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Time Dependent Depletion of Parent Well and Impact on Well Spacing in the Wolfcamp Delaware Basin Wolfcamp Delaware盆地母井时效枯竭及其对井距的影响
Pub Date : 2018-09-05 DOI: 10.2118/191799-MS
Cyrille Defeu, Giselle Garcia Ferrer, Efe Ejofodomi, Dan Shan, Farhan Alimahomed
Parent-child relationship is becoming a topic of high interest in the Permian Basin as more infill wells are being drilled at various times after the parent well has been produced. This paper uses an advanced modelling workflow to determine the impact of parent depletion on infill well spacing at various periods of the parent well production. As the parent well is being produced, constant well spacing based on virgin condition becomes problematic because pressure depletion around the well leads to change in stress magnitude and orientations. This change in reservoir conditions, is critical for planning infill well. Parent well depletion results in potential negative impact including: –Asymmetric fracture propagation from the child well into the depleted area around the parent well–Potential detrimental fracturing hits to the parent well These effects would potentially impair the production performance of both parent and infill wells, further reducing the overall pad efficiency of the pad completions. Parent well behavior is simulated using an unconventional fracture model (UFM), and the model is calibrated with available treating data. The resulting hydraulic fracture uses an advanced unstructured gridding algorithm that accounts for a fine complex fracture network along the lateral. A high-resolution, numerical reservoir simulator that combines the unstructured grid, rock physics, and reservoir fluid data is then used to match historical production data. The reservoir pressure depletion profile at various timesteps (6, 12, 24, and 36 months) is used as an input to calculate the resulting stress field state via a finite element model. The resulting updated geomechanical properties are used to simulate the infill well hydraulic fracture geometries at various spacing; subsequent unstructured grids are created and used to forecast production. Results are then compared to quantify the impact of depletion. –Initial reservoir pressure and horizontal stress reduce progressively with increasing time of production of the parent well; the average minimum stress change in the stimulated area reaches 18% decrease after 36 months of parent production.–Hydraulic fractures of infill wells grow preferentially towards the adjacent depleted area, reducing fracture extension in virgin rock by more than 60%.–Parent well depletion impacts fracture geometry and production performance of child wells.–Wells closer to the parent are more affected with increasing depletion time; these wells see up to 50% in production reduction as compared to the parent well.–At larger well spacing, little impact is observed due to limited interference between wells.–To help mitigate the impact of parent depletion on infill wells, an innovative spacing scheme that consists of using varying spacing on infill wells closest to the depleted parent well can be used. For this study and with current reservoir properties and completion design, if the parent well has been produced for less t
在二叠纪盆地,亲子关系正成为一个备受关注的话题,因为在主井生产后,越来越多的填充井在不同的时间被钻探。本文采用先进的建模工作流程来确定在母井生产的不同时期,母井枯竭对填充井间距的影响。随着母井的生产,基于未开发状态的恒定井距变得有问题,因为井周围的压力耗尽会导致应力大小和方向的变化。这种储层条件的变化对井的规划至关重要。母井枯竭会导致以下潜在的负面影响:从子井到母井周围的枯竭区域的不对称裂缝扩展,可能对母井造成有害的压裂冲击,这些影响可能会损害母井和填充井的生产性能,进一步降低垫层完井的整体效率。使用非常规裂缝模型(UFM)模拟母井行为,并使用现有的处理数据对模型进行校准。由此产生的水力裂缝采用了一种先进的非结构化网格算法,该算法考虑了沿侧向的精细复杂裂缝网络。高分辨率数值油藏模拟器结合了非结构化网格、岩石物理和油藏流体数据,然后用于匹配历史生产数据。利用不同时间步长(6、12、24和36个月)的油藏压力枯竭曲线作为输入,通过有限元模型计算得到的应力场状态。更新后的地质力学特性用于模拟不同井距下的充填井水力裂缝几何形状;随后创建非结构化网格并用于预测产量。然后对结果进行比较,以量化耗竭的影响。—随着母井生产时间的增加,油藏初始压力和水平应力逐渐减小;产母36个月后,增产区域的平均最小应力变化减小18%。—充填井水力裂缝优先向邻近衰竭区生长,使原生岩裂缝扩展减少60%以上。母井枯竭会影响裂缝的几何形状和子井的生产性能。随着枯竭时间的增加,靠近母井的井受到的影响更大;与母井相比,这些井的产量降低了50%。在较大井距时,由于井间干扰有限,影响很小。为了减轻母井枯竭对填充井的影响,可以采用一种创新的间距方案,即在最靠近枯竭母井的填充井上使用不同的间距。根据目前的油藏性质和完井设计,如果母井的生产时间不足12个月,则应将填充井放置在距母井至少750英尺的位置,如果母井的生产时间超过1年,则应放置在距母井至少900英尺的位置。
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引用次数: 3
Integrating Rock Properties and Fracture Treatment Data to Optimize Completions Design 整合岩石特性和裂缝处理数据,优化完井设计
Pub Date : 2018-09-05 DOI: 10.2118/191768-MS
E. Bruesewitz, J. Iriarte, J. Mazza, Carrie Glaser, E. Marshall, Scott H. Brooks
