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《岩土力学》2021,(2)
后压浆技术已应用于珊瑚岛礁基础设施建设中,但有关钙质砂后压浆桩水平承载性状的研究较少。针对钙质砂地基中后压浆桩的水平承载问题,通过室内模型试验手段对钙质砂未压浆桩与后压浆桩的水平承载规律进行了研究,探究了后压浆对钙质砂桩基水平承载性状的影响,并通过开挖后压浆单桩,分析了注入的水泥浆液在钙质砂中的渗扩情况。结果表明,钙质砂后压浆桩的水平临界荷载和水平极限荷载较同条件下未压浆桩均有显著的提高,且变形控制能力优于同条件下未压浆桩;未压浆桩与后压浆桩的桩侧地基土水平抗力系数的比例系数m值随桩顶侧向位移的增加逐渐趋于一致,且桩身弯矩和桩侧土压力都主要集中在上部桩身和土层中;桩基水平承载力受上部土体的影响较大,桩侧压浆通过改善上部土层的物理力学性质能有效提高桩基抵抗水平荷载的能力。此外,通过开挖分析得出桩侧注入的水泥浆液沿着桩身上返、下渗并横向扩散与钙质砂颗粒形成了水泥土加固体的稳定结构,进而提升了钙质砂桩基水平承载性能。 相似文献
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钻孔灌注桩压浆后的承载性能研究 总被引：15，自引：0，他引：15
根据某大厦及邻近场地试桩的静载荷及桩身应力测试结果,对压浆后桩的承载性能进行了深入地分析。未压浆桩的荷载-沉降关系符合双曲线函数,而压浆后桩的荷载-沉降关系符合幂函数。在极限状态时桩端阻力占总荷载比例为6.4 %～ 18.4 %,桩侧阻力占总荷载比例为81.6 %～93.6 %,且随着桩顶荷载的增加,桩端阻力所占比例快速增长。根据极限承载力外推值, 桩侧、桩端压浆的极限承载力提高幅度为89.85 %～147.81 %, 桩端压浆的极限承载力提高幅度为30.08 %～81.78 %。根据灰色关联分析,无论哪种压浆工艺,起主要作用的是压浆总量,且桩端压浆的影响大于桩侧压浆。 相似文献
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钻孔后压浆技术在苏通大桥基础工程中的应用 总被引：1，自引：0，他引：1
钻孔灌注桩后压浆技术,使水泥浆液在高压下渗透、充填和挤密,与沉渣、泥皮、桩周和桩端土体发生物理化学固结,增大了土体和桩端的强度,改变了桩的受力类型,提高了桩侧摩阻力和端阻力,从而提高了单桩的承载力。在苏通大桥超长大直径桩中应用了桩底后压浆技术。通过试桩静载试验,决定在工程施工中采用U型压浆管方案。试桩结果表明,压浆后极限承载力测试值是压浆前的1.48～2.0倍,压浆后端阻力是压浆前的2.46～7.21倍,表明利用后压浆技术达到了节约工程投资、提高工程施工质量及可靠性的目的,并产生了较大的技术经济效益和良好的社会环境效益,这将促进我国公路桥梁建设的桩基技术迈向一个新台阶。 相似文献
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珊瑚礁灰岩层中桩基承载特性的研究是岩土工程的热点问题。基于某跨海大桥工程开展的珊瑚礁灰岩层中桩端后压浆桩现场静载荷试验,对比分析了压浆前后的实测结果,研究了桩端后压浆的预压作用对桩阻力的影响,并在桩端后压浆试验结果分析的基础上,进一步研究了后压浆桩增强效应作用机制。结果表明,桩端后压浆技术可应用于珊瑚礁灰岩地层中,能有效地提高桩基承载力和减小沉降量;钻孔取芯试验明确了压力浆液在桩端以下一定范围内的分布情况,并证实了压力浆液对珊瑚礁灰岩的孔隙有充填作用;桩端压浆后,在桩端未能消散的压力产生负摩阻力,使负摩阻力在竖向荷载作用下提前发挥,并增大了压浆桩的侧阻力。此外,桩端后压浆的预压作用提高了桩端阻力,并减小了桩端位移,改善了桩基的承载性状。 相似文献
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通过对桩侧和桩底后压浆,可大幅度提高钻孔灌注桩单桩承载力.应用桩-土理论分析了后压浆中浆液对土体及桩体的作用,并从分析影响桩基承载力的因素出发,研究了后压浆的作用机理.在渗透率小的地层中后压浆以压密注浆为主,在渗透率大的地层中后压浆以渗透注浆为主.为避免过分压裂土层,在压浆过程中应控制灌浆压力.压浆量是影响后压浆质量和提高单桩承载力的关键因素之一. 相似文献
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苏通长江大桥北引桥二期试桩试验研究 总被引：1，自引：0，他引：1
苏通长江大桥北引桥二期试桩工程采用自平衡试桩法对4根桩进行了测试,其中2根采用U管桩端压浆技术。根 据未压浆桩端阻实测值与计算结果的比较,计算值偏大,实测值为计算值的0.75～0.95倍。未压浆桩发挥端阻所需位移分别 为16mm、38mm,压浆桩发挥端阻所需位移有所减少,分别为12mm、21mm。压浆后桩端阻力测试值是未压浆桩端阻力测试值 的2.46～3.32倍,是规范计算值的2.46～2.50倍。压浆后,桩端阻力在总荷载中所占比例明显提高,由14.42%～15.39%提 高到22.83%～27.22%。桩端压浆对桩侧摩阻力有较大影响,其显著影响范围约为桩端以上14.27m～19.12m,且发挥摩阻 力所需位移明显减小。 相似文献
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本文将辩证思维方法运用于西安地裂缝研究中,阐述了西安地裂缝的时空观和间隙性,指出地裂缝的活动和地震没有必然的联系,同时也不足以抑制一次大震的发生。 相似文献
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Carbon dioxide injection and associated hydraulic fracturing of reservoir formations 总被引：2，自引：1，他引：1
The storage potential of subsurface geological systems makes them viable candidates for long-term disposal of significant quantities of CO2. The geo-mechanical responses of these systems as a result of injection processes as well as the protracted storage of CO2 are aspects that require sufficient understanding. A hypothetical model has been developed that conceptualises a typical well-reservoir system comprising an injection well where the fluid (CO2) is introduced and a production/abandoned well sited at a distant location. This was accomplished by adopting a numerical methodology (discrete element method), specifically designed to investigate the geo-mechanical phenomena whereby the various processes are monitored at the inter-particle scale. Fracturing events were simulated. In addition, the influence of certain operating variables such as injection flow rate and fluid pressure was studied with particular interest in the nature of occurring fractures and trend of propagation, the pattern and magnitude of pressure build-up at the well vicinity, pressure distribution