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Quantifying Erosion of Downhole Solids Control Equipment during Openhole, Multistage Fracturing 量化裸眼多级压裂过程中井下固体控制设备的侵蚀
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-12-01 DOI: 10.2118/203096-pa
A. Dikshit, G. Woiceshyn, V. Agnihotri, G. Chochua, M. Noor
Proppant flowback from hydraulic fracturing is widespread and costly due to erosion and/or blockage of producing hydrocarbons as proppant may accumulate downhole. Several strategies have been applied to avoid or minimize proppant flowback, such as treatment optimization to maximize pack stability, resin-coated proppant, limiting drawdown, or letting it flow to deal with the consequences later. Another strategy to avoid proppant flowback is to install sand control equipment integrated into a sliding sleeve device (SSD) as part of the completion string. Although the presence of sand control equipment can mitigate the problem, it raises concern about erosion during fracturing. Although some installations have been successful, one is known to have experienced sand control failure. This study aimed to understand the effect of hydraulic fracturing on the erosion of completion equipment with an objective of improving the design to, as much as possible, prevent erosion failure. Computational fluid dynamics (CFD) was used to evaluate the root cause and identify more robust design solutions. The first step was to identify the most probable causes of sand control failure during multistage fracturing (MSF) in openhole (OH) horizontals. The as-is completion was then modeled, along with the screen, SSD, fracturing port, and OH isolation packer. Because the fracture location between two packers is unknown, and the fracturing port was located between multiple screen/SSD assemblies, annular flow across the assembly in both directions was considered. State-of-the-art CFD simulations were then performed on the installed design using actual flow conditions (rates, slurry properties, treatment time) from the failed installation. A new quasidynamic mesh (QDM) methodology was developed, which yielded more realistic (albeit still conservative) erosion-depth predictions. The results revealed areas for improving the design of key components of the 10-ksi-rated system, and CFD was rerun to confirm erosion resistance targets. Design modifications were implemented, and improved products were then manufactured and field tested. For a new 15-ksi design, particle–particle interaction was added to the CFD analysis. The results of the CFD analysis and field test are presented herein.
由于支撑剂可能在井下积聚,从而对生产碳氢化合物造成侵蚀和/或堵塞,因此水力压裂产生的支撑剂返排广泛且成本高昂。已经采用了几种策略来避免或最大限度地减少支撑剂回流,例如优化处理以最大限度地提高充填稳定性、树脂涂层支撑剂、限制压降或让其流动以处理后续后果。避免支撑剂返排的另一种策略是将防砂设备安装到滑动套管装置(SSD)中,作为完井管柱的一部分。尽管防砂设备的存在可以缓解这个问题,但它引发了人们对压裂过程中侵蚀的担忧。尽管一些装置已经成功,但已知有一个装置出现了防砂故障。本研究旨在了解水力压裂对完井设备腐蚀的影响,目的是改进设计,尽可能防止腐蚀失效。计算流体动力学(CFD)用于评估根本原因并确定更稳健的设计解决方案。第一步是确定裸眼(OH)水平多级压裂(MSF)期间防砂失效的最可能原因。然后对原状完井以及筛网、SSD、压裂口和OH隔离封隔器进行建模。由于两个封隔器之间的裂缝位置未知,且压裂口位于多个滤网/SSD组件之间,因此考虑了沿两个方向穿过组件的环形流。然后,使用故障安装的实际流动条件(速率、浆料特性、处理时间),对安装的设计进行最先进的CFD模拟。开发了一种新的准动态网格(QDM)方法,该方法产生了更现实(尽管仍然保守)的侵蚀深度预测。结果揭示了改进10ksi额定系统关键部件设计的领域,并重新运行CFD以确认抗侵蚀目标。进行了设计修改,然后制造了改进的产品并进行了现场测试。对于新的15ksi设计,CFD分析中增加了颗粒-颗粒相互作用。本文给出了CFD分析和现场试验的结果。
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引用次数: 4
Optimal Wellbore Placement of a Penta-Lateral Well in the Schrader Bluff Reservoir, North Slope, Alaska 阿拉斯加北坡Schrader Bluff油藏五分支井的最佳井眼布置
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-12-01 DOI: 10.2118/204468-pa
P. Maraj, Ken Huber, D. Itter, J. Nelson, M. Rabinovich, Alex Youngmun, Yuriy Antonov, Luis Mejia, S. Martakov, Jhonatan H Pazos, Austin Small, N. Tropin
