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Dimer Indolizine Derivatives of Quaternary Salt Corrosion Inhibitors: Enlightened High-Effective Choice for Corrosion Prevention of Steel in Acidizing 四元盐类缓蚀剂二聚吲唑嗪衍生物对钢铁酸性腐蚀防护的高效选择
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-10-01 DOI: 10.2118/200098-pa
Zhen Yang, Yefei Wang, M. Finšgar, Fengtao Zhan, Huayou Hu, Jiajia Wu, Wengang Ding, M. Ding, Wuhua Chen
For decades, increasingly severe downhole conditions call for superior and less-expensive corrosion inhibitors (CIs) for acidizing in petroleum production. Inhibitors that exhibit satisfactory protective ability at relatively low concentration are of great interest to most scholars in this area. In this work, two newly obtained dimer indolizine derivatives that were derived from the conventional quaternary quinolinium salts were introduced as potential highly efficient acidizing CIs. The indolizine derivatives could perform well alone, even without any synergistic component, in concentrated hydrochloric acid (HCl). Two quinoline ammonium salts, ethyl acetate quinolinium chloride (EAQC) and n-butyl quinolinium chloride (BuQC), were synthesized in advance by means of the quaternarization process. Afterward, in the presence of alkali, the ammonium salts could then get converted into the corresponding novel dimer indolizine derivatives easily by means of a 1,3-dipolar cycloaddition reaction in a relatively high yield. The derivatives were purified and their accurate chemical structures were confirmed by elementary analysis, nuclear magnetic resonance (NMR), and mass spectrometry (MS). Dimer derivatives of two quinoline salts were prepared successfully and characterized separately as C26H23N2O4Cl and C26H27N2Cl. Corrosion-inhibition performance of the quaternary quinoline salts as well as the related dimer indolizine derivatives in concentrated HCl for N80 steel was investigated by gravimetric research, electrochemical method, and scanning electron microscopy (SEM) energy dispersive X-ray analysis. The thermodynamic aspect of the inhibition was also discussed. The structure of EAQC and BuQC are very close to the quinolinium salt inhibitors that are commonly used as key components in commercially accessible acid CI products. However, under alkaline condition, EAQC and BuQC would easily be transformed to dimer indolizine derivatives that possess a general “indolizine” structure. That is the reason why the targeted molecules are recognized as “dimer indolizine derivatives.” Both the derivatives have good thermal stability at approximately 248°F and are easily soluble in acid solution. The surprising difference in the anticorrosion effect between the original quinoline salts and their dimer derivatives was proved by weight-loss experiments in 15 wt% HCl at 194 and 248°F with dosage ranges from 0.01 to 0.5 wt%. The derivatives could retard the corrosion of steel considerably at a much lower concentration compared with their precursors. A 0.1-wt% dosage of indolizine derivatives could increase the inhibition efficiency (IE) of N80 steel remarkably, to approximately 99.0% in 15 wt% HCl at 194°F. Results obtained from gravimetric tests and electrochemical methods are in good agreement and confirmed the well-behaved inhibition of the derivatives. We predict that the inhibition will be enhanced apparently when similar quinoline or pyridine ammonium salt ar
