微地震定位的加权弹性波干涉成像法（英文）

震源定位是微地震监测关键技术之一。本文提出用于微地震定位的弹性波和加权弹性波(WEW)干涉成像方法。该方法在保证定位精度的同时,还可避免震源假象。通过各向同性水平层介质状模型的数值试验,初步表明该方法可适应低信噪比微震信号、速度随机扰动、较稀疏的检波器分布等情况,并在速度模型存在一定的系统误差时也仍保持较高的定位精度。由于干涉成像方法不需要进行初至拾取,定位效率相对传统走时方法也得到了提高。采用二维断层模型试算Nnumerical results of using a two-dimensional fault model,表明方法还能实现多震源定位,且比逆时成像有更高的定位精度。     

震源逆时定位的成像条件分析

震源逆时定位采用不同的成像条件可以实现自动定位,而不同成像条件的特性与应用条件是该技术值得研究的问题.本文结合波场的逆时延拓特征与成像条件的物理含义,明确了波场的逆时延拓特征是构建成像条件的基础,指出最大振幅成像条件可以同时确定震源位置与激发时间,而相关型成像条件的定位精度要高于最大振幅成像条件且有可能突破绕射极限的控制,其中多维互相关成像条件适用于稀疏检波器分布的情况.针对自相关定位剖面中浅部强振幅假象提出了改进自相关成像条件.通过不同的模型测试,验证了本文关于不同成像条件的结论及提出的改进自相关成像条件的有效性.     

衰减干涉假象的海洋一次波与多次波同时成像方法

海水与空气间的强波阻抗差使得海洋地震资料普遍发育自由表面相关多次波,如何利用好多次波所携带的有效信息已成为提高海洋地震资料成像品质的新突破点.基于面炮偏移的一次波与多次波同时成像方法能够避免多次波预测精度的影响,但是,正向传播的震源子波与反向延拓的自由表面相关多次波所产生的干涉假象严重制约了该技术的应用,本文提出了一种基于单程波偏移算子,可在成像域压制干涉假象的一次波与多次波同时成像方法.其中包含了三个步骤:第一,传统单程波偏移成像方法中的震源子波替换为一次波、多次波与震源子波,初始上行延拓波场为一次波与多次波,基于单程波算子的波场延拓与互相关成像条件的应用得到包含干涉假象的一次波与多次波同时成像;第二,以子波为震源,自由表面相关多次波为记录,按照传统单程波偏移成像方法得到干涉假象;第三,基于最小二乘匹配滤波算法,将第一步的成像结果与第二步的干涉假象进行匹配相减,得到干涉假象衰减后的一次波与多次波同时成像,避开了由于实际资料子波无法准确提取而造成一次波与多次波对成像能量级的不一致性.Sigsbee2B模型测试验证了本方法的有效性,并在我国某探区深海实际资料处理中得到了成功应用,深层基底得到了清晰刻画,并且照明均衡度明显改善.     

单程波角度域内压制多次波偏移假象

多次波偏移中的假象主要来自于不同地震事件之间的互相关,由于这种互相关满足成像条件,很难直接在偏移过程中去除.但是对于准确的速度模型,真实的成像结果在角度域内应该是平直的.根据这个判断准则,可以在角度域内移除多次波偏移中的假象.本文以数据自相关偏移为例,提出了在单程波多次波偏移中移除假象的主要流程:首先在在单程波偏移过程中高效地提取角度域共成像点道集,然后对角度域共成像点道集应用高分辨率的抛物线型Radon变换,用合适的切除函数处理后,反变换回到角度域,最后叠加各个角度成分,得到偏移结果.Marmousi模型的合成数据测试表明,这种方法可以很好地压制多次波偏移过程中产生的假象,有效地提高成像结果的信噪比.     