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引用次数: 0
Unplugging Standalone Sand-Control Screens Using High-Power Shock Waves 使用大功率冲击波拔下独立防砂筛管
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-12-01 DOI: 10.2118/199294-PA
A. Habibi, Charles E. Fensky, M. Perri, Morteza Roostaei, Mahdi Mahmoudi, Vahidoddin Fattahpour, Hongbo Zeng, M. Sadrzadeh
Previous studies showed that different parameters influence the plugging of completion tools. These parameters include rock mineralogy, reservoir-fluid properties, and type of completion tools. Although different methods have been used for unplugging these tools, there is still debate regarding the performance of these methods on damage removal. In this study, we assessed the performance of high-power shock waves generated from an electrohydraulic-stimulation (EHS) tool on cleaning completion tools plugged during oil production. These devices were extracted from different wells in Canada, Europe, and the US. First, we quantified the extent of cleaning for the plugged slotted liners using the EHS tool at the laboratory scale. Next, we analyzed the mineral composition of the plugging materials removed after the treatment by conducting scanning electron microscopy (SEM) with energy dispersive X-ray spectroscopy (EDS), inductively coupled plasma mass spectroscopy (ICP-MS), colorimetric, and dry-combustion analyses. Finally, we reviewed the pulsing-stimulation-treatment results applied to several field case studies. The results of unplugging slotted liners at the laboratory scale showed that up to 28.5% of the plugged slots are cleaned after 120 pulses of shock waves. The mineral-characterization results showed that the main plugging materials are calcite, silicates, and iron-based components (corrosion products). The cleaning performance (CP) of the EHS tool increases by increasing the number of pulses and the output energy (OE) applied to the tool. The CP parameter is high at (i) high concentrations of carbonates, barium (Ba)-based components, and organic matter, and (ii) low concentrations of corrosion products and sulfates. The results of field case studies showed that the cleaning of the EHS tool is not limited to the sand-control devices and it can clean other tools that are less accessible for other techniques, such as subsurface safety valves. This paper provides a better understanding of the performance of shock waves on damage removal from plugged completion tools. The results could open new insight into the applications of shock waves for cleaning the completion tools.
以往的研究表明,不同的参数会影响完井工具的封堵。这些参数包括岩石矿物学、储层流体性质和完井工具类型。尽管已经使用了不同的方法来拔出这些工具,但关于这些方法在去除损伤方面的性能仍然存在争议。在这项研究中,我们评估了电液增产(EHS)工具产生的大功率冲击波对石油生产过程中堵塞的完井工具的清洗性能。这些装置是从加拿大、欧洲和美国的不同井中提取的。首先,我们在实验室规模上使用EHS工具量化了堵塞的开槽尾管的清洁程度。接下来,我们通过扫描电子显微镜(SEM)、能量色散x射线能谱(EDS)、电感耦合等离子体质谱(ICP-MS)、比色法和干燃烧分析来分析处理后去除的堵漏材料的矿物组成。最后,我们回顾了脉冲刺激治疗在几个现场案例研究中的应用结果。实验室拔槽衬管的结果表明,经过120次冲击波脉冲后,高达28.5%的槽被清理干净。矿物表征结果表明,堵漏材料主要为方解石、硅酸盐和铁基组分(腐蚀产物)。EHS工具的清洁性能(CP)通过增加脉冲数量和施加在工具上的输出能量(OE)而提高。当(i)碳酸盐、钡(Ba)基组分和有机物浓度高,(ii)腐蚀产物和硫酸盐浓度低时,CP参数高。现场案例研究结果表明,EHS工具的清洗不仅限于防砂装置,它还可以清洗其他技术难以触及的其他工具,如地下安全阀。本文可以更好地理解冲击波对封堵完井工具损伤清除的影响。研究结果可以为冲击波清洁完井工具的应用提供新的见解。
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引用次数: 1
Effects of Seepage on Gas Loss through Shale Desorption during Shale Core Removal 页岩取心过程中渗流对页岩解吸气体损失的影响
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-12-01 DOI: 10.2118/204234-pa
Junbo He, Jiren Tang, Honglian Li, Jing Zhang, Qi Yao