几十年来,日益严峻的井下条件要求在石油生产中使用优质且价格较低的缓蚀剂(CI)进行酸化。在相对较低的浓度下表现出令人满意的保护能力的抑制剂引起了该领域大多数学者的极大兴趣。在这项工作中,引入了两种新获得的二聚中氮茚衍生物,它们来源于传统的季喹啉盐,作为潜在的高效酸化CI。中氮茚衍生物可以单独在浓盐酸(HCl)中表现良好,即使没有任何协同成分。采用季铵化法合成了两种喹啉铵盐,乙酸乙酯-氯化喹啉(EAQC)和正丁基氯化喹啉(BuQC)。然后,在碱的存在下,铵盐可以通过1,3-偶极环加成反应以相对高的产率容易地转化为相应的新型二聚中氮茚衍生物。对衍生物进行了纯化,并通过元素分析、核磁共振(NMR)和质谱(MS)证实了其准确的化学结构。成功地制备了两种喹啉盐的二聚体衍生物,并分别表征为C26H23N2O4Cl和C26H27N2Cl。采用重量分析、电化学方法和扫描电子显微镜(SEM)能量色散X射线分析等方法,研究了季喹啉盐及其二聚物中氮茚衍生物在浓盐酸中对N80钢的缓蚀性能。还讨论了抑制作用的热力学方面。EAQC和BuQC的结构非常接近喹啉盐抑制剂,喹啉盐抑制剂通常用作商用酸性CI产品的关键成分。然而,在碱性条件下,EAQC和BuQC很容易转化为具有一般“中氮嗪”结构的二聚中氮嗪衍生物。这就是为什么靶分子被认为是“二聚中氮茚衍生物”的原因。这两种衍生物在大约248°F下都具有良好的热稳定性,并且很容易溶于酸溶液中。15年的失重实验证明了原始喹啉盐及其二聚体衍生物在防腐效果上的惊人差异 194°F和248°F下盐酸的重量百分比,剂量范围为0.01 至0.5 重量%。与前体相比,在低得多的浓度下,衍生物可以显著延缓钢的腐蚀。0.1~wt%的中氮茚衍生物能显著提高N80钢的缓蚀效率,15 194°F下的重量%HCl。重量测试和电化学方法的结果一致,证实了衍生物的良好抑制作用。我们预测,当类似的喹啉或吡啶铵盐通过类似的1,3-偶极环加成机制转化时,抑制作用将明显增强。我们已经确定,二聚中氮茚衍生物的使用为低成本的防腐提供了一个创造性的新选择,并且保护化合物可以在未来几年用作酸化CI的主要成分。
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引用次数: 2
Prediction of Slug/Churn Transition for Viscous Upward Two-Phase Flows in Vertical Pipes 垂直管内粘性向上两相流的段塞/丘转预测
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-10-01 DOI: 10.2118/203832-PA
G. Abdul-Majeed, Mahshid Firouzi
In this study, we investigate the effect of liquid viscosity (μL) on the slug/churn transition in gas/liquid flows in vertical pipes. A total of 80 experimental churn-flow data points from two different sources are compiled as a data set, covering liquid viscosities from 17.23 to 586 mPa·s. Air was used in these studies as a gas phase with two different liquids, aqueous glycerol and a commercial synthetic mineral oil, flowing in vertical pipes of 0.0192- and 0.0508-m inner diameter (ID). The data set is used to examine the existing slug/churn-flow-transition models and provide further insights into the effect of μL on the transition. The existing models are categorized into two groups according to their response of the slug/churn transition to the increase in liquid superficial velocity (Vsl) on the Vsg/Vsl flow map. The first category exhibits a decrease in superficial gas velocity (Vsg) with the increase in Vsl at slug/churn (the transition concave to the left). The other one predicts an increase in Vsg with increasing of Vsl (the transition concave to the right). Analysis of the data set reveals that on the Vsg/Vsl flow map, the slug/churn transition moves toward lower superficial gas velocities as liquid viscosity increases and occurs approximately at a constant Vsg for low to medium Vsl. The predictions of these models were tested against the data set and poor results were shown by most models. The best performance is given by the Abdul-Majeed (1997) model. A dimensional analysis is applied in the present study to develop a new slug/churn-transition model. This analysis indicates that the transition is related to three dimensionless numbers, namely gas- and liquid-phase Froude numbers, in addition to the inverse liquid-viscosity number. An improved revision to the Abdul-Majeed model is achieved using these three dimensionless numbers. The revision enables the model to predict the transition for low, medium, and high liquid viscosity. The revised model clearly outperforms all the existing models for the present data and viscous data from independent studies. Furthermore, the revised model exhibits the expected trend against changes in pipe diameter and gas density.
