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Reassessing Artificial Lift Selection in a Challenging Thermal Field 在具有挑战性的热场中重新评估人工举升选择
Pub Date : 2022-03-21 DOI: 10.2118/200193-ms
A. Alwazeer, Khadija Shaqsi, Amur Habsi, A. Busaidi, Khalid Salhi, M. Balushi, A. Hinai, Hamood Husaini, P. Putra, A. Hilali, R. Mujaini
This paper reviews the process for artificial lift selection and highlights the creativity applied to solve operational challenges. Artificial Lift (AL) systems are an essential component of oil and gas production in which wells are not flowing naturally to surface. The typical factors in assessing AL selection in conventional fields are driven by cost, anticipated rates, operating envelopes, depth and also factors such as corrosive elements, sand expectation, anticipated failure rates and operational experience. However, in heavy oil fields, the selection is complicated by additional factors such as Steam Break Through (SBT) and extreme viscosity variation. Many challenges were encountered during the actual operation of "A" East field which required revisiting early assumptions and modifying both lift selection and operating philosophy. The "A" East reservoir has an oil viscosity range between 400 to 400,000 cp at reservoir conditions. In order to deplete the high pressure in the reservoir (~137 bar) and minimize the adverse impact on steam injection quality and efficiency, about 40% of the wells were selected to be cold produced, initially using Progressive Cavity Pumps (PCP) to handle higher viscosities. These selected cold producers would later be converted to Cyclic Steam Stimulation (CSS) using Beam Pumps (BP). Cold production helped to lower the reservoir pressure. The remaining of the field operated with BP using down hole Steam By Pass Pumps (SBPP). The SBPP approach was adopted to minimize conversion time between injector and producer in CSS cycles. Challenges operating the SBPP pumps led to abandoning this approach, however, the insert pump concept continued. There were notable challenges operating the insert pumps as well mostly at the flanks after several steam cycles and various efforts which required a re-evaluation of AL systems available. Metal to Metal Progressive Cavity Pump (M2MPCP) was introduced to mitigate some extreme viscosities encountered in the flanks and reaching viscosities above 15000 cp at 60 C° (see figure 1). There were some operating challenges related to slow optimization and reaction times were mitigated by the introduction of automation using an algorithm-driven approach. Other challenges were related to BP start-ups in thick oil and other pump struggles with gas locking due to SBT. These challenges required adaptations and modifications such as slow start after interventions until heated fluids arrive to the wellbore. In other cases, production choke backs allowing for single phase flow through the pump. Conversion methods between cycles was accelerated by the introduction of stripping tool. Optimization efforts were also challenging and slow and demanded higher than expected manpower, this challenge was addressed by utilizing automation and algorithms which made a significant difference. The selection of a suitable AL system needs to take into consideration the overall requirements at the different de
本文回顾了人工举升选择的过程,并重点介绍了应用于解决操作挑战的创造性。人工举升(AL)系统是油气生产中必不可少的组成部分,在这种情况下,油井不能自然地流向地面。在常规油田中,评估人工智能选择的典型因素包括成本、预期产量、作业包层、深度,以及腐蚀元素、砂料预期、预期故障率和操作经验等因素。然而,在稠油油田,由于蒸汽突破(SBT)和极端粘度变化等其他因素,选择变得复杂。在“A”East油田的实际操作过程中遇到了许多挑战,需要重新审视早期的假设,修改举升装置的选择和操作理念。“A”East油藏在油藏条件下的油粘度范围在400 ~ 40000cp之间。为了降低储层高压(~137 bar),并尽量减少对注汽质量和效率的不利影响,选择了大约40%的井进行冷采,最初使用渐进式螺杆泵(PCP)来处理更高的粘度。这些选定的冷采油系统随后将使用束流泵(BP)转换为循环蒸汽增产(CSS)。冷采有助于降低储层压力。油田的其余部分由BP使用井下蒸汽旁通泵(SBPP)进行作业。采用SBPP方法可以最大限度地减少CSS循环中注入器和生产器之间的转换时间。然而,由于SBPP泵的操作困难,这种方法被放弃了,插入泵的概念继续存在。经过几个蒸汽循环和各种努力,需要重新评估可用的AL系统,在操作插入泵以及主要在侧翼存在明显的挑战。引入金属对金属渐进式螺杆泵(M2MPCP)可以缓解侧翼遇到的一些极端粘度,并在60°C时达到15000cp以上的粘度(见图1)。通过引入算法驱动的自动化方法,可以缓解一些与缓慢优化和反应时间相关的操作挑战。其他挑战涉及BP在稠油领域的初创企业,以及其他因SBT导致的气锁问题。这些挑战需要适应和改进,例如在干预后缓慢启动,直到加热的流体到达井筒。在其他情况下,生产阻塞允许单相流通过泵。汽提工具的引入加快了循环之间的转换方法。优化工作也具有挑战性,速度慢,需要的人力比预期的要多,这一挑战通过使用自动化和算法得到了显著的改善。选择合适的人工智能系统需要考虑不同发展阶段的总体要求。设备的标准化具有积累经验和降低维护成本等优势,但是,升降机系统的选择应该有一定的灵活性和变化,以应对不可预见的操作挑战。这种灵活性可以最大限度地提高油田的生产潜力,并增加了操作团队使用各种举升系统的机会。