A horizontal well landed in a single formation rarely encounters homogeneous rock from the heel to the toe of the wellbore. When analyzing treatment responses that occur during hydraulic fracturing, a decreasing trend in surface treating pressure in sequential stages is typically attributed to reduced friction within the casing or frac string. However, there are several variances in treating pressure that are not readily explained by examining the surface pressures and pipe friction in isolation. These variances are also apparent when looking at bottom hole injectivity. Combining surface data and geomechanical data quickly reveals the degree of variability in rock properties along a lateral and the impact that variability can have on a completion, leading to a more optimal design. This paper demonstrates how engineers can take advantage of their most detailed completions and geomechanical data by looking for trends arising from past detailed treatment analyses and applying that gained knowledge to future completions. This study relies on the analysis of proprietary high-resolution geomechanical data derived from the processing of accelerations measured at the drillbit and high-frequency fracture treatment data recorded at one-second intervals. The data were standardized to a common format, screened for quality control, normalized, and analyzed using a data management platform. The methodology combines critical mechanical rock properties such as Young's Modulus, and Poisson's ratio with high-frequency fracture treatment data, including treating pressures, rates, and fluid and proppant volumes. Further application of the geomechanical data to derive brittleness allows for construction of a more predictive petromechanical model to optimize completion approaches. A brief analysis of past completions indicated virtually no correlation between gamma ray measurements along the stage and fracture treating conditions. However, when evaluating high-resolution mechanical rock properties along the lateral, a much more useful correlation exists between minimum horizontal stress variations (calculated from Poisson's Ratio) and eventual treating pressure and proppant placement difficulties. Calculated brittleness and bottomhole injectivity (which accounts for changes in slurry rate and pipe friction) also show a relationship, especially when cluster efficiency factors are included. This study of six Eagle Ford wells suggests that rock properties are the dominant variables affecting fracture treatment pressure and bottomhole injectivity. This method can be used to predict trouble stages, improve operational efficiencies, and optimize proppant placement. This paper proposes a process to improve completion efficiency while demonstrating the value of information contained in high-resolution and high-frequency datasets. Historically underutilized, these datasets are playing an increasingly prevalent role in advanced analytics due to improved and novel technolog
在单一地层中钻井的水平井很少会遇到从井筒跟部到趾部的均质岩石。在分析水力压裂过程中发生的处理响应时,地面处理压力在连续阶段呈下降趋势,这通常归因于套管或压裂管柱内部摩擦的减少。然而,在处理压力时存在一些差异,这些差异不容易通过单独检查表面压力和管道摩擦来解释。在观察井底注入能力时,这些差异也很明显。结合地面数据和地质力学数据,可以快速揭示沿水平段岩石性质的变化程度,以及这种变化对完井作业的影响,从而实现更优化的设计。本文展示了工程师如何利用他们最详细的完井和地质力学数据,从过去的详细处理分析中寻找趋势,并将所获得的知识应用于未来的完井。该研究依赖于对高分辨率地质力学数据的分析,这些数据来自于对钻头上测量的加速度和每隔一秒记录的高频压裂数据的处理。数据被标准化为通用格式,经过质量控制筛选,规范化,并使用数据管理平台进行分析。该方法结合了关键的岩石力学特性,如杨氏模量和泊松比,以及高频压裂数据,包括处理压力、速率、流体和支撑剂体积。进一步应用地质力学数据来推导脆性,可以建立更具预测性的岩石力学模型,以优化完井方法。对以往完井作业的简要分析表明,压裂段的伽马射线测量值与压裂处理条件之间几乎没有相关性。然而,当评估沿侧向的高分辨率岩石力学特性时,最小水平应力变化(由泊松比计算)与最终处理压力和支撑剂放置困难之间存在更有用的相关性。计算出的脆性和井底注入能力(考虑泥浆速率和管柱摩擦力的变化)也显示出相关性,特别是在考虑簇效率因素时。对Eagle Ford 6口井的研究表明,岩石性质是影响压裂压力和井底注入能力的主要变量。该方法可用于预测故障阶段,提高作业效率,并优化支撑剂的放置。本文提出了一个提高完井效率的过程,同时展示了高分辨率和高频数据集中包含的信息的价值。由于数据管理和解释的改进和新技术,这些数据集在高级分析中发挥着越来越普遍的作用。这个过程有助于提出更好的问题,并根据真实数据改进关键决策。
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引用次数: 1
Decision-Focused Optimization: Asking the Right Questions About Well-Spacing 以决策为中心的优化:提出正确的井距问题
Pub Date : 2018-09-05 DOI: 10.2118/191783-MS
Ryan A. Hassen, D. S. Fulford, Clayton T. Burrows, G. Starley