地震干涉技术的三维震源定位方法

快速、精确地进行震源定位是地震学的基础性研究课题之一.为了满足目前相关地震工作的需要,找到一种与实际情况相适应的有效震源定位方法具有切实意义.本文研究了干涉成像方法,根据地下介质构造以及对应传播速度,利用干涉的方法对震源位置进行成像.这种算法对地震记录的要求较低,不需要精确的初至时间,适应于多震源延时激发且信噪比较低的微震定位.基于二维干涉定位我们得到了三维干涉定位方法,确定了对应的成像理论.首先在二维水平层状介质模型中测试,定位结果趋近模拟位置.之后建立了三维均匀介质模型,进行三维弹性波场的数值模拟,对接收到的数据进行互相关运算,利用结果进行干涉成像,可以得到较为精确的水平位置,再结合二维模型中的方法确定深度,定位结果与模拟震源相符.最后根据三维模型下的微震数据同时定位出多个微震震源,证实了算法在微震定位中切实有效.     

三维复杂速度模型的交切法地震定位

地震定位是地震监测与减灾研究重要基础.基于均匀或横向均匀介质模型,利用震源轨迹确定震源位置的交切法具有稳健和效率高的优点,但定位精度较低,特别是震源深度.为提高震源定位精度,我们提出适用于三维复杂速度模型的地震定位交切法.将地壳速度模型由均匀或横向均匀介质模型扩展为三维复杂速度模型;均匀或横向均匀介质模型对应的原假设为球面或双曲面的震源轨迹通过最小走时树射线追踪技术予以确定.确定震源位置的震源轨迹以到时差作为约束条件;将震源定位于震源轨迹交汇最密集的点处,即总的到时差残差(RDT)最小的点处.定位结果的不确定性可通过RDT值较小节点的空间分布予以定性表示.考察了准确速度模型、扰动速度模型、扰动观测到时及地震在台网外等4种情况下改进方法的地震定位效果,结果表明改进的交切法可用于三维复杂速度模型的地震定位;综合利用P波与S波的到时差信息,可明显改善震源位置约束;使用多条震源轨迹进行定位,有助于减少由随机因素导致的定位误差.     

利用微震数据对震源下方构造直接成像

现有的微震记录直接成像方法是将微震记录既当作入射记录,也当作散射记录,从而实现偏移成像.但此方法并不能突出透射波所携带的来自震源下方的深层散射波信息.本文在假设已知微震位置与子波的前提下,提出了对微震下方构造进行逆时偏移的成像方法.该方法类似于常规的逆时偏移,只是震源位置在地下.这使得在成像时,地下更深部的入射波场相比震源在地表时会更为精确,因此能够获得更加准确的成像结果.该方法会给成像结果带来一种尾波高频干扰：地下的震源发出的上行波与上方介质作用后,所产生的多级散射波会干扰反传波场.对此,在成像过程中,对入射场和散射场都进行左右行波分离,以压制该噪声.而在子波信息未知,无法重构入射场时,使用了激发时间成像条件,也能够实现同等效果的偏移成像,且不会出现尾波高频干扰.利用数值实验验证了本文方法的有效性.     

基于机器学习的时间反转散射体检测方法

地下小尺度散射体的检测和识别对于提高地震勘探的分辨率具有重要意义,目前业界普遍采用绕射波分离及成像方法检测地下散射体,而绕射波成像的质量主要取决于绕射波和反射波波场分离的程度.本文将被动源震源定位问题中常用的时间反转原理引入到地下散射体检测中,首先通过分析被动源和主动源模型反传波场的聚焦状态,验证了时间反转原理应用于地下散射体检测中的可行性;并引入机器学习中的朴素贝叶斯分类算法,给出适用于时间反转散射体检测的分类算法框架,计算模型中每个点成为散射体的概率,最终检测出地下散射体最有可能存在的位置.散射体模型和Sigsbee2a模型的试算结果证实了本文方法在不需对反射波和绕射波分离的情况下,即可实现对地下散射体的检测和定位,同时由于考虑了多次散射的影响,检测结果能准确反映地下散射体的位置.     