在本研究中,我们研究了液体粘度(μL)对垂直管道中气体/液体流动的段塞/搅拌过渡的影响。来自两个不同来源的总共80个实验搅拌流数据点被汇编为一个数据集,涵盖了17.23至586mPa·s的液体粘度。在这些研究中,空气作为气相与两种不同的液体(含水甘油和商业合成矿物油)一起使用,在内径为0.0192米和0.0508米的垂直管道中流动。该数据集用于检查现有的段塞/搅拌流过渡模型,并进一步深入了解μL对过渡的影响。现有模型根据其对Vsg/Vsl流图上液体表观速度(Vsl)增加的段塞/搅拌转变的响应分为两组。第一类在段塞/搅拌器处(向左凹陷的过渡),随着Vsl的增加,表观气体速度(Vsg)降低。另一个预测Vsg随着Vsl的增加而增加(向右凹陷的过渡)。对数据集的分析表明,在Vsg/Vsl流动图上,随着液体粘度的增加,段塞/搅拌转变向较低的表观气体速度移动,并且在低至中等Vsl的大致恒定Vsg下发生。这些模型的预测是根据数据集进行测试的,大多数模型的结果都很差。Abdul-Majeed(1997)模型的性能最好。在本研究中应用量纲分析来建立一个新的段塞/搅拌过渡模型。该分析表明,这种转变与三个无量纲数有关,即气相和液相弗劳德数,以及液体粘度的倒数。使用这三个无量纲数对Abdul-Majeed模型进行了改进修正。该修正使模型能够预测低、中、高液体粘度的转变。就目前的数据和独立研究的粘性数据而言,修正后的模型明显优于所有现有模型。此外,修正后的模型显示了管道直径和气体密度变化的预期趋势。
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引用次数: 4
Compatibility Test and Nanoparticles Stability: Comparison between Smart Soft Water and Smart Hard Water 相容性测试与纳米颗粒稳定性:智能软水与智能硬水的比较
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-10-01 DOI: 10.2118/204218-pa
S. Ezzati, E. Khamehchi
Smart water is one of the most common methods for increasing oil recovery factor (RF) widely used in both sandstone and carbonate reservoirs. Smart water changes oil reservoir rock wettability from oil-wet to water-wet and increases oil RF. When smart water is combined with formation water, it can form sediments that will be called incompatibility, the results of which will be precipitation of inorganic scale deposition in surface facilities, flow lines, well tubing, gravel packs, and in the reservoirs. In contrast, by stabilizing the various nanoparticles in water, beneficial changes such as wettability alteration, sand production prevention, and decreased fines migration can be realized in oil reservoirs. Therefore, water compounds should be designed to have a minimum amount of incompatibility and the greatest amount of nanostability.For this study, the formation water and seawater were created in the laboratory. Seawater was diluted in different concentrations and combined with formation water, and the best-diluted seawater was selected. Sensitivity analysis was performed using the Taguchi algorithm on diluted water, and it was used to make smart soft water (SSW) and smart hard water (SHW). In this project, we aimed to compare the amount of incompatibility and nanostability in SSW and SHW. To analyze the amount of incompatibility, different compositions of SSW and SHW were made and combined with formation water. In all cases, soft water was more compatible with formation water. To compare stability, different nanofluids were made in optimized soft water and hard water. By testing the zeta potential, it was observed that soft water shows more stability. In general, this study proved two advantages of SSW over SHW.