Engineers and leaders who must decide on development strategies for unconventional resource projects face a challenging design problem. While we must make decisions on well and completion design, including well-spacing in three-dimensions, the complexity of the physical system and the interactions between these parameters can become overwhelming. The technical optimization problem can be difficult; however, asking the right questions can make the business decision clearer than it first appears. The typical approach to design optimization problems is to build models, with a tendency toward including an ever-increasing number of parameters to describe the system in exhaustive detail. However, our uncertainty in the model parameters often makes it impossible to identify the true optimum. In this work, we focus instead on reducing the number of model parameters and capturing the impact of these critical uncertainties on our business decisions. This allows us to answer the right questions in order to define and choose the best well-spacing strategy. For well-spacing optimization, a critical uncertainty is the relationship between the chosen well-spacing and the potential well-performance degradation, in terms of estimated ultimate recovery (EUR) and initial production (IP). Rather than attempting to describe fracture geometry and well interference from a mechanistic standpoint, we introduce a lumped parameter, the shared reservoir (SR) factor, to account for this complex relationship. The parameter distribution may be calibrated to (a) well results in a play, (b) well results in carefully selected analogue plays, or (c) simulated well results from probabilistic analyses. An example of a Monte-Carlo simulation using the uncertainty of the SR factor, as well as the mean EUR and IP, highlights the utility of the method. We also illustrate how the spacing decision impacts key risk and financial metrics, including the expected monetary value of the project, the probability of regretting the decision, and the probability of commercial success of the project. The shared reservoir factor is proposed to capture the complex relationships between the well-spacing decision and the EUR and IP that result from this decision. Using the shared reservoir factor, we can develop simple stochastic models to clarify an otherwise frustratingly complex optimization problem.
工程师和领导者必须决定非常规资源项目的开发策略,他们面临着一个具有挑战性的设计问题。虽然我们必须对井和完井设计做出决策,包括三维井距,但物理系统的复杂性以及这些参数之间的相互作用可能会变得非常复杂。技术优化问题可能很困难;然而,提出正确的问题可以使商业决策比最初看起来更清晰。设计优化问题的典型方法是建立模型,倾向于包括越来越多的参数,以详尽地描述系统的细节。然而,模型参数的不确定性往往使我们无法确定真正的最优。在这项工作中,我们专注于减少模型参数的数量,并捕获这些关键不确定性对我们的业务决策的影响。这使我们能够回答正确的问题,从而定义和选择最佳的井距策略。对于井距优化,一个关键的不确定性是所选择的井距与潜在的井性能下降之间的关系,即估计的最终采收率(EUR)和初始产量(IP)。我们不是试图从力学的角度来描述裂缝的几何形状和井眼干扰,而是引入了一个集总参数,即共享油藏(SR)因素,来解释这种复杂的关系。参数分布可以校准为:(a)某一区块的井结果,(b)精心选择的模拟区块的井结果,或(c)概率分析的模拟井结果。一个蒙特卡罗模拟的例子使用SR因素的不确定性,以及平均EUR和IP,突出了该方法的实用性。我们还说明了间隔决策如何影响关键风险和财务指标,包括项目的预期货币价值、后悔决策的可能性以及项目商业成功的可能性。提出了共享储层因子,以捕捉井距决策与由此决定的EUR和IP之间的复杂关系。利用共享储层因子,我们可以建立简单的随机模型来澄清一个令人沮丧的复杂优化问题。
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引用次数: 2
Far-Field Diversion System Designed for Slickwater Fracturing 滑溜水压裂远场导流系统设计
Pub Date : 2018-08-28 DOI: 10.2118/191769-MS
Leonid Vigderman, A. Bogdan, Lingjuan Shen, D. Heller, Tony Yeung, Diankui Fu
Fracture geometry control and increased fracture complexity have been recognized to be critical factors in optimizing unconventional well completion design as well as preventing detrimental frac hits. A major challenge of far-field diversion in slickwater fracturing is ensuring transport of material to the fracture tip or secondary fracture in a low-viscosity fluid. This paper will present a novel far-field diverter system for fracturing with low-viscosity fluids to address these challenges composed of an engineered mixture of unique ultra-lightweight proppant and degradable material. Not only can the system effectively divert fracturing to control fracture geometry and enforce complexity, but will also maintain fracture conductivity. Several types of tests were performed to determine the effectiveness and optimize the design of the far-field diverter system. First, a series of slot plugging tests were carried out to optimize diversion performance of the system by blocking fluid flow through targeted fracture widths while maintaining flow through the larger portions of a fracture. Next, the diverter was pumped through a flow apparatus to demonstrate its far-field transportability in low-viscosity fluids. Finally, conductivity of the diverter system after degradation was tested. The new far-field diverter system was designed to create a permeability