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引用次数: 0
A Comparative Analysis for Optimal Fracture Design Between the Crest and Flank Wells. Examples from Saih Rawl, Oman Tight Gas Field 顶井与侧井裂缝优化设计的对比分析。以阿曼Saih Rawl致密气田为例
Pub Date : 2022-03-21 DOI: 10.2118/200038-ms
A. A. Al Hinai, M. Abdelazim, Khalfan Mubarak Al Bahri, Ahmed Abdullah Al Suleimani, A. Nunez, Aadil Salim Al Shekaili
Saih Rawl gas is located in the South Oman Salt Basin. There are two main formations targeted for gas production; Barik & Miqrat Formations. These formations are tight and exhibit low permeability. In order to enhance gas production, these formations have to be hydraulically stimulated. The main objectives of this paper is to demonstrate the petrophysical properties of the hydraulically fractured zones. Assess gas flow contribution thru the individual zones measured by production logging and comparing with the amount of proppant placed in the formation. In addition, the paper discusses reservoir properties and characteristics obtained from logging, post stimulation operations results and post stimulation gas production. The paper discusses 20 wells; 10 from the crest and 10 from the flank. The two formations Barik and Miqrat cover approximately 17 sub reservoir units. The total overall placement ratio is 95% and 78% for the crest and flank respectively with 156 hydraulic stimulation stages. It was observed that five sub reservoir units proved to be challenging to place the desired proppant. The maximum operating pressure is reached before achieving the desired proppant concentration leading to a screen out; concentrations of 2 – 3 pounds per gallon. Petrophysical evaluation of porosity and permeability cross plots showed a linear relationship in the wells in the crest. While there was no clear relationship was seen in the flank. Radioactive tracers used are to understand if there is any proppant propergation into the higher or lower zones. Not all the five challenging sub reservoir units showed propergation to other units. The wells located in the crest showed a better production rate as compared to the flank. The paper highlights the importance of the using petrophysical evaluation to optimize hydraulic fracturing design for successful operations.
Saih Rawl天然气位于南阿曼盐盆地。有两个主要的产气层;Barik & Miqrat地层。这些地层致密,渗透率低。为了提高天然气产量,必须对这些地层进行水力压裂。本文的主要目的是阐明水力压裂带的岩石物理性质。通过生产测井评估各个层的气体流量贡献,并与地层中放置的支撑剂量进行比较。此外,本文还讨论了测井资料、增产后作业结果和增产后产气量所获得的储层物性特征。本文讨论了20口井;头顶10人,侧翼10人。Barik和Miqrat两个地层覆盖了大约17个子储层单元。顶部和侧翼的总布置率分别为95%和78%,共进行了156级水力增产。研究人员观察到,5个次油藏单元很难放置所需的支撑剂。在达到所需的支撑剂浓度之前达到最大工作压力,从而导致筛出;浓度为每加仑2 - 3磅。岩石物性评价的孔隙度和渗透率交叉图在峰顶井中呈线性关系。而侧翼没有明显的关系。使用放射性示踪剂是为了了解是否有任何支撑剂进入较高或较低的层位。并非所有5个具有挑战性的次储层单元都表现出对其他单元的侵蚀。与侧翼井相比,位于顶部的井显示出更好的产量。本文强调了利用岩石物性评价优化水力压裂设计的重要性。
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引用次数: 0
Optimizing the Performance of Produced Water Chemical Treatment Following CEOR Polymer Breakthrough CEOR聚合物突破后采出水化学处理性能优化
Pub Date : 2022-03-21 DOI: 10.2118/200292-ms
M. Hesampour, S. Toivonen, Saija Holpoainen, Jouni Koski, Prince Sheril, Iris Porat, L. Bava
Chemical enhanced oil recovery (CEOR) plays a major role in sustaining production, extending the life of field and improves the recoverable reserves which is of economic benefit. The injected polymer will eventually propagate to the production wells where it is co-produced with production fluids. The presence of polymer in the back produced water may increase the residual oil levels and suspended solids in the produced water. This causes production systems bottlenecks, have a detrimental effect on water treatment processes, and increase in Oil in Water levels higher than admissible specs for discharge or reinjection. Several CEOR projects are introduced to producing fields where an established water treatment process already exists. These processes are initially designed to perform under a set of fluid and operating conditions. Polymer breakthrough can change the back produced water characteristics and impact the performance of the process. Upgrading of processes may require substantial investment. Chemical additives are widely considered as pragmatic alternative to improve water quality to desired levels. The selection of chemicals is very important as there are other