (G-D extrapolator) and its high-frequency asymptotic expansion to extrapolate wavefields and also delineates an improved correlation imaging condition in the local angle domain. The results for migrating synthetic and real VSP data demonstrate that the application of the high-frequency G-D extrapolator asymptotic expansion can effectively decrease computational complexity. The local angle domain correlation imaging condition can be used to weaken migration artifacts without increasing computation.     

Inversion for elliptically anisotropic velocity using VSP reflection traveltimes

This paper presents a traveltime inversion approach, using the reflection traveltimes from offset VSP data, to reconstruct the horizontal and vertical velocities for stratified anisotropic media. The inverse problem is reduced to a set of linear equations, and solved by the singular value decomposition (SVD) technique. The validity of this inversion scheme is verified using two sets of synthetic data simulated using a finite‐difference method, one for an isotropic model and the other for an elliptically anisotropic model. The inversion result demonstrates that our anisotropic velocity inversion scheme may be applied to both isotropic and anisotropic media. The method is finally applied to a real offset VSP data set, acquired in an oilfield in northwestern China.     

Azimuthal anisotropy analysis of walkaround vertical seismic profiling vertical seismic profiling: a case study from Saudi Arabia

Understanding fracture orientations is important for optimal field development of fractured reservoirs because fractures can act as conduits for fluid flow. This is especially true for unconventional reservoirs (e.g., tight gas sands and shale gas). Using walkaround Vertical Seismic Profiling (VSP) technology presents a unique opportunity to identify seismic azimuthal anisotropy for use in mapping potential fracture zones and their orientation around a borehole. Saudi Aramco recently completed the acquisition, processing and analysis of a walkaround VSP survey through an unconventional tight gas sand reservoir to help characterize fractures. In this paper, we present the results of the seismic azimuthal anisotropy analysis using seismic traveltime, shear‐wave splitting and amplitude attenuation. The azimuthal anisotropy results are compared to the fracture orientations derived from dipole sonic and image logs. The image log interpretation suggests that an orthorhombic fracture system is present. VSP data show that the P‐wave traveltime anisotropy direction is NE to SW. This is consistent with the cemented fractures from the image log interpretation. The seismic amplitude attenuation anisotropy direction is NW to SE. This is consistent with one of the two orientations obtained using transverse to radial amplitude ratio analysis, with the dipole sonic and with open fracture directions interpreted from image log data.     

Estimation of effective source signatures from marine VSP data1

We present a simple method for estimating an effective source wavelet from the first arrival in marine vertical seismic profiling (VSP) data. The method, which utilizes the free-space Green's function of the Helmholz equation, is simple and very computer efficient. We show examples from synthetic and real offset and walkaway VSP data. In the synthetic examples, we show that data modelled with the estimated wavelet give small residuals when subtracted from the reference data. In the real data examples, we show that when modelling with the wavelet estimated from the real data, in a smooth macromodel, we obtain a good fit between the first arrivals in the real and modelled data.     

Monte-Carlo Bayesian look-ahead inversion of walkaway vertical seismic profiles

We describe a method to invert a walkaway vertical seismic profile (VSP) and predict elastic properties (P‐wave velocity, S‐wave velocity and density) in a layered model looking ahead of the deepest receiver. Starting from Bayes's rule, we define a posterior distribution of layered models that combines prior information (on the overall variability of and correlations among the elastic properties observed in well logs) with information provided by the VSP data. This posterior distribution of layered models is sampled by a Monte‐Carlo method. The sampled layered models agree with prior information and fit the VSP data, and their overall variability defines the uncertainty in the predicted elastic properties. We apply this technique first to a zero‐offset VSP data set, and show that uncertainty in the long‐wavelength P‐wave velocity structure results in a sizable uncertainty in the predicted elastic properties. We then use walkaway VSP data, which contain information on the long‐wavelength P‐wave velocity (in the reflection moveout) and on S‐wave velocity and density contrasts (in the change of reflectivity with offset). The uncertainty of the look‐ahead prediction is considerably decreased compared with the zero‐offset VSP, and the predicted elastic properties are in good agreement with well‐log measurements.     