barrier at the fracture tip to contain fracture length growth as well as to be used in the middle of a stage to control growth of secondary/tertiary fractures to allow redistribution of fracturing fluid within the rock to further increase complexity. Lab tests demonstrated that by controlling the particle size of the engineered proppant and diverter mixture, the diverter system can be tailored to plug different fracture widths. Significantly, flow tests using a low-viscosity, slickwater fluid demonstrated the excellent transport properties and limited settling rate of the diverter. Finally, conductivity tests showed that by using an engineered mixture of non-degradable, ultra-lightweight proppant and degradable material, conductivity in the fracture is maintained after particle degradation, which is critical when applied in the middle of a stage to increase fracture complexity. To the authors’ knowledge, this is the first published paper of a far-field diverter that is optimized for slickwater fracturing for both fracture geometry and complexity control. The new diverter technology overcomes the significant limitations of other available systems such as fracture closure, inadequate transport to the far field, or the requirement to use high viscosity fluids.
裂缝几何形状控制和裂缝复杂性的增加已被认为是优化非常规完井设计和防止有害裂缝撞击的关键因素。在滑溜水压裂中,远场导流的一个主要挑战是确保材料在低粘度流体中输送到裂缝尖端或次级裂缝。本文将介绍一种用于低粘度流体压裂的新型远场分流系统,该系统由独特的超轻质支撑剂和可降解材料的工程混合物组成,以解决这些挑战。该系统不仅可以有效地分流压裂,控制裂缝的几何形状和复杂性,还可以保持裂缝的导流能力。为了确定远场分流系统的有效性和优化设计,进行了几种类型的测试。首先,进行了一系列的槽封堵测试,通过阻断流体流过目标裂缝宽度,同时保持裂缝大部分的流动,来优化系统的导流性能。接下来,将该暂堵剂泵入流动装置,以验证其在低粘度流体中的远场可输运性。最后,测试了降解后暂堵剂体系的导电性。新型远场分流系统的设计目的是在裂缝尖端形成渗透性屏障,以控制裂缝长度的增长,并在压裂阶段中期用于控制第二/第三次裂缝的增长,从而允许压裂液在岩石内重新分布,从而进一步增加复杂性。实验室测试表明,通过控制工程支撑剂和暂堵剂混合物的粒径,暂堵剂系统可以针对不同的裂缝宽度进行定制。值得注意的是,使用低粘度滑溜水进行的流动测试表明,该暂堵剂具有优异的输送性能和有限的沉降速率。最后,导电性测试表明,通过使用不可降解的超轻质支撑剂和可降解材料的工程混合物,在颗粒降解后仍能保持裂缝的导电性,这对于在压裂阶段中期应用以增加裂缝复杂性至关重要。据作者所知,这是第一篇针对滑溜水压裂进行裂缝几何形状和复杂性控制优化的远场暂堵剂的论文。新的暂堵剂技术克服了其他现有系统的重大限制,如裂缝闭合、远场输送不足或使用高粘度流体的要求。
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引用次数: 2
A Novel Workflow for Fracture Reconstruction and Uncertainty Analysis for Unconventional Reservoir Development 非常规油藏开发裂缝重建与不确定性分析新流程
Pub Date : 2018-08-28 DOI: 10.2118/191795-MS
Baosheng Liang, S. Du
Fracture networks present a critical influence on to better assess oil recovery and to optimize production of hydraulically fractured reservoirs. We established a novel workflow for fracture uncertainty analysis and prediction, in which multiple fracture pattern realizations are created from the geostatistical analysis. The original fracture networks were created using geomechanics tools. Then the fracture network is reconstrued for uncertainty analysis and history matching. For different realizations of the fracture distributions created in this workflow, we successfully maintain the continuity of the fractures, as well as the connections from the matrix to fractures. The generated grid can be further used for treatment simulation to determine fractures geometry, height growth and respected proppant transport in the induced fracture network. In this paper, we also apply Embedded Discrete Fracture Model (EDFM) to capture the realistic geometry of fractures. Within the EDFM, each fracture plane is embedded inside the matrix grid and is discretized by the cell boundaries. We study a series of reservoir simulation realizations, in which the complex hydraulic fracture networks are created in the workflow. We investigate different fracture realizations in both planar and complex fracture configurations while maintaining the continuity within the fracture networks. This study also includes the influence of the network geometry and fractures properties on the overall performance of the reservoir. From the uncertainty analysis results, we find that the overall reservoir performance is controlled by the fracture connectivity and the distribution of conductivity within the network. A good match of production history can be achieved by adjusting the fracture connectivity. Modeling with multiple realizations of fracture networks acknowledge that a reliable production forecast is achievable using geostatistical analysis for fracture connection reconstructions. Applying Embedded Discrete Fracture Model (EDFM) on the fracture-related model simulation provides a robust and effective means of investigating multiple fracture realizations.