associated challenges to be considered e.g. of the use of inorganic coagulants such as polyaluminum chloride (PAC) has been shown in studies to generate significant amounts of viscous sludge with low dry solids creating, sludge handing and equipment issues in the field. In this study, a new product combination has been developed to solve some of the drawbacks of traditional chemical such as sludge production while maintaining the performance of treatment. The composition of the product was determined through series of lab experiments and using design of experiments (DOE) methodology. The experiments were initially performed using a synthetic mixture of 400 parts per million (ppm) of hydrolyzed polyacrylamide (HPAM with hydrolysis degree ~ 30%) in saline water. The results were benchmarked to PAC and shown to produce a lower amount of sludge (25-50%) with the same performance in the same range of dosage (300-400 ppm). The sludge generated from the new combined product was also less viscous compared to the benchmark product. The investigation also revealed that a composition containing both inorganic/organic coagulant and cationic polymer improved performance. Results were validated with a field sample containing approx. 300 ppm of HPAM polymer. It was found that to generate less sludge and remove maximum total suspended solids, complete removal of polymer is not required. This new product offers several benefits including a reduction in the operating costs (product dosage is about half of benchmark product, polyaluminum chloride), reduction in the chemical footprint, improves the operational efficiency of the water treatment process and allows to operate within their environmental specifications.
化学提高采收率(CEOR)对油田的持续生产、延长油田寿命、提高可采储量具有重要的经济效益。注入的聚合物最终会进入生产井,与生产液共同开采。聚合物在后采水中的存在可能会增加采出水中的剩余油水平和悬浮固体。这会造成生产系统的瓶颈,对水处理过程产生不利影响,并使水中含油量高于排放或回注的允许规格。几个CEOR项目被引入到已经存在既定水处理工艺的生产油田。这些过程最初被设计为在一组流体和操作条件下运行。聚合物的突破会改变回采出水的特性,影响工艺性能。过程的升级可能需要大量的投资。化学添加剂被广泛认为是一种实用的替代方法,可以将水质改善到理想的水平。化学品的选择是非常重要的,因为还有其他相关的挑战需要考虑,例如,使用无机混凝剂,如聚氯化铝(PAC),研究表明,在低干固体生成的情况下,产生大量粘性污泥,污泥处理和现场设备问题。在本研究中,开发了一种新的产品组合,以解决传统化学的一些缺点,如产生污泥,同时保持处理性能。通过一系列的实验室实验和实验设计(DOE)方法确定了产品的组成。实验最初是在盐水中使用百万分之400 (ppm)水解聚丙烯酰胺(HPAM,水解度为30%)的合成混合物进行的。结果以PAC为基准,并显示在相同剂量范围内(300- 400ppm)产生相同性能的较低污泥量(25-50%)。与基准产品相比,新组合产品产生的污泥粘度也较低。研究还发现,含有无机/有机混凝剂和阳离子聚合物的组合物提高了性能。结果验证了现场样品含有约。300 ppm的HPAM聚合物。研究发现,为了产生更少的污泥和去除最大的总悬浮固体,不需要完全去除聚合物。这种新产品具有多种优势,包括降低运营成本(产品用量约为基准产品聚合氯化铝的一半),减少化学足迹,提高水处理过程的运行效率,并允许在其环境规范内运行。
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引用次数: 0
Mukhaizna Steam Flood Project: Thermal Surveillance Practices and Log Response Mukhaizna蒸汽驱项目:热监测实践和测井响应
Pub Date : 2022-03-21 DOI: 10.2118/200090-ms
Sultan AL-Qassabi, Mohammed Al Rahbi, Ali Al Habsi, Rashid Al Shaibi
Mukhaizna is a heavy oil field located in southern Oman. The heavy oil (700 to 3900 cP at reservoir conditions) was found at a true vertical depth of 2000 to 2460 ft, which is considered rather deep for a steam flood. Initial reservoir pressure was 1,300 psi, and the initial temperature was 122°F. The field has been developed with horizontal producers, vertical steam injectors, and vertical infill producers in patterns of about 67 acres in size. To date, 3000+ wells have been drilled in Mukhaizna field, and a huge amount of Petrophysical data has been acquired. Petrophysical surveillance work provides monitoring of time lapse thermal efficiency sweeping, perforation picking strategies of hot, swept and cold zones, as well understanding open hole log response in thermal hot wells. Using this information, we were able to target the correct zones to improve the thermal sweep and increase oil production. The first part of this paper will describe the open-hole log response in thermal wells and how perforation intervals are picked based on this log response. These perf picks were later corroborated with well production data to ensure alignment with well production performance. The second part of this paper will present a field-specific correlation of steam quality measured at the separator with spinner surveys at wellhead injectors, aiming to estimate steam quality directly from a spinner survey without having to run a steam quality separator, which is time-consuming and involves extensive effort.