Imaging pre‐existing natural fractures using microseismic data

In hydraulic fracturing treatments, locating not only hydraulic fractures but also any pre‐existing natural fractures and faults in a subsurface reservoir is very important. Hydraulic fractures can be tracked by locating microseismic events, but to identify the locations of natural fractures, an additional technique is required. In this paper, we present a method to image pre‐existing fractures and faults near a borehole with virtual reverse vertical seismic profiling data or virtual single‐well profiling data (limited to seismic reflection data) created from microseismic monitoring using seismic interferometry. The virtual source data contain reflections from natural fractures and faults, and these features can be imaged by applying migration to the virtual source data. However, the imaging zone of fractures in the proposed method is strongly dependent on the geographic extent of the microseismic events and the location and direction of the fracture. To verify our method, we produced virtual reverse vertical seismic profiling and single‐well profiling data from synthetic microseismic data and compared them with data from real sources in the same relative position as the virtual sources. The results show that the reflection travel times from the fractures in the virtual source data agree well with travel times in the real‐source data. By applying pre‐stack depth migration to the virtual source data, images of the natural fractures were obtained with accurate locations. However, the migrated section of the single‐well profiling data with both real and virtual sources contained spurious fracture images on the opposite side of the borehole. In the case of virtual single‐well profiling data, we could produce correct migration images of fractures by adopting directional redatuming for which the occurrence region of microseismic events is divided into several subdivisions, and fractures located only on the opposite side of the borehole are imaged for each subdivision.     

零偏VSP资料波阻抗反演方法研究(英文)

VSP资料钻前预测的关键在于高精度的波阻抗反演,本文针对VSP资料高分辨率、高信噪比以及能精确地分离出上、下行波的特点,提出了一种利用VSP资料进行井底以下钻头前方地层波阻抗反演的方法。该方法首先对VSP走廊叠加记录采用非线性迭代反演方法反演地下地层的波阻抗;通过在迭代过程中不断修改阻尼因子,以及引入预条件共轭梯度法求解方程组,增强了解的稳定性和收敛速度。理论模型与实际资料的处理结果表明该方法具有较好的效果,并在VSP资料钻前预测研究中具有良好的应用前景。     

利用零偏移距VSP资料在小波域计算介质Q值

讨论了地震子波为一般零相位子波情况下,利用零偏移距垂直地震剖面(VSP)资料在时-频域计算Q值方法．以Morlet小波为基本小波,基于单程波传播理论, 在地震子波为一般的零相位子波情况下,推导出了在时-频域计算Q值的公式．通过对横坐标作恰当的非线性变换后,该公式在形式上与地震子波为脉冲时的计算公式类似．文中采用VSP正演记录,验证了本文提出的方法的正确性．文中还讨论了在时-频域恰当地选择有效频带,降低反射波对Q值计算结果影响的方法．     

CDP mapping in tilted transversely isotropic (TTI) media. Part I: Method and effectiveness

Transverse isotropy with a tilted axis of symmetry (TTI) causes image distortion if isotropic models are assumed during data processing. A simple anisotropic migration approach needs long computational times and is sensitive to the signal-to-noise ratio. This paper presents an efficient, general approach to common-depth-point (CDP) mapping to image the subsurface in TTI media from qP-wave seismic data by adding anisotropic and dip parameters to the velocity model. The method consists of three steps: (i) calculating traveltimes and positions of the CDP points; (ii) determining CDP trajectories; (iii) CDP imaging. A crucial step is the rapid computation of traveltimes and raypaths in the TTI media, which is achieved by the Fermat method, specially adapted for anisotropic layered media. The algorithm can image the subsurface of a given model quickly and accurately, and is suitable for application to a bending reflector. The effectiveness of the method is demonstrated by comparing the raypaths, the traveltimes and the results of CDP mapping, when assuming isotropic media, transversely isotropic media with a vertical axis of symmetry (TIV), and TTI media.     