In the process of shale coring, the gas adsorption will increase the flow resistance of gas inside the core, which will inevitably affect the accuracy of shale gas loss. To clarify the underlying effects of seepage flow and related factors during shale desorption, we conducted an experimental study on the influence of methane on seepage resistance of fractured shale and matrix shale under different adsorption pressures. Changes in reservoir fluid and deformation resulting from CH4 saturation adsorption resulted in changes in shale permeability. This study investigated six adsorption durations (2, 4, 6, 12, 18, and 24 hours) under adsorption pressures of 5, 9, and 13 MPa in shale samples. During each cycle, different injection pressures (2 to 6 MPa) were applied, and seepage resistance of shale samples was measured by the transient method. The results showed that the permeation resistance of the sample decreased significantly after adsorption of CH4 reached saturation and decreased with increasing CH4 adsorption duration. Compared with matrix shale samples, fractured shale samples were shown to have more suitable pore microcracks and higher CH4 affinity. Therefore, fractured samples were found to have higher permeability resistance and higher adsorption capacity compared to matrix shale. The permeability flow of a sample had a negative exponential relationship with confining pressure, and stress sensitivity increased with increasing CH4 adsorption time. The model representing gas loss indicated a positive correlation between change in impermeability and the flow of escaped gas on the core surface. A significant reduction in the impermeability of the core will result in a significant reduction in shale gas loss.
在页岩取芯过程中,气体吸附会增加岩心内部气体的流动阻力,这必然会影响页岩气损失的准确性。为了阐明页岩解吸过程中渗流的潜在影响及其相关因素,我们对不同吸附压力下甲烷对裂缝页岩和基质页岩渗流阻力的影响进行了实验研究。储层流体的变化和CH4饱和吸附引起的变形导致页岩渗透率的变化。本研究调查了六个吸附持续时间(2、4、6、12、18和24 小时),在5、9和13的吸附压力下 页岩样品中的MPa。在每个循环中,不同的喷射压力(2至6 MPa),并通过瞬态法测量页岩样品的渗透阻力。结果表明,样品的渗透阻力在CH4吸附达到饱和后显著降低,并随着CH4吸附时间的增加而降低。与基质页岩样品相比,裂隙页岩样品具有更合适的孔隙微裂纹和更高的CH4亲和力。因此,与基质页岩相比,压裂样品具有更高的渗透阻力和更高的吸附能力。样品的渗透率流量与围压呈负指数关系,应力敏感性随CH4吸附时间的增加而增加。表示气体损失的模型表明,不渗透性的变化与岩心表面逸出气体的流动之间呈正相关。岩心不渗透性的显著降低将导致页岩气损失的显著减少。
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引用次数: 0
Modeling Cuttings Transport without Drillpipe Rotation While Using the Concepts of Static and Dynamic Yield Stresses 利用静态和动态屈服应力的概念模拟钻杆不旋转时岩屑运移
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-12-01 DOI: 10.2118/204466-pa
Shiraz Gulraiz, K. Gray
Cuttings transport, in connection with drilling fluid rheology, has been extensively studied in the literature. Despite this, contradictory results continue to be reported regarding the effect of yield stress on cuttings transport. This study uses the concepts of static and dynamic yield stresses to investigate the effects of yield stress on cuttings transport. A modified form of an existing rheological function is proposed to model static and dynamic yield stresses while incorporating flow history. Flow equations are based on the mixture approach and are numerically solved using computational fluid dynamics (CFD) methodology. Assuming that the liquid phase is homogenous and drill cuttings are noncolloidal, it is shown that the distinction between static and dynamic yield stresses diminishes as volumetric cuttings concentration increases. The Herschel-Bulkley function predicts infinite viscosity at the limit of zero shear rate and, hence, improved cuttings transport with increasing dynamic yield stress, whereas in line with the majority of experimental studies, the proposed rheological model shows that high dynamic yield stress is detrimental for cuttings transport. Comparing fluids with the same dynamic yield stress, the fluid with a larger difference between static and dynamic yield stresses has better cuttings carrying capacity. However, these results are only valid for simple yield stress fluids in which yield stress is dependent on shear rate only.