Mukhaizna是位于阿曼南部的一个稠油油田。稠油(油藏条件下700 ~ 3900 cP)在2000 ~ 2460英尺的垂直深度被发现,对于蒸汽驱来说,这是相当深的深度。初始储层压力为1300 psi,初始温度为122°F。该油田已经开发了67英亩的水平井、垂直注汽井和垂直注汽井。迄今为止,在Mukhaizna油田已经钻了3000多口井,并获得了大量的岩石物理数据。岩石物性监测工作可监测热、热、冷三层的时移热效率扫描、射孔选择策略,并了解热井的裸眼测井响应。利用这些信息,我们能够瞄准正确的区域,以改善热波及并提高石油产量。本文的第一部分将描述热井的裸眼测井响应,以及如何根据该测井响应选择射孔间隔。这些射孔工具随后与油井生产数据进行了验证,以确保与油井生产动态一致。本文的第二部分将介绍分离器测量的蒸汽质量与井口注入器旋转测量的特定油田相关性,旨在直接从旋转测量中估计蒸汽质量,而无需运行蒸汽质量分离器,这既耗时又费力。
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引用次数: 0
Brine to Enhance the Transport of Encapsulated Petroleum Sulfonates Nanosurfactants Deeper into the High Temperature Carbonate Reservoirs 卤水促进包裹石油磺酸盐纳米表面活性剂向高温碳酸盐岩储层深层运移
Pub Date : 2022-03-21 DOI: 10.2118/200222-ms
A. Gizzatov, Mohammed Kawelah, Afnan Mashat, A. Abdel-Fattah
Development of NanoSurfactants (NSs), encapsulated petroleum sulfonates, is in progress for use as one of the most cost efficient surfactants in chemical enhanced oil recovery (CEOR) applications under extreme conditions. This work provides a better understanding of NS transport though porous carbonate rocks and demonstrates how hot and salty brines can facilitate NS transport when compared to deionized (DI) water. Transport of NSs at 90 °C in 57,000 ppm total dissolved solids (TDS) brine as well as NS components, petroleum sulfonate and zwitterionic co-surfactant, in 90 °C DI water through limestone core plugs was studied using a core flood apparatus. Effluent samples were measured for the total surfactant concentration using a total organic carbon (TOC) analyzer, and the dynamic retention values were calculated and compared. Structural integrity of NS assemblies before and after transport through the porous rock structure were studied using 1H Nuclear Magnetic Resonance (NMR) spectroscopy. Petroleum sulfonate surfactants are unstable in hot brines with high concentrations of divalent ions, and therefore cannot be transported through porous rock structures. Transforming such unstable sulfonates into NS formulations can overcome these challenges. Dynamic retention results in water-wet limestone demonstrate that NSs can be successfully transported through 150 - 200 millidarcy (mD) reservoir rocks with retention values < 0.4 mg/g of rock. These values are 30-50% lower than the retention of NS components alone, which is < 0.7 mg/g, if measured at the same conditions using DI water. Much lower retention for NSs was observed in brines, when compared to its surfactant components in DI water. This can be attributed to the NSs nanostructure which is designed to encapsulate sulfonates closer to the core while efficiently dispersing in the brines by co-surfactants with zwitterionic heads located at the surface. High salinity brine also helps to screen surface charges present on the rock surface. NMR spectroscopy results confirm that the nano-assembled NS structure does not exhibit noticeable changes after core flood experiments and confirms that the formulation has great potential for CEOR applications. Results presented in this work demonstrate that NS formulations made of assembled and dispersed nanocapsules enable the application of one of the lowest cost industrial surfactants for CEOR in hot and salty brines. This formulation in brines significantly reduces the loss of surfactants to the carbonate rock when compared to the same surfactant components in fresh water.