裂缝网络对于更好地评价采收率和优化水力压裂油藏的生产具有重要的影响。我们建立了一种新的裂缝不确定性分析和预测工作流程,其中通过地质统计分析创建了多个裂缝模式实现。原始裂缝网络是使用地质力学工具创建的。然后重新解释裂缝网络,进行不确定性分析和历史匹配。对于在该工作流程中创建的裂缝分布的不同实现,我们成功地保持了裂缝的连续性,以及从基质到裂缝的连接。生成的网格可以进一步用于处理模拟,以确定裂缝的几何形状、高度增长和诱导裂缝网络中支撑剂的运移情况。在本文中,我们还应用嵌入式离散裂缝模型(EDFM)来捕捉裂缝的真实几何形状。在EDFM中,每个裂缝面都嵌入到矩阵网格中,并通过单元边界进行离散。我们研究了一系列油藏模拟实现,其中在工作流中创建了复杂的水力裂缝网络。我们在保持裂缝网络连续性的同时,研究了平面裂缝和复杂裂缝构型的不同裂缝实现。该研究还包括网络几何形状和裂缝性质对储层整体性能的影响。从不确定性分析结果来看,储层整体动态受裂缝连通性和网络内导电性分布的控制。通过调整裂缝连通性,可以很好地匹配生产历史。裂缝网络的多重实现建模表明,利用地质统计分析进行裂缝连接重建可以实现可靠的产量预测。将嵌入式离散裂缝模型(EDFM)应用于裂缝相关模型仿真,为研究多种裂缝实现提供了一种鲁棒且有效的手段。
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引用次数: 2
Improved Efficiency of a Nitrate Reducing Bacteria/Nitrate Treatment by the Incorporation of a Sulfate Analog 硫酸盐模拟物对硝酸盐还原菌/硝酸盐处理效率的提高
Pub Date : 2018-08-28 DOI: 10.2118/191773-MS
Kiran Gawas, Dana Safarin, H. Riley, J. Ogle
Hydraulic fracturing in the Marcellus Shale play has moved to produced water only scenarios because of prohibitive water disposal costs. Well completion under produced water only conditions increases the demand on chemical additive performance. In addition, water reuse selects deleterious microorganisms through natural selection, which may increase the likelihood of formation souring. Conventional biocides are typically used to mitigate these risks, but to some extent, they present health, safety, and environmental (HSE) concerns. In addition, several conventional biocides have side reactions with sulfide, notably tetrakis(hydroxymethyl)phosphonium sulfate (THPS) and 2,2-dibromo-3-nitrilopropionamide (DBNPA). This paper describes an improved method for the effective control of deleterious microorganisms without the use of conventional biocides. An environmentally friendly system that includes nitrate-reducing bacteria (NRB) coupled with nitrate co-introduction was previously shown to mitigate souring as effectively as a biocide alternative for more than 1,000 assets. The NRB inhibit growth of the deleterious sulfate-reducing bacteria (SRB) primarily by competing for the available carbon source if the source is limited. This paper describes an improved NRB/nitrate system that incorporates a sulfate analog, which presumably inhibits dissimilatory sulfate reduction and enhances mitigation. Laboratory experiments were performed to measure the amount of hydrogen sulfide (H2S) produced in field brine samples inoculated with SRB. The improved NRB/nitrate system was shown to inhibit the production of H2S under worst-case scenarios in laboratory competitive exclusion experiments. Results for the new treatment at four trial wells are presented. Sulfate-reducing bacteria populations, acid-reducing bacteria populations, and a gaseous H2S concentration were monitored over three months and were found to satisfy the operator's set key performance indicators. Overall, the amount of chemical required for treatment was reduced for this improved system, which substantially reduced the operator costs to treat the wells. The combination of chemistries with mutually exclusive cellular targets highlights the value of synergistic effects, specifically reducing system cost to treat while retaining low aquatic toxicity, as compared to traditional biocides used in the oilfield.