岩屑运移与钻井液流变学的关系在文献中得到了广泛的研究。尽管如此,关于屈服应力对岩屑运移的影响,仍有相互矛盾的结果报道。本研究采用静态和动态屈服应力的概念来研究屈服应力对岩屑运移的影响。提出了一种现有流变函数的修正形式来模拟静态和动态屈服应力,同时考虑了流动历史。流动方程基于混合方法,并采用计算流体动力学(CFD)方法进行数值求解。假设液相是均匀的,钻屑是非胶体的,静态屈服应力和动态屈服应力之间的区别随着体积岩屑浓度的增加而减小。Herschel-Bulkley函数预测了零剪切速率极限下的无限粘度,因此,随着动态屈服应力的增加,岩屑输运得到改善,然而,与大多数实验研究一致,所提出的流变模型表明,高动态屈服应力不利于岩屑输运。与动屈服应力相同的流体相比,静、动屈服应力差较大的流体携岩屑能力较好。然而,这些结果仅适用于屈服应力仅依赖于剪切速率的简单屈服应力流体。
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引用次数: 3
Crack Propagation Hypothesis and a Model To Calculate the Optimum Water-Soaking Period in Shale Gas/Oil Wells for Maximizing Well Productivity 裂缝扩展假说和页岩气/油井最佳吸水期计算模型
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-12-01 DOI: 10.2118/201203-pa
B. Guo, R. Shaibu, Xuejun Hou
Currently, researchers and the industry believe that water invasion into a shale matrix should dominate the process of water soaking before flowback of hydraulic fracturing fluids. Based on laboratory observations with Tuscaloosa marine shale (TMS) cores, we postulate a hypothesis that cracks are formed in shale formations during and after hydraulic fracture stimulation and that they later contribute to improved well productivity. The formation of cracks contributes to improving well inflow performance, while the cracks also draw fracturing fluid from the hydraulic fractures, reduce fracture width, and consequently lower well inflow performance. The trade-off between crack development and fracture closure allows for an optimum water-soaking time, which could potentially maximize well productivity. A mathematical model was developed to describe the dynamic propagation of cracks based on the capillary-viscous force balance. The effect of crack formation on the long-term well productivity was analyzed using a previously published mathematical model for well productivity. A combination of the crack propagation and the well productivity models for the first time provides a technique for predicting the optimum fluid soaking time before flowback of hydraulic fracturing fluids. Sensitivity analyses show that reducing the viscosity of fracturing fluid could potentially speed up the optimum water-soaking time, while lowering the water-shale interfacial tension (IFT) could potentially delay the optimum water-soaking time. Real-time shut-in pressure data can be used in the crack propagation model to “monitor” crack development and identify the optimum water-soaking time before the flowback of hydraulic fracturing fluids for maximizing well productivity and the gas/oil recovery factor.