纳米表面活性剂(NSs)是一种封装的石油磺酸盐,它是极端条件下化学提高石油采收率(CEOR)应用中最具成本效益的表面活性剂之一。这项工作提供了通过多孔碳酸盐岩运移的更好理解,并证明了与去离子水(DI)相比,热盐水和咸盐水如何促进NS的运移。采用岩心驱替装置,研究了90℃下57,000 ppm总溶解固体(TDS)盐水中NSs以及90℃DI水中NSs组分、石油磺酸盐和两性离子共表面活性剂通过石灰石岩心塞的运移。利用总有机碳(TOC)分析仪测定出水样品的表面活性剂总浓度,计算并比较动态保留值。采用1H核磁共振(NMR)技术研究了NS组件通过多孔岩石结构前后的结构完整性。石油磺酸盐表面活性剂在含有高浓度二价离子的热盐水中不稳定,因此不能通过多孔岩石结构进行输送。将这种不稳定的磺酸盐转化为NS配方可以克服这些挑战。水湿石灰岩的动态滞留结果表明,NSs可以成功地通过150 - 200毫达西(mD)储集岩,其滞留值< 0.4 mg/g。如果在相同条件下使用去离子水测量,这些值比单独使用NS组分的保留率低30-50%,其< 0.7 mg/g。与表面活性剂组分相比,NSs在盐水中的保留率要低得多。这可以归因于NSs纳米结构,该结构设计用于封装更靠近核心的磺酸盐,同时通过位于表面的两性离子头的共表面活性剂有效地分散在盐水中。高盐度盐水也有助于屏蔽岩石表面的表面电荷。核磁共振波谱结果证实,纳米组装的NS结构在岩心淹水实验后没有出现明显的变化,证实了该配方具有巨大的CEOR应用潜力。这项工作的结果表明,由组装和分散的纳米胶囊组成的NS配方可以在热盐水和盐水中应用成本最低的工业表面活性剂之一。与在淡水中使用相同的表面活性剂组分相比,盐水中的这种配方显著减少了表面活性剂在碳酸盐岩中的损失。
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引用次数: 0
A Self-Adaptive Artificial Neural Network Technique to Estimate Static Young's Modulus Based on Well Logs 基于测井曲线的静态杨氏模量自适应人工神经网络估算方法
Pub Date : 2022-03-21 DOI: 10.2118/200139-ms
A. Mahmoud, S. Elkatatny, Abdulwahab Ali, T. Moussa
Static Young's modulus (Estatic) is an essential parameter needed to develop the earth geomechanical model, Young's modulus (E) considerably varies with the change in the lithology. Recently, artificial intelligence (AI) techniques were used to estimate Estatic for carbonate formation. In this study, artificial neural network (ANN) was used to estimate Estatic for sandstone formation. In this study, the ANN design parameters were optimized using the self-adaptive differential evolution (SaDE) optimization algorithm. The ANN model was trained to predict Estatic from conventional well log data such as bulk density, compressional time, and shear time. 409 data points from Well-A were used to train the ANN model which was then tested using 183 unseen data from the same well and validated on 11 data points from a different well (Well-B). The developed SaDE-ANN model estimated Estatic for the training data set with a very low average absolute percentage error (AAPE) of 0.46%, very high correlation coefficient (R) of 0.999 and coefficient of determination (R2) of 0.9978. And the Estatic values of testing data set were estimated with AAPE, R, and R2 of 1.46%, 0.998, and 0.9951, respectively. These results confirmed the high accuracy of the developed Estatic model.