智能水是提高采收率的最常见方法之一,广泛应用于砂岩和碳酸盐岩储层。智能水将油藏岩石的润湿性从油湿变为水湿,并增加石油RF。当智能水与地层水结合时,它可以形成称为不相容性的沉积物,其结果将是在地面设施、采气管线、井管、砾石充填和储层中沉淀无机垢沉积。相反,通过稳定水中的各种纳米颗粒,可以在油藏中实现润湿性改变、防砂和减少细粒迁移等有益变化。因此,水化合物应设计为具有最小量的不相容性和最大量的纳米稳定性。在这项研究中,地层水和海水是在实验室中产生的。对不同浓度的海水进行稀释,并与地层水混合,选出最佳稀释海水。使用田口算法对稀释水进行灵敏度分析,并将其用于制作智能软水(SSW)和智能硬水(SHW)。在这个项目中,我们旨在比较SSW和SHW中的不相容性和纳米稳定性。为了分析不相容性的大小,制备了不同组成的SSW和SHW,并将其与地层水结合。在所有情况下,软水与地层水更为相容。为了比较稳定性,在优化的软水和硬水中制备了不同的纳米流体。通过测试ζ电位,观察到软水显示出更大的稳定性。总的来说,本研究证明了SSW相对于SHW的两个优点。
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引用次数: 3
Study of Gel Plug for Temporary Blocking and Well-Killing Technology in Low-Pressure, Leakage-Prone Gas Well 低压易泄漏气井凝胶塞暂堵压井技术研究
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-10-01 DOI: 10.2118/204213-pa
Xiong Ying, Xu Yuan, Zhang Yadong, F. Ziyi
A gel-plug system for temporary blocking technology is proposed in this paper to address the prevalent leakage of killing fluid in low-pressure wells; the low technical strength of existing gel plugs for temporary blocking in well killing; difficult-to-control crosslinking time; and gel embrittlement and the difficulty of breaking certain gel plugs. A mixture of etherified galactomannan plant gum, isooctanol polyoxyethylene ether surfactant, and oil phase was used as a thickener. An inorganic salt complex containing long-chain polyhydroxy alcohol was used as a crosslinker and the concentration of long-chain polyhydroxy alcohol far exceeds the theoretical amount required to complex the metal ion. A mixture of polyhydroxy alcohol with a small amount of weak acid was used as a crosslinking regulator. Finally, a mixture of sodium thiosulfate and long-chain quaternary ammonium salt surfactant was used as a stabilizer. Laboratory evaluations showed that this gel-plug system can be directly pumped into the wellbore after being mixed homogeneously, and the viscosity of the system on the surface can be controlled by the amount of crosslinking regulator. The viscosity of the gel-plug system after gelling was high (viscoelastic solid colloid); the initial viscosity reached 30 000 mPa·s at 120°C and retained a semisolid gel shape after aging for 72 hours. Right-angle thickening occurred when the gel warmed to target-zone temperature. The acidic liquid breaker acted quickly, and the viscosity of the broken fluid was lower than 5 mPa·s after 1 to 4  hours. This gel plug for temporary blocking and well-killing technology was successfully applied in a low-pressure, leakage-prone gas well. No gas, pressure, or liquid remained in the open well after killing, the wellhead was successfully replaced, and the tubing was successfully removed. The gel plug also exhibited self-healing: The hole formed by the tubing could be filled and sealed automatically by the gel plug in the annulus. The static friction (outer wall) of 73-mm tubing in the gel plug was 39.6 t/km; the dynamic friction (outer wall) after tubing removal was 7.2 t/km. This gel plug thus shows promise as a temporary blocking technology in workover operations of low-pressure, leakage-prone gas wells.