目前,研究人员和业内人士认为,在水力压裂液返排之前,水侵入页岩基质的过程应该占主导地位。根据对Tuscaloosa海相页岩(TMS)岩心的实验室观察,我们假设裂缝是在水力压裂期间和之后在页岩地层中形成的,并且它们后来有助于提高油井产能。裂缝的形成有助于改善井的流入性能,同时裂缝也会从水力裂缝中吸出压裂液,减小裂缝宽度,从而降低井的流入性能。在裂缝发育和裂缝闭合之间进行权衡,可以获得最佳的浸水时间,从而可能最大限度地提高油井产能。建立了基于毛细管-粘性力平衡的裂纹动态扩展数学模型。利用先前发表的井产能数学模型分析了裂缝形成对井长期产能的影响。裂缝扩展和油井产能模型的结合首次为预测水力压裂液返排前的最佳流体浸泡时间提供了一种技术。敏感性分析表明,降低压裂液粘度可能会加快最佳浸水时间,而降低水-页岩界面张力(IFT)可能会延迟最佳浸水时间。实时关井压力数据可用于裂缝扩展模型,以“监测”裂缝发育,并确定水力压裂液返排前的最佳浸水时间,从而最大限度地提高油井产能和油气采收率。
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引用次数: 4
Sand Screen with Check-Valve Inflow Control Devices 带有单向阀流入控制装置的防砂筛管
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-12-01 DOI: 10.2118/201206-pa
A. Dikshit, Amrendra Kumar, E. Anikanov, P. Petukhov, A. Rudic, G. Woiceshyn, B. Gadiyar, M. Parlar, Camilo Jurgensen
Sand control screens are installed with an internal string (wash pipe) as required which, among other functions, provides a circulation path. In long horizontal wells, running a wash pipe consumes considerable rig time and may limit the ability to reach target depth. In cases in which fluid losses are experienced after screen installation, isolating the open hole with a fluid-loss control valve can be prolonged. This paper describes a wash-pipe-free solution for screen installation using a check-valve inflow control device (CV-ICD). ICD screens are commonly used to delay/restrict the influx of unwanted fluids such as gas or water. The wash-pipe-free solution integrates a check valve with the ICD to prevent outflow through the screen during circulation and allows inflow through the screen when placed on production. This solution uses a check ball that seals against the ICD during circulation but falls back on a porous retainer plate during production. The check ball and retainer plate can be dissolved by spotting a reactive fluid inside the screen or made to erode over time with production. Laboratory testing yielded the following results: the ICD with the check ball was shown to seal up to 5,000 psi; the check ball and retainer plate can be dissolved by a reactive fluid, which can be tailored to bottomhole temperature and the required time of dissolution; and the pressure activation test demonstrated that the maximum differential pressure to seat the ball was less than 5 psi. This CV-ICD solution has been applied worldwide in more than 35 wells, most of which were targeted to avoid running a wash pipe. However, in two wells the technology was successfully used to set openhole packers with a 5,000-psi setting pressure. In this paper, we present the wash-pipe-free ICD screen installation with a dissolvable check valve and the capability of setting a hydraulic packer without a wash pipe or intervention in the open hole. The novel contribution presented herein is the ability to integrate a ball and cage to existing nozzle-based ICDs by using dissolvable material to achieve the preceding results in this application.