静态杨氏模量(Static)是建立地球地质力学模型所必需的一个重要参数,杨氏模量(E)随着岩性的变化而有很大的变化。最近,人工智能(AI)技术被用于估算碳酸盐岩地层的静态。本文采用人工神经网络(ANN)对砂岩地层进行静力学估计。在本研究中,采用自适应差分进化(SaDE)优化算法对人工神经网络的设计参数进行优化。人工神经网络模型经过训练,可以根据常规测井数据(如体积密度、压缩时间和剪切时间)预测静校正。来自a井的409个数据点用于训练人工神经网络模型,然后使用来自同一口井的183个未见数据进行测试,并使用来自另一口井(b井)的11个数据点进行验证。所建立的SaDE-ANN模型对训练数据集的估计具有非常低的平均绝对百分比误差(AAPE)为0.46%,非常高的相关系数(R)为0.999,决定系数(R2)为0.9978。AAPE、R、R2分别为1.46%、0.998、0.9951,对检验数据集的Estatic值进行估计。这些结果证实了所建立的静态模型具有较高的精度。
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引用次数: 3
Improving Zonal Isolation and Cutting the Water Production with the Help of an Engineered Self-Healing Cementing System: A Case Study Review of the First Implementation of its Kind in Kuwait 借助工程自修复固井系统改善层间隔离并减少产水:科威特首次实施此类固井的案例研究综述
Pub Date : 2022-03-21 DOI: 10.2118/200299-ms
B. Al-Khayyat, Meshari Al-Mudhaf, A. Saffar, Tarasankar Mitra, Ken Monteiro, Sarah Al-Safran, Saleh Gholoum, M. Al-Khaja, Jasim Ali, Fatemah Al-Rashed, Mohammad Alotaibi, Fahad Almunayes
In one of the prolific fields in Kuwait, achieving zonal isolation posed a big challenge mainly due to setting the production liner shoe close to the oil-water-contact zone. Cement bond logs from the primary cementing jobs were not acceptable due to contamination from intruding water leading to a high water-cut in the produced oil. We review the first implementation of a self-sealing Cementing System in Kuwait to improve zonal isolation and cutting the water production. A comprehensive pre-job study was executed to engineer a suitable cementing system containing a swellable elastomer for oil-water-cuts with proper test in Lab. A novel HPHT multi-function test cell apparatus and procedure were utilized to measure in-situ ability of fractured cement specimens to seal oil-water-flows under the given simulated downhole conditions. Shrinkage or expansion of the set cement was also verified under pressure and temperature with a continuous test method run over several days. Thorough lab tests and Computational Fluid Dynamics simulations were run to enable a fit-for-purpose and robust cement slurry design ensuring proper placement of the cementing system in the well. This paper will describe how this cement was designed and engineered in laboratory. It will also describe how the set up was made simulating a crack in cement specimen and injecting water cut oil reacts and provides desired results. A calculated cement engineering approach was adopted to ensure better cement slurry placement and reduce the chances of slurry contamination. The test conditions were staged to replicate the most appropriate downhole conditions of pressure, temperature and simulated micro channel in the cement sheath. After the successful implementation of the self-sealing cementing system along the 7-in production liner in 2 wells, the corresponding cement bond log images showed hydraulic isolation and the production data from the wells indicated a reduction of nearly 50% in the water cut thus allowing a favorable oil production. This technology is applied in other wells of this field and other fields also with good results. This is being continued to use in critical wells.
在科威特的一个高产油田,实现层间隔离带来了很大的挑战,主要原因是生产尾管鞋靠近油水接触层。由于侵入水的污染,导致采出油含水率很高,因此第一次固井作业的水泥胶结测井结果不理想。我们回顾了科威特首次实施的自密封固井系统,以改善层间隔离并减少出水量。作业前进行了全面的研究,设计了一种适合油水切割的含膨胀弹性体的固井系统,并在实验室进行了适当的测试。采用一种新型的HPHT多功能测试单元装置和程序,在给定的模拟井下条件下,对裂缝性水泥试件封堵油水流动的能力进行了原位测试。通过连续几天的测试方法,还验证了水泥在压力和温度下的收缩或膨胀。进行了全面的实验室测试和计算流体动力学模拟,以实现适合用途和坚固的水泥浆设计,确保在井中正确放置固井系统。本文将描述这种水泥是如何在实验室设计和工程的。它还将描述如何模拟水泥试样中的裂缝和注入含水油的反应,并提供期望的结果。采用计算的水泥工程方法,确保更好的水泥浆投放,减少水泥浆污染的机会。测试条件分阶段进行,以复制最合适的井下压力、温度和模拟水泥环中的微通道条件。在2口井沿7-in生产尾管成功实施自密封固井系统后,相应的水泥胶结测井图像显示水力隔离,井的生产数据表明含水率降低了近50%,从而实现了良好的产油量。该技术在该油田其他井及其他油田的应用也取得了良好的效果。目前,该技术仍在关键井中使用。
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引用次数: 0
Addressing Challenges for Consistent Improvement of Cement Bonds in South Oman Fields 解决南阿曼油田持续改善水泥胶结的挑战
Pub Date : 2022-03-21 DOI: 10.2118/200184-ms
Gluber Meza, Samiullah Satti, H. Al-Sabti
Short liner cementing is very common in Oman southern oil fields. Among the challenges one can find no mechanical separation between the fluids, cement and pre-flush volumes are relatively small leading or increasing the chances of contamination and requiring remedial cementing jobs with uncertain success. As a result, poor cement bond log across the liner section were observed in more than 80% of all the cementing jobs. An engineering approach was proposed for this scenario. First increase rheologies of the fluids using physics instead of chemistry to diminish the fluid contamination inside of the casing and create a better sweeping effect outside of the casing. Selecting the adequate solid size ratios of the weighting agent to reduce the possible loss circulation problems generated by higher friction pressure. Increasing the generation and ultimate compressive strength of the cement system and finally providing expansion properties to the set cement. This paper presents the field CBL/USIT logs results and a case study showing the application and effectiveness of the technique proposed comparing with the previous approach in different wells.