由于水处理成本过高,Marcellus页岩的水力压裂已经转向只使用采出水。仅在采出水条件下完井增加了对化学添加剂性能的要求。此外,回用水通过自然选择选择了有害微生物,这可能会增加地层酸败的可能性。传统的杀菌剂通常用于减轻这些风险,但在某种程度上,它们存在健康、安全和环境(HSE)问题。此外,一些传统的杀菌剂与硫化物有副反应,特别是四(羟甲基)硫酸磷(THPS)和2,2-二溴-3-硝基丙酰胺(DBNPA)。本文介绍了一种不使用常规杀菌剂而有效控制有害微生物的改进方法。一种环境友好型系统,包括硝酸盐还原细菌(NRB)和硝酸盐的共同引入,此前已被证明可以像杀菌剂一样有效地缓解酸败,适用于1000多种资产。NRB抑制有害硫酸盐还原菌(SRB)的生长主要是通过竞争可利用的碳源(如果碳源有限)。本文描述了一种改进的NRB/硝酸盐系统,其中包含硫酸盐类似物,可能会抑制异化硫酸盐还原并增强缓解。通过室内实验,测定了接种SRB后的大田卤水样品中硫化氢(H2S)的产生量。在实验室竞争排斥实验中,改进的NRB/硝酸盐体系在最坏情况下抑制了H2S的产生。介绍了四口试验井的新处理效果。对硫酸盐还原菌种群、酸还原菌种群和气态H2S浓度进行了三个多月的监测,发现它们满足了作业者设定的关键性能指标。总的来说,改进后的系统减少了处理所需的化学药剂用量,大大降低了作业者处理井的成本。与油田中使用的传统杀菌剂相比,化学物质与相互排斥的细胞靶标的结合突出了协同效应的价值,特别是降低了系统处理成本,同时保持了较低的水生毒性。
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引用次数: 0
Stimulated Oil Reservoir Volume Estimation of Prominent US Tight Oil Formations 美国著名致密油储层的增产油藏体积估算
Pub Date : 2018-08-28 DOI: 10.2118/191774-MS
P. Panja, R. Velasco, M. Deo
In this work, we estimate the Stimulated Original Oil In Place (SOOIP) of hydraulically fractured horizontal wells in prominent shale plays. This is done by compiling production data from hundreds of wells belonging to the Bakken, Niobrara, Wolfcamp, Eagle Ford, Bone Springs, and Woodford totaling over 2,500 wells. Additionally, we present probabilistic distributions of SOOIP with mean, standard deviation, P10, P50, and P90 estimates for each play. To circumvent the challenge of data availability for each well, we use the findings of a previous study where all reservoir unknowns are grouped into two major parameters. One of these parameters, alpha, is a function of the stimulated reservoir volume, compressibility, and pressure drawdown, where the last two are unknowns. While alpha is determined with high confidence for each well, we account for the uncertainty of compressibility and drawdown values across wells by assuming a normal distribution for these parameters. Lastly, by incorporating 1 million Monte Carlo samplings and a Mersenne Twister random number generator we estimate SOOIP distributions for each play with varying degrees of confidence. The final results show that the Niobrara and Bakken have the highest mean SOOIP values per well while the values for the Woodford and Bone Springs are the lowest among all six plays considered. Volumetric calculations using data from the literature qualitatively corroborate these findings. New insight on the stimulated volumes per well for prominent shale plays can be derived from these results as they correlate to horizontal well length, formation thickness, and hydraulic fracture half-lengths in each play.