防砂筛管根据需要安装了内部管柱(洗管柱),除其他功能外,还提供了循环路径。在长水平井中,下入洗管会消耗大量钻机时间,并可能限制到达目标深度的能力。如果筛管安装后出现流体漏失,则可以延长使用流体漏失控制阀隔离裸眼的时间。本文介绍了一种使用单向阀流入控制装置(CV-ICD)安装筛管的无冲洗管解决方案。ICD筛管通常用于延迟/限制不需要的流体(如气体或水)的流入。无冲洗管解决方案集成了一个带有ICD的止回阀,以防止在循环过程中通过筛管流出,并允许在生产时通过筛管流入。该解决方案使用止回球,在循环过程中密封ICD,但在生产过程中回落到多孔保持板上。止回球和固定板可以通过在筛管内发现反应性流体而溶解,也可以随着生产时间的推移而被腐蚀。实验室测试结果如下:带有止回球的ICD密封压力可达5000 psi;止回球和固定器板可以通过反应性流体溶解,反应性流体可以根据井底温度和所需溶解时间定制;压力激活测试表明,密封球的最大压差小于5 psi。该CV-ICD解决方案已在全球超过35口井中应用,其中大多数井的目标是避免下入洗管。然而,在两口井中,该技术成功地应用于坐封压力为5000 psi的裸眼封隔器。在本文中,我们介绍了一种无需冲洗管的ICD筛管装置,该装置带有可溶解的止回阀,并且能够在裸眼井中无需清洗管或干预即可下封液压封隔器。本文提出的新贡献是能够通过使用可溶解材料将球和保持架集成到现有的基于喷嘴的icd中,从而在该应用中实现上述效果。
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引用次数: 1
Measurement While Drilling Mud Pulse Signal Denoising and Extraction Approach Based on Particle-Swarm-Optimized Time-Varying Filtering Empirical Mode Decomposition 基于粒子群优化时变滤波经验模态分解的随钻测量泥浆脉冲信号去噪与提取方法
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-12-01 DOI: 10.2118/204454-pa
Zhong Xianyou, Cen Li, Zhao Yankun, Huang Tianwei, Jinjin Shi
At present, mud pulse transmission is widely used in underground wireless transmission. To extract more accurately the original drilling fluid pulse signals while drilling, in this paper, we developed an algorithm for optimal denoising shaping based on particle-swarm-optimized time-varying filtering empirical mode decomposition (TVFEMD). The performance of TVFEMD heavily depends on its parameters (i.e., B-spline order and bandwidth threshold). In the traditional TVFEMD method, the parameters are given in advance and may not be optimized, so it is difficult to achieve satisfactory decomposition results. To tackle this issue, the correlation coefficient was used as the objective function, and the particle-swarm-optimization algorithm was used to optimize the parameters of TVFEMD in this paper. First, the particle swarm optimization was used to search for the best combination of parameters. Then, the TVFEMD was applied to obtain a series of intrinsic mode functions (IMFs). Subsequently, the optimal denoising and shaping algorithm was used to determine the best reconstructed signal by low-pass filtering. Permutation entropy was taken as the evaluation index to obtain a reconstruction signal. Finally, the reconstructed signal was processed by square wave shaping to obtain accurate drilling fluid pulse signals. The approximation of the algorithm is 0.7581, and relevance is as high as 0.8535. The simulation signal and drilling fluid pulse signal analysis results showed that the proposed approach can extract the original pulse signal accurately.
目前,泥浆脉冲传输广泛应用于井下无线传输。为了在钻井过程中更准确地提取原始钻井液脉冲信号,本文提出了一种基于粒子群优化时变滤波经验模式分解(TVFEMD)的最优去噪整形算法。TVFEMD的性能在很大程度上取决于其参数(即B样条阶数和带宽阈值)。在传统的TVFEMD方法中,参数是预先给定的,可能不会进行优化,因此很难获得令人满意的分解结果。为了解决这一问题,本文将相关系数作为目标函数,并使用粒子群优化算法对TVFEMD的参数进行优化。首先,使用粒子群优化算法来搜索参数的最佳组合。然后,应用TVFEMD获得了一系列本征模函数。随后,采用最优去噪整形算法,通过低通滤波确定最佳重构信号。以置换熵作为评价指标,得到重建信号。最后,对重构后的信号进行方波整形处理,得到准确的钻井液脉冲信号。该算法的近似值为0.7581,相关性高达0.8535。仿真信号和钻井液脉冲信号分析结果表明,该方法能够准确提取原始脉冲信号。
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引用次数: 2
West Africa Salt-Zone Cementing Best Practices: Laboratory Evaluation and 5-Year Field Application Review 西非盐区固井最佳实践:实验室评估和5年现场应用回顾