短尾管固井在阿曼南部油田非常普遍。在这些挑战中,人们可以发现流体之间没有机械分离,水泥和预冲洗体积相对较小,导致或增加了污染的可能性,并且需要进行不确定成功的补救固井作业。因此,在所有固井作业中,超过80%的尾管段的水泥胶结测井结果都很差。针对这种情况提出了一种工程方法。首先,使用物理方法而不是化学方法来增加流体的流变性,以减少套管内部的流体污染,并在套管外部产生更好的扫井效果。选择适当的加重剂固体尺寸比,以减少高摩擦压力可能产生的漏失循环问题。提高水泥体系的生成抗压强度和极限抗压强度,最终使水泥凝块具有膨胀性能。本文介绍了现场CBL/USIT测井结果,并通过一个案例研究,对比了该技术在不同井中的应用和有效性。
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引用次数: 0
Data-Driven Integrated Reservoir Development of a Mature Condensate-Rich Gas Field in the Sultanate of Oman 阿曼某成熟富凝析气田数据驱动综合储层开发
Pub Date : 2022-03-21 DOI: 10.2118/200028-ms
Roeland van Gilst, Ahmed Al Kindi, Naila Al Balushi, Al Mutasem Abri, Ahmed Al Busaidy, Aida Al-Khusaibi
Recent observations indicate a distinct hydrocarbon composition change in a mature condensate rich gas field in the Sultanate of Oman, which will drastically change the next development decisions. The new insights were a result of: 1) data analysis and visualization and 2) collaboration between Development Planning (DP), Well & Reservoir Management (WRM) and Exploration. Field data such as well tests, fluid samples and production logging tests were integrated with geological concepts to deliver reservoir models that could assist late field life decision making. The outcome of the data analysis was summarized in the so-called "Plumbing Diagram", which combines reservoir architecture, structural elements, fluid fill and a reservoir connectivity analysis. The diagram was also used as a collaboration tool between Development, WRM and Exploration, which enabled the non-core team members to quickly understand the key uncertainties, risks and opportunities. Field data indicated vertical changes in hydrocarbon composition across the field. These new observations were combined with exploration burial diagrams and thin section analysis from core data. This led to the insight that the gas field is not just rich in condensate, but has gone through various hydrocarbon charge stages starting with an initial oil charge. A recently drilled well confirmed the existence of the oil charge with solid bitumen indicating a subsequent thermal cracking phase. Integration with wire line log evaluations made it possible to define two field-wide fluid zones, referred to by the team as: 1) Free Gas (FG) and 2) Condensate Rich Gas (CRG). The split of the two fluid zones will have a major impact on the field Development and WRM strategy as the focus is shifting towards development of the CRG zone, which is more challenging mainly due to the fluid fill mixture of oil, bitumen, gas and condensate. This paper describes how field data, observations and collaboration between teams improved the total hydrocarbon system understanding driving the future development decisions. The success of the changes in the development and WRM strategy will serve as blueprint for condensate rich gas fields with a similar burial and charge history in the north of Oman.