在这项工作中,我们估计了在突出的页岩区水力压裂水平井的原始产油量(SOOIP)。这是通过收集Bakken、Niobrara、Wolfcamp、Eagle Ford、Bone Springs和Woodford共计2500多口井的生产数据来完成的。此外,我们给出了SOOIP的概率分布,包括每个油气藏的均值、标准差、P10、P50和P90估计值。为了规避每口井数据可用性的挑战,我们使用了之前的研究结果,该研究将所有未知的油藏分组为两个主要参数。其中一个参数alpha是油藏体积、压缩性和压降的函数,后两个参数是未知的。虽然每口井的alpha值都是高置信度确定的,但我们通过假设这些参数的正态分布来考虑井间压缩性和压降值的不确定性。最后,通过合并100万个蒙特卡罗样本和一个梅森扭扭随机数生成器,我们以不同的置信度估计每个游戏的SOOIP分布。最终结果表明,Niobrara和Bakken的单口井平均SOOIP值最高,而Woodford和Bone Springs的单口井平均SOOIP值最低。利用文献数据进行的体积计算定性地证实了这些发现。这些结果与水平井长度、地层厚度和每个区块的水力裂缝半长有关,因此可以对重要页岩区块的单井增产体积有新的认识。
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引用次数: 0
Advanced Formation Evaluation to Optimize Shale Development in Permian Basin 超前地层评价优化二叠系页岩开发
Pub Date : 2018-08-28 DOI: 10.2118/191792-MS
V. Ingerman
Permian Basin reserves exceed the reserves of the largest conventional field in the world, Ghawar, Saudi Arabia [1]. To develop this field many companies use ‘factory drilling’ or ‘geometrical approach’. This approach decreases the cost of drilling and make sense for source rocks because these are hydrocarbons saturated rocks or the rocks where hydrocarbons have been cooked. Geometrical approach would be ideal for homogeneous formations, but as it will be shown below shale place are very inhomogeneous vertically and laterally. While a drilling cost for a single well is reduced, this approach significantly increases the overall development costs and environmental impact because of drilling a big number of low producing wells. We found the way to solve this problem developing a technology that uses standard open-hole log data to calculate Production Profile that shows predicted production along the entire well.
二叠纪盆地的储量超过了世界上最大的常规油田——沙特阿拉伯Ghawar的储量。为了开发这一油田,许多公司采用“工厂钻探”或“几何方法”。这种方法降低了钻井成本,并且对于烃源岩来说是有意义的,因为这些烃源岩是碳氢化合物饱和的岩石或碳氢化合物已经被煮熟的岩石。对于均匀地层,几何方法是理想的,但下面将展示页岩的垂直和横向非常不均匀。虽然降低了单井的钻井成本,但由于钻井了大量低产井,这种方法显著增加了整体开发成本和环境影响。我们找到了解决这一问题的方法,开发了一种使用标准裸眼测井数据计算生产剖面的技术,该技术可以显示整个井的预测产量。
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引用次数: 0
Understanding Development Drivers in Horizontal Wellbores in the Midland Basin 了解Midland盆地水平井开发驱动因素
Pub Date : 2018-08-28 DOI: 10.2118/191782-MS
B. Cherian, M. Shoemaker, S.u Nwoko, S. Narasimhan, O. Olaoye, J. Iqbal, J. Peacock, J. Becher, B. Ferguson, N. Zakhour
The Permian Basin in North American has been the driving force behind global energy growth, resulting from the exploitation of unconventional resources. The combination of high quality stacked resources, horizontal drilling, completion tools, and hydraulic fracturing innovations has accelerated the learning curve in this basin over the past few years: which was the impetus of this study. This paper utilizes an integrated model approach to understand reservoir performance on a pad with four wells completed across multiple horizons in the Midland Basin. Rich multi-domain data sets were utilized that included seismic, wireline triple-combo, compressional and shear log suites, core (rock mechanics testing, geochemical analysis (XRF and XRD) and routine core analysis), completion data (fracture treatments with pre-and post-job shut-in pressures), and production data including 1,500 days of production history with bottom-hole pressure gauge data. 3-D surface seismic, high tier logs, and core data were used initially to create a facies model. Properties were distributed into a geo-model using the existing vertical well-control and seismic as constraints. A sector model was then built that enabled modeling of 4 development wells that consisted of parent well, followed by 3 child-wells. The history matching of fracture treatments and production data with bottom-hole pressure data resulted in significant understanding of key parameters driving subsurface performance. A workflow, representing the seamless integration of said models, is presented that enables an improved understanding of what impact sequence and timing of operations has on the subsurface contact area as well as the implied change in well performance if an optimal strategy is executed. Geomechanical facies that drive vertical connectivity and fracture geometry, as well as reservoir parameters that impact fracture contact with the reservoir, were identified.