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-11-09 DOI: 10.2118/203444-ms
D. Nana, C. Uba, C. Johnson, Matthieu Lonca, Jamel Zghal
To determine which salt-based cement system (potassium chloride or sodium chloride) was suitable for cementing across halite and anhydrite salt sections in West Africa, eight slurry recipes were tested to assess how formation salt contamination would affect slurry properties. The formation salt used for testing was sampled from a deepwater, presalt well in Angola. The recommendations developed from the laboratory study were implemented in 10 projects across West Africa over 5 years with 100% operational and well integrity success. A candidate deepwater well was selected in which the surface and intermediate strings penetrated salt formations. Four slurry designs (a lead and tail slurry used on each casing string) were programmed. Each slurry was designed and tested as two distinct systems using potassium chloride and sodium chloride salt, respectively, yielding a total of eight slurry designs. Using the methodology and data presented by Martins et al. (2002), the mass of dissolved formation salt that each slurry may receive during placement was estimated and duly incorporated into each slurry design. Subsequently, the salt-contaminated slurries were tested and compared with the properties of the initial uncontaminated slurries. On the basis of these results, conclusions were then made on which salt slurry system (potassium chloride or sodium chloride) exhibited better liquid and set properties after contamination with formation salt. Subsequently, this knowledge was applied to 10 projects across three countries in West Africa. This study showed that when the contact time of liquid cement slurry to salt formation was low—typically when the salt-formation interval across which the cement slurry flowed was less than 100 m thick—the level of formation salt dissolution entering the slurry during placement was limited. In this case, a potassium chloride salt-based slurry delivered improved liquid and set properties as compared with a sodium chloride salt-based slurry. In the field, this knowledge was applied in all oilfield projects cemented by an oilfield service company between 2015 and 2020. This included deepwater, shallow offshore, and onshore wells. All related salt-zone cement jobs, including sidetrack plugs, placed across the salt formations were successful on the first attempt. In an absence of industry consensus around salt-formation cement slurry design, this paper validates a guideline for West Africa, based on results from laboratory testing and 5 years of field application. In contrast to current literature that recommends only sodium chloride salt-based slurry designs across halite or anhydrite salt intervals, this work demonstrates that potassium chloride salt-based slurry systems can effectively be used to achieve well integrity where a halite or anhydrite salt interval is less than 100 m (328.1 ft) thick.