最近的观察表明,在阿曼苏丹国一个成熟的富含凝析油的气田中,碳氢化合物成分发生了明显的变化,这将极大地改变下一步的开发决策。新的见解是:1)数据分析和可视化的结果;2)开发规划(DP)、井与油藏管理(WRM)和勘探部门之间合作的结果。现场数据,如试井、流体样品和生产测井测试,与地质概念相结合,可以提供油藏模型,帮助油田后期的生命周期决策。数据分析的结果总结在所谓的“管道图”中,该图结合了储层建筑、结构元素、流体填充和储层连通性分析。该图表还被用作开发、水资源管理和勘探之间的协作工具,使非核心团队成员能够快速了解关键的不确定性、风险和机会。现场数据显示,整个油田的油气成分垂直变化。这些新的观测结果与勘探埋藏图和岩心薄片分析相结合。这使人们认识到,气田不仅富含凝析油,而且从最初的石油充注开始,还经历了不同的碳氢化合物充注阶段。最近钻探的一口井证实了含固体沥青的原油充注的存在,表明随后存在热裂解阶段。与电缆测井评估相结合,可以定义两个全油田流体层,团队将其称为:1)游离气(FG)和2)富凝析气(CRG)。这两个流体层的分离将对油田开发和水资源管理战略产生重大影响,因为重点正在转向CRG层的开发,CRG层的充填流体主要是石油、沥青、天然气和凝析油的混合物,因此更具挑战性。本文描述了现场数据、观察和团队之间的合作如何提高对整个油气系统的理解,从而推动未来的开发决策。开发和水资源管理战略变化的成功将成为阿曼北部具有类似埋藏和充注历史的富含凝析油气田的蓝图。
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引用次数: 1
Evaluation of Organic Acids Implementation in Stimulating Tight Gas Reservoirs: A Case Study on Sarah Sandstone Formation 有机酸在致密气藏增产中的应用评价——以萨拉砂岩组为例
Pub Date : 2022-03-21 DOI: 10.2118/200242-ms
Ellewa Ahmed Elsheikh, T. Moawad, A. Alnetaifi, Abdulrahman Alquraishi, Y. Almutawea
Sandstone formations are yet stimulated with mud acid when matrix acidizing is most competent. In terms of high-pressure high-temperature (HP-HT) conditions, the corrosive impact of hydrochloric (HCl) acid prompted the need to explore other alternatives to mud acid. This study examines the efficiency of organic acids in stimulating Sarah sandstone, a tight gas formation of potential. Two Berea cores were first exploited to investigate the optimum and most efficient injected acid volume. The mineralogy of Sarah formation was identified using X-ray diffraction (XRD) aided by Scanning Electron Microscopy (SEM). Formation mineralogy led to the selection of acetic-HF and oxalic-HF as proper acids for stimulation experiments. Bentonite water-base mud was used to alter the permeability of three fresh Sarah sandstone core samples. The organic-HF acids were used to stimulate two core samples, while mud acid was tested in the third core for comparison. Energy-dispersive X-ray spectrometer (EDX) and SEM were utilized to study the impact of acids on porous media. Experiments conducted in Berea core samples led to the execution of five pore volumes (PV) of preflush and one PV of main treatment as the optimum volume during the acidizing trials. XRD and SEM identified pore-filling clay minerals causing the low permeability of Sarah formation. Furthermore, the water-base mud injected decreased the permeability further by 80%. Oxalic-HF and acetic-HF mixtures recovered the initial permeability of core samples by 46% and 35% respectively. SEM-EDX results showed how organic acids have partially unblocked the pathways of the structural pores leading to permeability enhancement. This research not only recommends the use of oxalic-HF acid for acidizing Sarah sandstone formation but also spotlights the ability of organic acids employment as preflush in hydraulic fracturing operations.
砂岩层在基质酸化能力最强的时候,还需要进行泥浆酸化。在高压高温(HP-HT)条件下,盐酸(HCl)酸的腐蚀性影响促使人们需要探索泥浆酸的其他替代品。本研究考察了有机酸对Sarah砂岩(一种致密气储层)的增产效果。首先开发了两个Berea岩心,以研究最佳和最有效的注入酸体积。利用x射线衍射(XRD)和扫描电镜(SEM)对Sarah地层进行了矿物学鉴定。地层矿物学决定了选择醋酸- hf和草酸- hf作为刺激实验的合适酸。利用膨润土水基泥浆对萨拉砂岩岩心的渗透率进行了改变。有机氢氟酸对两个岩心样品进行了刺激,而泥浆酸对第三个岩心进行了对比。利用能量色散x射线能谱仪(EDX)和扫描电镜(SEM)研究了酸对多孔介质的影响。在Berea岩心样品中进行的实验表明,在酸化试验中,执行5个预冲孔体积(PV)和1个主处理孔体积(PV)作为最佳孔体积。XRD和SEM鉴定了导致Sarah地层低渗透率的填孔粘土矿物。此外,注入的水基泥浆进一步降低了80%的渗透率。草酸- hf和乙酸- hf混合物分别恢复岩心样品的初始渗透率46%和35%。SEM-EDX结果显示了有机酸如何部分地打开了结构孔的通道,从而提高了渗透率。该研究不仅推荐使用草酸-氢氟酸对Sarah砂岩地层进行酸化,而且强调了有机酸在水力压裂作业中作为预冲水的能力。
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引用次数: 0
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