between well regions and pore velocity distribution between well regions. Modelling results generally show an initiation of fracturing caused by tensile failure of the rock material at the region of fluid injection; however, fracturing caused by shear failure becomes more dominant at the later stage of injection. Furthermore, isolated fracturing events were observed to occur at the production/abandoned wells that were not propagated from the injection point. This highlights the potential of CO2 introduced through an injection well, which could be used to enhance oil/gas recovery at a distant production well. The rate and magnitude of fracture development are directly influenced by the fluid injection rate. Likewise, the magnitude of pressure build-up is greatly affected by the fluid injection rate and the distance from the point of injection. The DEM modelling technique illustrated provides an effective procedure that allows for more specific investigations of geo-mechanical mechanisms occurring at subsurface systems. The application of this methodology to the injection and storage of CO2 facilitates the understanding of the fracturing phenomenon as well as the various factors governing the process. 相似文献
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Shunde Yin 《国际地质力学数值与分析法杂志》2013,37(15):2523-2538
Integration of poromechanics and fracture mechanics plays an important role in understanding a series of thermal fracturing phenomena in subsurface porous media such as cold water flooding for enhanced oil recovery, produced‐water reinjection for waste disposal, cold water injection for geothermal energy extraction, and CO2 injection for geosequestration. Thermal fracturing modeling is important to prevent the potential risks when fractures propagate into undesired zones, and it involves the coupling of heat transfer, mass transport, and stress change as well as the fracture propagation. Analytical method, finite element method, and finite difference method as well as boundary element method have been used to perform the thermal fracturing modeling considering different degrees and combinations of coupling. In this paper, extended finite element method is employed for the thermal fracturing modeling in a fully coupled fashion with remeshing avoided, and the stabilized finite element method is employed to account for the convection‐dominated heat transfer in the fracturing process with numerical oscillation circumvented. With the thermal fracturing model, a hypothetical numerical experiment on cold water injection into a deep warm aquifer is conducted. Results show that parameters such as injection rate, injection temperature, aquifer stiffness, and permeability can affect the fracture development in different ways and extended finite element method and stabilized finite element method provide effective tools for thermal fracturing simulation. Copyright © 2012 John Wiley & Sons, Ltd. 相似文献
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超深储层地层起裂压力较高,水力压裂受现场泵注设备的限制严重,文中重点研究了大尺度水力压裂物模实验水泥样品尺寸（762 mm×762 mm×914 mm）在循环和常规两种泵注条件下的起裂扩展和声发射规律。实验结果显示,（1）相对于普通泵注,采用循环泵注方式进行水力压裂可以有效降低起裂压力,类似于单轴和三轴循环加载岩石力学行为,都是由于循环加载引起疲劳损伤;（2）对于螺旋射孔完井方式,水力压裂裂缝只从最薄弱射孔处起裂,一旦起裂后其他射孔孔眼很难再开启,水力压裂现场应合理选择分段距离和簇间距,实现储层改造效率最优化;（3）循环泵注水力压裂存在Kaiser效应（当加载应力到前次加载最高应力值时出现的声发射信息）。因孔隙流体扩散到岩石并导致孔隙压力的局部上升,破坏模式仍然可以由摩尔圆表示。研究成果对循环泵注条件的裂缝扩展规律研究以及发展新型压裂改造技术具有重要意义。 相似文献