针对低压井普遍存在的压井液泄漏问题,提出了一种适用于临时封堵技术的凝胶塞系统;现有用于压井临时封堵的凝胶塞技术强度低;交联时间难以控制;以及凝胶脆化和破坏某些凝胶塞的困难。将醚化的半乳甘露聚糖植物胶、异辛醇聚氧乙烯醚表面活性剂和油相的混合物用作增稠剂。使用含有长链多羟基醇的无机盐络合物作为交联剂,并且长链多羟醇的浓度远远超过络合金属离子所需的理论量。使用多羟基醇与少量弱酸的混合物作为交联调节剂。最后,使用硫代硫酸钠和长链季铵盐表面活性剂的混合物作为稳定剂。实验室评估表明,这种凝胶塞系统在混合均匀后可以直接泵入井筒,并且该系统在表面上的粘度可以通过交联调节剂的量来控制。凝胶化后的凝胶塞系统的粘度高(粘弹性固体胶体);在120°C时,初始粘度达到30000 mPa·s,老化72小时后仍保持半固体凝胶状 小时。当凝胶加热到目标区域温度时,出现直角增厚。酸性液体破胶剂作用迅速,破胶液1~4天后粘度低于5mPa·s 小时。该暂堵压井胶塞技术已成功应用于低压易漏气井。压井后,裸井中没有气体、压力或液体残留,井口成功更换,油管成功拆除。凝胶塞还表现出自修复性:环空中的凝胶塞可以自动填充和密封油管形成的孔。胶塞中73 mm油管的静摩擦(外壁)为39.6 t/km;油管拆除后的动摩擦(外壁)为7.2t/km。因此,这种凝胶塞有望成为低压、易泄漏气井修井作业中的一种临时封堵技术。
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引用次数: 7
Health, Safety, and Environment Operational Excellence through Full Utilization of Intelligent Field 充分利用智能领域实现健康、安全和环境卓越运营
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-10-01 DOI: 10.2118/203837-pa
K. Yateem, H. Muailu, Mohammed Gomaa, O. Ayoola
Working in the oil industry comes with unique challenges and risks, and so extra precautions and safety measures coupled with strict environmental compliance must be applied. Contrary to the common belief that strict safety enforcement could hinder smooth operations, the deployment of new technologies and enhanced solutions of processes has enabled operational excellence (OE) and improved safety performance. In this paper, we demonstrate health, safety, and environment performance improvement through implementing two main initiatives: The first category has initiatives that require less intervention or personnel; for example, the deployment of cableless pressure sensors or permanent monitoring systems in key wells to ensure continuous real-time pressure data to monitor reservoir pressure. The second category has initiatives that mitigate traditional health, safety, and environment risks; for example, through use of multiphase flow meters (MPFMs) to collect accurate and continuous flow measurements instead of traditional well testing. Optimizing operations costs while maintaining a high-level of safety is achieved through a dedicated team working in a state-of-the-art Production Operations Surveillance Hub (POSH), which enables the monitoring of wells in real time, making production optimization decisions, and ensuring a high level of well integrity via close monitoring of wells and assets.
在石油行业工作会带来独特的挑战和风险,因此必须采取额外的预防措施和安全措施,并严格遵守环境法规。与人们普遍认为严格的安全执法可能会阻碍顺利运营相反,新技术和增强的流程解决方案的部署实现了卓越运营(OE)并提高了安全性能。在本文中,我们通过实施两个主要举措来展示健康、安全和环境绩效的改善:第一类举措需要较少的干预或人员;例如,在关键井中部署无缆压力传感器或永久监测系统,以确保连续的实时压力数据来监测储层压力。第二类是减轻传统健康、安全和环境风险的举措;例如通过使用多相流量计(MPFM)来收集精确和连续的流量测量值而不是传统的试井。在保持高水平安全的同时优化运营成本是通过一个在最先进的生产运营监控中心(POSH)工作的专门团队实现的,该中心能够实时监控油井,做出生产优化决策,并通过密切监控油井和资产确保高水平的油井完整性。
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引用次数: 3
Direct Injection of Biomineralizing Agents to Restore Injectivity and Wellbore Integrity 直接注入生物矿化剂以恢复注入能力和井筒完整性
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-10-01 DOI: 10.2118/203845-pa
Catherine M. Kirkland, R. Hiebert, R. Hyatt, J. Mccloskey, J. Kirksey, Abby Thane, A. Cunningham, R. Gerlach, L. Spangler, Adrienne J Phillips