基于改进线性Radon变换的井孔地震上下行波场分离方法

反射波场分离是井孔地震资料处理中极其重要的一个环节,波场分离的质量直接影响成像结果的精度.不管是VSP还是井间地震资料,其反射波时距曲线都近似直线型,根据这一特征,本文提出一种改进的线性Radon变换方法来进行井孔资料的反射波上下行波场分离.该方法基于频率域线性Radon变换,通过引入一个新的变量λ来消除变换算子对频率的依赖性,避免了求取每一频率分量对应的不同变换算子,显著降低了计算成本;文中在求解该方法对应的最小二乘问题时,引入了发展较为成熟的高分辨率Radon变换技术来进一步提高波场分离的精度.采用本文方法进行井孔地震资料的上下行波场分离可以在保证分离精度的前提下有效地提高计算效率.根据上下行波在λ-f域内分布的特殊性,设计简单的滤波算子就可实现上下行波场的分离.最后通过合成数据试算以及实际资料处理（VSP数据和井间地震数据）验证了该方法的可行性和有效性.     

陆上纵波源VSP资料中的纯横波

常规陆上VSP(Vertical Seismic Profiling)勘探普遍采用纵波震源激发,三分量检波器接收,主要利用的是纵波和转换横波信息。已有的研究表明,炸药震源在井下激发、可控震源在地面垂向振动,均会产生较强的纯纵波和一定强度的纯横波;泊松比差别较大的分界面有利于形成较强的透射转换横波。本文通过对激发形成的纯横波和下行转换形成的横波进行对比分析,认为纯横波的主频往往低于纯纵波的主频,而下行转换横波的主频通常接近纵波的主频。本文分别对两个陆上纵波源零偏和非零偏VSP资料进行分析,结果表明这些资料中普遍存在纯横波,只是横波的强弱存在不同程度的变化。利用纵波源零偏VSP资料,可以获得横波速度信。最后对VSP纵波和横波联合应用前景进行了分析,应该充分利用纵波源VSP资料中的横波信息。     

Verification of correctness of using real part of complex root as Rayleigh-wave phase velocity with synthetic data

High-frequency (≥ 2 Hz) Rayleigh-wave phase velocities have been utilized to determine shear-wave velocities in near-surface geophysics since the early 1980s. One of the key steps is to calculate theoretical dispersion curves of an earth model. When the earth model contains a low-velocity half-space, however, some roots of the dispersion equation turn out to be complex numbers, which makes phase velocities disappear at some frequencies. When encountering this situation, the common practice is to append an additional high velocity layer as the half-space to the model to make the roots real or use the real parts of complex roots as Rayleigh-wave phase velocities. The correctness of the first method has been verified. The correctness of the second method, however, remains to be unproved. We use synthetic data generated by numerical modeling of the wave equation to verify the correctness of the second method. In this paper, we firstly discuss the reasons that only complex numbers of the dispersion equation exist at some frequencies when an earth model contains a low velocity half-space. Then we discuss how the nearest offset affects a synthetic model and recommend an optimal nearest offset in generating synthetic data that are close to real-world situations. Several synthetic models are used to verify correctness of using real parts of complex roots as Rayleigh-wave phase velocities when an earth model contains a low velocity layer as the half-space.     

A methodology to estimate the maximum offset and reflection imaging radius for a 2D/3D vertical seismic profiling survey

We have developed a straightforward and ray based methodology to estimate both the maximum offset and reflection imaging radius for multi‐layered velocity models, which can be used for a 2D/3D VSP survey design. Through numerical examples, we demonstrate that the presence of a high‐velocity layer above a target zone significantly reduces the maximum offset and reflection imaging radius. Our numerical examples also show that including in a migration VSP data acquired beyond a recommended maximum offset, radically degrades the quality of the final VSP image. In addition, unlike the conventional straight‐line based approximation that often produces an incorrect large reflection imaging radius, our methodology predicts the VSP imaging radius with more accuracy than does the conventional approximation.     

由宽角反射地震资料重建壳幔反射结构的相似性剖面

针对人工源宽角地震测深中炮点与接收点稀疏的特点,利用几何散射理论进行壳幔散射体的相似性剖面成像,利用互易性原理计算散射体相似性成像的时间条件,研究基于宽角反射地震资料重建壳幔反射结构的相似性成图方法. 其中,成像点的时间采用快速、高精度的程函方程求解技术. 利用该方法处理东南陆缘区宽角反射剖面实际资料,结果表明,较之壳幔反射结构的CDP成图技术,相似性成图方法具有提高反射同相轴横向连续性的能力.