浅谈地震剖面的假象识别

假象识别是正确解释地震剖面的前提,也是描述地震成像保真度(精准度)的主要标准之一.本文通过分析反射地震剖面实例,对几种常见的、易被误解的地震成像假象的特征进行了分类阐述,提出基于成因识别地震成像假象的思路.从地震剖面成像过程来看,假象的成因包括信号误判、成像畸变和波速模型误差这三个主要因素.许多不易被识别的假象起源于地震数据处理成像过程中对信号的误判,犹如“张冠李戴”;成像畸变假象的根源包括成像照明度、资料频宽和方法假设等方面的缺陷,造成抹痕等成像结果畸变假象;当地震波速度模型误差较大时,地震成像结果不仅会出现成像位置错误,还可能在波阻抗不连续点出现散射拖尾假象.因此,衡量地震成像精准度的标准应包括成像结果的分辨率、位置准确度和假象识别三个要素.这些要素相互影响,因此应该根据研究目标和实际情况,综合评判地震成像中假象的影响.     

基于Hilbert变换的全波场分离逆时偏移成像

逆时偏移方法利用双程波算子模拟波场的正向和反向传播,通常采用互相关成像条件获得偏移剖面,是一种高精度的成像方法.但是传统的互相关成像条件会在偏移结果中产生低频噪声;此外,如果偏移速度中存在剧烈速度变化还可能进一步产生偏移假象.为了提高逆时偏移的成像质量,可在成像过程中先对震源波场和检波点波场分别进行波场分离,然后选择合适的波场成分进行互相关成像.本文基于Hilbert变换,推导了可在偏移过程中进行上下行和左右行波场分离的高效波场分离公式以及相应的成像条件,结合Sigsbee 2B合成数据,给出了不同波场成分的互相关成像结果.数值算例结果表明,采用本文提出的高效波场分离算法以及合理的波场成分互相关成像条件可以获得高信噪比的成像结果.     

矿山微地震全波自动定位的层析成像方法(英文)

针对在矿山微地震监测过程中纵横波及其传播速度难以确定的难点,在球坐标系中以波动方程为基础,推导出了矿山微地震全波自动定位的层析成像的计算公式,并给出了参数选择准则,藉此可以获得微地震成像能量最大值及其对应参数。通过判断能量最大值在风险区内的位置,可以将风险区内外的微地震事件区分出来。对于能量最大值位于风险区域内的微地震事件,其震源位置和震动时间以及传播速度与能量最大值对应的坐标参数相同,能量最大值对应于震源函数相对强度;当能量最大值位于风险区域边界上时,微地震事件不在风险区域范围之内。理论模型试算和矿山实际微地震资料的应用表明:层析成像方法无需纵横波识别和传播速度假定,只要给定事故风险区域范围及其传播速度范围,便可完成微地震事件定位,是一种全波全自动定位方法,具有进一步研究价值。     

基于波动方程的微地震震源位置、震源时间及VTI介质各向异性参数联合反演

对于非常规油气开发,水力压裂监控的效果取决于对微地震事件的分析、解释.准确的微地震震源位置是关乎施工成败的重要因素.微地震震源位置的准确性与多个参数相关,其不仅依赖于微地震事件的激发时间,同时也依赖于储层介质参数信息,因此进行微地震震源位置、震源时间、储层介质参数的联合反演尤为重要.页岩气储层通常表现出较强的各向异性,...     

Comparison of surface and borehole locations of induced seismicity

Monitoring of induced microseismic events has become an important tool in hydraulic fracture diagnostics and understanding fractured reservoirs in general. We compare microseismic event and their uncertainties using data sets obtained with surface and downhole arrays of receivers. We first model the uncertainties to understand the effect of different acquisition geometries on location accuracy. For a vertical array of receivers in a single monitoring borehole, we find that the largest part of the final location uncertainty is related to estimation of the backazimuth. This is followed by uncertainty in the vertical position and radial distance from the receivers. For surface monitoring, the largest uncertainty lies in the vertical position due to the use of only a single phase (usually P‐wave) in the estimation of the event location. In surface monitoring results, lateral positions are estimated robustly and are not sensitive to the velocity model. In this case study, we compare event location solutions from two catalogues of microseismic events; one from a downhole array and the second from a surface array of 1C geophone. Our results show that origin time can be reliably used to find matching events between the downhole and surface catalogues. The locations of the corresponding events display a systematic shift consistent with a poorly calibrated velocity model for downhole dataset. For this case study, locations derived from surface monitoring have less scatter in both vertical and horizontal directions.     