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Researchers have recently realized that the non-tectonic natural fractures are developed in shale formations and significant for the exploitation of shale gas. Studies have shown that the tectonic fractures in naturally fractured reservoirs have influences on the maximization of stimulated reservoir volume (SRV) during hydraulic fracturing. However, the effect of the non-tectonic randomly natural fractures on the fracturing network propagation is not well understood. Laboratory experiments are proposed to study the evolution of fracturing network in naturally fractured formations with specimens that contain non-tectonic random fractures. The influences of the dominating factors were studied and analyzed, with an emphasis on natural fracture density, stress ratio, and injection rate. The response surface methodology was employed to perform the multiple-factor analysis and optimization in the maximization of the SRV. A sensitivity study reveals a number of interesting observations resulting from these parameters on the fracturing network evaluation. It is suggested from the geometry morphology of fracturing network that high natural fracture density and injection rate tend to maximize the fracturing network. The influence of stress contrast on fracturing network is nonlinear; an optimal value exists resulting in the best hydraulic fracturing effectiveness. 相似文献
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曙光油田低渗油藏存在老井低产与注压高注不进的双重难题,需要实施重复压裂提高产能.但常规重复压裂存在改造效果差和快速水窜风险,因而选择在注采对应井开展转向压裂矿场实验研究.通过注采对应井转向压裂方案研究、转向剂筛选及现场实施,取得了良好的增产增注效果.此次实验研究中,注采井均实施转向压裂,拓宽了转向压裂的思路,扩大了转向压裂的应用范围,进一步验证了转向压裂对老井挖潜增产、提高低渗油气田采收率具有重要的意义. 相似文献
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Mingze Liu Guang Zhang Guogang Gou Bing Bai Shaobin Hu Xiaochun Li 《Natural Hazards》2018,90(3):1137-1151
Reasonable determination of formation fracturing pressure concerns the stable operation of underground fluid injection projects. In this work, we studied the effect of unsteady flow on fracturing pressure. Hydraulic fracturing tests on low permeable sandstone were conducted with the injection rate between 0.1 and 2.0 ml/min. Then, the fracturing pressure prediction models for hollow cylinder under both unsteady flow and steady flow conditions were deduced. Finally, the effect of unsteady flow on the fracturing pressure was studied based on the experimental result and several influence factors. It was shown that fracturing pressure increased with the elevated pressurization rate in the tests, while the slope of the variation curve decreases. The model considering unsteady flow can reflect the variation tendency of fracturing pressures in experiments, while fracturing pressures from the model considering steady flow are invariant with different pressurization rates. Fracturing pressure decreases with the elevated rock permeability and increases with the elevated fluid viscosity, and these two effects are actually generated by the unsteady flow. Whether to consider the unsteady flow has no significant influence on the effect of rock tensile strength on fracturing pressure when the tensile strength is very low. However, when the tensile strength is high, the effect of unsteady flow cannot be neglected. 相似文献
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3500 m以深页岩气资源量占整个川南地区总资源量的比例高达86.5%,该区深层页岩气藏构造复杂,压裂形成复杂缝网的难度大,有必要通过数值模拟研究深层页岩气复杂缝网主控因素,对实现川南地区深层页岩气的效益开发具有重要意义。在对川南地区页岩气气田某井的岩芯进行细观尺度下的观察并构建二维裂缝模型的基础上,利用位移间断边界元法(DDM)模拟深层页岩水力压裂过程中水力裂缝与天然裂缝相互作用的物理力学过程,研究主应力、应力差和压裂液排量对裂缝扩展的影响。结果表明:在高应力差条件下缝网的复杂程度和总长度急剧降低,缝网的平均宽度增大,且平均宽度随排量增加而增大的能力变得有限。在高应力差条件下提升压裂液排量,缝网长度的增加以产生新生裂缝为主,同时提升排量对于激活天然裂缝有一定的提升作用,但是效果有限。相比于拉张裂缝,剪切裂缝的形成受主应力和压裂液排量的影响更显著,在高应力差条件下缝网中剪切裂缝的长度急剧降低。随着压裂液的注入,在较低应力差和相同压裂液注入量的情况下,低排量工况下的裂缝长度逐渐大于高排量工况下的裂缝长度。在应力差较高的情况下裂缝扩展的速率较低,同时会使提升排量而形成更多新生裂缝的能力变得有限。基于显微镜观察构建的裂缝模型计算出的结果能够较好地符合场地实际,为深层水力压裂设计和施工提供参考。 相似文献