由于非常规资源的开发,北美二叠纪盆地一直是全球能源增长的推动力。在过去的几年里,高质量的堆叠资源、水平钻井、完井工具和水力压裂创新的结合加速了该盆地的学习曲线,这是本研究的动力。本文利用综合模型方法来了解Midland盆地一个区块的油藏动态,该区块在多个层位上完成了四口井。利用了丰富的多领域数据集,包括地震、电缆三重组合、压缩和剪切测井、岩心(岩石力学测试、地球化学分析(XRF和XRD)和常规岩心分析)、完井数据(压裂前后关井压力)和生产数据(包括1500天的生产历史和井底压力测量数据)。三维地面地震、高地层测井和岩心数据最初用于创建相模型。利用现有的直井控制和地震作为约束,将储层属性分布到地质模型中。然后建立了一个扇形模型,可以对4口开发井进行建模,其中包括母井和3口子井。通过将压裂处理和生产数据与井底压力数据进行历史匹配,可以很好地理解驱动地下性能的关键参数。提出了一个代表上述模型无缝集成的工作流程,可以更好地理解作业顺序和时间对地下接触面积的影响,以及执行最佳策略时油井性能的隐含变化。确定了影响垂向连通性和裂缝几何形状的地质力学相,以及影响裂缝与储层接触的储层参数。
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引用次数: 1
Hydraulic Fracture and Reservoir Characterization for Determining Optimal Well Spacing in the Marcellus Shale 确定Marcellus页岩最佳井距的水力裂缝和储层表征
Pub Date : 2018-08-28 DOI: 10.2118/191802-MS
P. Pankaj, P. Shukla, P. Kavousi, T. Carr
Naturally fractured reservoirs such as the Marcellus shale require an integrated reservoir modeling approach to determine well spacing and well-to-well interference. The Marcellus Shale Energy and Environment Laboratory (MSEEL) is a joint project between universities, companies, and government to develop and test new completion technologies and acquire a robust understanding of the Marcellus shale. The study presented in this paper aims to reveal an approach to determine reservoir depletion with time through coupled geological modeling and geomechanical evaluation followed by completion and well performance history matching for a multiwell pad in the Marcellus shale. The geomechanical model was prepared with interpreted vertical log data. A discrete natural fracture (DFN) model was created and used to determine the complexity of hydraulic fracture geometry simulated through complex fracture models on a two well pad. The microseismic data obtained during the hydraulic fracture simulations served as a constraining parameter for the hydraulic fracture footprint in these wells. Sensitivity to the DFN is realized by parametric variations of DFN properties to achieve a calibrated fracture geometry. Reservoir simulation and history matching the well production data confirmed the subsurface production response to the hydraulic fractures. Well spacing sensitivity was done to reveal the optimum distance that the wells need to be spaced to maximize recovery and number of wells per section. Hydraulic fracture geometry was found to be a result of the calibration parameters, such as horizontal stress anisotropy, fracturing fluid leakoff, and the DFN. The availability of microseismic data and production history matching through integrated numerical simulation are therefore critical elements to bring unique representation of the subsurface reaction to the injected fracturing fluid. This approach can therefore be consistently applied to evaluate well spacing and interference in time for the subsequent wells completed in the Marcellus. With the current completion design and pumping treatments, the optimal well spacing of 990 ft was determined between the wells in this study. However, wells to be completed in the future need to be modeled due to the heterogeneity in the reservoir properties to ensure that wells are not either underspaced to cause well production interference or overspaced to create upswept hydrocarbon reserves in the formation. By adopting the key learnings and approach followed in this paper, operators can maximize subsurface understanding and will be able to place their wellbore in a nongeometric pattern based on reservoir heterogeneity to optimize well spacing and improve recovery.
Marcellus页岩等天然裂缝性油藏需要综合油藏建模方法来确定井距和井间干扰。马塞勒斯页岩能源与环境实验室(MSEEL)是大学、公司和政府之间的一个联合项目,旨在开发和测试新的完井技术,并对马塞勒斯页岩进行深入了解。本文的研究旨在揭示一种方法,通过耦合地质建模和地质力学评估,然后进行完井和井况历史匹配,来确定油藏随时间的枯竭。利用解释的垂向测井资料建立地质力学模型。建立了离散自然裂缝(DFN)模型,并通过对两个井台的复杂裂缝模型进行模拟,确定水力裂缝几何形状的复杂性。水力压裂模拟过程中获得的微地震数据是这些井水力压裂足迹的约束参数。通过DFN特性的参数变化来实现对DFN的敏感性,从而获得校准的裂缝几何形状。油藏模拟和历史数据与油井生产数据相匹配,证实了地下生产对水力裂缝的响应。通过井距敏感性分析,可以确定最佳井距,以最大限度地提高采收率和每个井段的井数。水力裂缝几何形状是标定参数的结果,如水平应力各向异性、压裂液漏出量和DFN。因此,微地震数据的可用性和通过综合数值模拟匹配的生产历史是提供注入压裂液地下反应的独特表征的关键因素。因此,该方法可以持续应用于Marcellus后续完井的井距和干扰评估。根据目前的完井设计和泵送处理,本研究确定了井间距为990英尺的最佳井距。然而,由于储层性质的非均质性,未来要完井的井需要进行建模,以确保井的井距不会过小而造成生产干扰,也不会过大而在地层中产生上涌的油气储量。通过采用本文中的关键知识和方法,作业者可以最大限度地了解地下,并能够根据储层非均质性将井眼置于非几何模式,从而优化井距并提高采收率。
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引用次数: 5
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Day 2 Thu, September 06, 2018
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