为了确定哪种盐基水泥体系(氯化钾或氯化钠)适合在西非的岩盐和硬石膏盐段进行固井,研究人员测试了8种泥浆配方,以评估地层盐污染对泥浆性能的影响。用于测试的地层盐取自安哥拉的一口深水盐下井。在5年的时间里,实验室研究提出的建议在西非的10个项目中得到了实施,并取得了100%的运营和井完整性成功。选择了一口候选深水井,其中地面和中间管柱穿过盐层。四种泥浆设计(每个套管柱上使用一种铅浆和尾浆)进行了编程。每种泥浆都被设计和测试为两种不同的系统,分别使用氯化钾和氯化钠盐,总共产生了8种泥浆设计。利用Martins等人(2002)提供的方法和数据,估计了每种泥浆在放置过程中可能吸收的溶解地层盐的质量,并将其适当地纳入每种泥浆设计中。随后,对盐污染浆料进行了测试,并与初始未污染浆料的性能进行了比较。在这些结果的基础上,得出了盐浆体系(氯化钾或氯化钠)在被地层盐污染后表现出更好的液固性的结论。随后,这些知识被应用到西非三个国家的10个项目中。研究表明,当水泥浆液与盐层的接触时间较短时(通常是当水泥浆流过的盐层厚度小于100 m时),在放置过程中,进入水泥浆的地层盐溶解水平受到限制。在这种情况下,与氯化钠盐基浆料相比,氯化钾盐基浆料提供了更好的液体和凝固性能。在2015年至2020年期间,某油服公司将这些知识应用于所有油田项目。这包括深水、浅海和陆上油井。所有相关的盐层固井作业,包括在盐层上放置侧钻桥塞,在第一次尝试中都取得了成功。在盐地层水泥浆设计缺乏行业共识的情况下,本文基于实验室测试和5年的现场应用结果,验证了西非的指导方针。目前的文献只推荐在岩盐或硬石膏层中使用氯化钠盐基泥浆,而这项研究表明,在岩盐或硬石膏层厚度小于100米(328.1英尺)的情况下,氯化钾盐基泥浆系统可以有效地实现井的完整性。
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引用次数: 0
Application of Nanosilica in Glycerol-Based Drilling Fluid for Shale Formations 纳米二氧化硅在页岩地层甘油基钻井液中的应用
IF 1.4 4区 工程技术 Q3 ENGINEERING, PETROLEUM Pub Date : 2020-11-01 DOI: 10.2118/204238-pa
Chao Lyu, Shuqing Hao, Liang Yang
In this study, we perform several tests to develop a formula of glycerol-based drilling fluid that is suitable for shale formations with severe wellbore instability problems. Drilling fluids with varying combinations of nanosilica, glycerol, sodium carboxymethyl cellulose (Na-CMC), and xanthan gum (XG) in organic soil glycerol-based slurry are tested, and the effects of nanosilica on the swelling of shale samples and the lubricity of drilling fluids are also investigated to verify the feasibility of designed drilling fluids. The experimental investigations reveal that the values of apparent viscosity (AV), plastic viscosity (PV), and yield value (YP) of the optimal formulation meet the rheological parameters required for the drilling of shale formations. The AV and PV values of drilling fluid with 55:45 glycerol/water ratio are lower than those of drilling fluids with other glycerol/water ratios. A higher XG content means higher YP value in the experiment and 0.4% XG is suitable for the glycerol-based drilling fluid to prevent the collapse of the shale wellbore. There is a critical nanosilica content threshold (0.5%), and the filtration loss (FL) increases gradually when this threshold is exceeded due to the agglomeration of nanosilica. The nanosilica coated on clay particles in shales because of the formation of hydrogen bonds results in a decrease in permeability of shale formations. The swelling of shale through hydration is greatly reduced by 37% and the sticking coefficient of drilling fluid is reduced by 28% when 0.5% nanosilica is added. The addition of nanosilica to glycerol-based drilling fluid is significant to deal with the wellbore instability problems in troublesome shale formations.
在这项研究中,我们进行了几项测试,以开发一种适用于具有严重井筒不稳定问题的页岩地层的甘油基钻井液配方。测试了纳米二氧化硅、甘油、羧甲基纤维素钠(Na-CMC)和黄原胶(XG)在有机土壤甘油基泥浆中的不同组合钻井液,并研究了纳米二氧化硅对页岩样品溶胀和钻井液润滑性的影响,以验证设计钻井液的可行性。实验研究表明,最佳配方的表观粘度(AV)、塑性粘度(PV)和屈服值(YP)满足页岩地层钻井所需的流变参数。甘油/水比为55:45的钻井液的AV和PV值低于其他甘油/水比例的钻井液。XG含量越高,实验中YP值越高,0.4%的XG适用于甘油基钻井液,以防止页岩井筒坍塌。存在一个临界的纳米二氧化硅含量阈值(0.5%),当由于纳米二氧化硅的团聚而超过该阈值时,过滤损失(FL)逐渐增加。由于氢键的形成,纳米二氧化硅涂层在页岩中的粘土颗粒上,导致页岩地层的渗透率降低。当添加0.5%的纳米二氧化硅时,页岩的水化膨胀大大降低了37%,钻井液的粘滞系数降低了28%。在甘油基钻井液中添加纳米二氧化硅对于解决棘手页岩地层中的井筒不稳定问题具有重要意义。
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引用次数: 5
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SPE Drilling & Completion
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