地面与井中观测条件下的微地震干涉逆时定位算法

勘探和开发非常规油气藏已经成为国际油气工业界的新热点.由于这类油藏具有低渗透率的特点,开采过程中往往需要多级压裂形成能够使烃类自由流动的裂隙.通过定位分析压裂过程中诱导的微地震震源能够帮助人们刻画裂缝属性(走向、密度等),评价压裂效果,分析断裂模式,推定震源机制等.微地震定位可以采用波动方程逆时聚焦方法实现.由于微地震数据信噪比低,加之速度模型不准确、稀疏观测等诸多因素使得定位的精度大打折扣.本文将波动方程逆时聚焦定位原理与干涉"成像"原理相结合,探讨多源微地震信号的干涉逆时定位算法,尤其扩展该算法到三维多分量地面、井中以及井地联合观测条件下.通过理论合成数据与实际射孔资料的数值试验,展示了该微地震定位算法的精度优势与抗噪特点,并指出波场聚焦微地震定位方法在实际应用中的制约因素与应对策略.     

A review of the microseismic focal mechanism research

Reservoir reconstructions implemented in unconventional oil and gas exploration usually adopt hydraulic fracturing techniques to inject high-pressure fluid into the reservoir and change its pore-fracture connection structure to enhance production. Hydraulic fracturing changes the reservoir stress and causes the rocks to crack, thus generating microseismic events.One important component of microseismic research is the source mechanism inversion. Through the research on the microseismic focal mechanism, information on the source mechanisms and in-situ stress status variations can be quantitatively revealed to effectively optimize the reservoir reconstruction design for increasing production. This paper reviews the recent progress in hydraulic fracturing induced microseismic focal mechanism research. We summarize their main principles and provide a detailed introduction of the research advances in source modeling, microseismic data synthesis, and focal mechanism inversion. We also discuss the challenges and limitations in the current microseismic focal mechanism research and propose prospects for future research ideas and directions.     

Assessment of focal mechanisms of microseismic events computed from two three‐component receivers: application to the Arkema‐Vauvert field (France)

We have developed a method that enables computing double‐couple focal mechanisms with only a few sensors. This method is based on a non‐linear inversion of the P, Sv and Sh amplitudes of microseismic events recorded on a set of sensors. The information brought by the focal mechanism enables determining the geometry of the rupture on the associated geological structure. It also provides a better estimate of the conventional source parameters. Full analysis has been performed on a data set of 15 microseismic events recorded in the brine production field of Vauvert. The microseismic monitoring network consisted of two permanent tools and one temporary borehole string. The majority of the focal mechanisms computed from both permanent tools are similar to those computed from the whole network. This result indicates that the double‐couple focal mechanism determination is reliable for both permanent 3C receivers in this field.     

Consistency of stress state,locations and source mechanisms of events induced by hydraulic fracturing: downhole monitoring

We present results of processed microseismic events induced by hydraulic fracturing and detected using dual downhole monitoring arrays. The results provide valuable insight into hydraulic fracturing. For our study, we detected and located microseismic events and determined their magnitudes, source mechanisms and inverted stress field orientation. Event locations formed a distinct linear trend above the stimulated intervals. Source mechanisms were only computed for high‐quality events detected on a sufficient number of receivers. All the detected source mechanisms were dip‐slip mechanisms with steep and nearly horizontal nodal planes. The source mechanisms represented shear events and the non‐double‐couple components were very small. Such small, non‐double‐couple components are consistent with a noise level in the data and velocity model uncertainties. Strikes of inverted mechanisms corresponding to the nearly vertical fault plane are (within the error of measurements) identical with the strike of the location trend. Ambient principal stress directions were inverted from the source mechanisms. The least principal stress, σ₃, was determined perpendicular to the strike of the trend of the locations, indicating that the hydraulic fracture propagated in the direction of maximum horizontal stress. Our analysis indicated that the source mechanisms observed using downhole instruments are consistent with the source mechanisms observed in microseismic monitoring arrays in other locations. Furthermore, the orientation of the inverted principal components of the ambient stress field is in agreement with the orientation of the known regional stress, implying that microseismic events induced by hydraulic fracturing are controlled by the regional stress field.     

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.