In this manuscript, we describe the second of two field demonstrations of microbially induced calcium carbonate precipitation (MICP) performed in a failed waterflood injection well in Indiana. In 2012, fracture-related flow pathways developed in the wellbore cement, causing injection water to bypass the oil-bearing formation and enter a high-permeability sandstone thief zone, thereby substantially decreasing injection pressure. In the first field demonstration, our study team characterized the well's mode of failure and successfully applied MICP to decrease flow through the defective cement. However, because the MICP treatment was conducted using a bailer delivery system, the degree of permeability reduction achievable was not adequate to fully restore the historic injection pressure of 1,400 psi at 1 gal/min. For the second field demonstration (reported herein), a direct injection system was developed that substantially increased the injection volume of MICP-promoting fluids. Two strategies were implemented to produce more ureolytic microbes: resuspending concentrated frozen cells immediately before injection and scaling up the bioreactor growth capacity. Multiple pulses of microbes and urea-calcium media were pumped into a string of 1-in.-diameter tubing separated by brine spacers and injected continuously at a flow rate of 3.4 to 1.4 gal/min. During the third day of injection, an injection pressure of 1,384 psi at a flow rate of 1.4 gal/min was achieved, and the experiment was terminated. This study demonstrates that MICP can be successfully used in large-volume applications where the time frame for the delivery of reactants is limited. This finding has significant relevance for commercialization of the MICP biotechnology in the oil and gas industry.
在这份手稿中,我们描述了在印第安纳州一口失败的注水井中进行的微生物诱导碳酸钙沉淀(MICP)的两个现场演示中的第二个。2012年,井筒水泥中形成了与裂缝相关的流动通道,导致注入水绕过含油层,进入高渗透砂岩贼带,从而大幅降低了注入压力。在第一次现场演示中,我们的研究团队描述了油井的失效模式,并成功地应用MICP来减少通过缺陷水泥的流量。然而,由于MICP处理是使用贝勒输送系统进行的,可实现的渗透率降低程度不足以完全恢复1400的历史注入压力 psi,1加仑/分钟。对于第二次现场演示(本文报道),开发了一种直接注射系统,该系统显著增加了MICP促进流体的注射体积。实施了两种策略来产生更多的解脲微生物:在注射前立即重悬浓缩的冷冻细胞和扩大生物反应器的生长能力。微生物和尿素钙介质的多个脉冲被泵送到1英寸的串中-直径的管道,所述管道由盐水间隔器分离并且以3.4至1.4加仑/分钟的流速连续注入。在注射的第三天,注射压力为1384 在1.4gal/min的流速下达到psi,并且终止实验。这项研究表明,MICP可以成功地用于反应物输送时间有限的大容量应用。这一发现对MICP生物技术在石油和天然气行业的商业化具有重要意义。
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引用次数: 8
Effect of Enhanced-Oil-Recovery Chemicals on Oil/Water-Separation Processes, from Laboratory Scale to Flow-Loop Scale 提高采收率化学品对油水分离过程的影响,从实验室规模到流动回路规模
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-10-01 DOI: 10.2118/200455-pa
C. Cassar, A. Mouret, M. Salaün, M. Klopffer
With the use of chemically based enhanced-recovery methods, water management, which has always been a major point in the production-operation processes, needs to be considered and adapted because the whole water cycle will be affected by the backproduced additives. Enhanced-oil-recovery (EOR) chemicals such as alkali molecules, high-molecular-weight polymers, or surfactant formulation will dramatically modify pH, viscosity, and phase behaviors of produced fluids. The main issues encountered in oil/water-separation processes are directly related to the risk of tight emulsion formation, which might considerably complicate the surface-water-treatment processes. The objective of this paper is to underline the effect of one of these chemicals, a surfactant formulation, on the produced-water cycle when they are backproduced first at a laboratory scale and second on a large-scale separation unit using an industrial-size flow loop and a well-instrumented separator. Our goal is first to investigate the impact of surfactant on the water/oil mixture separation efficiency, and second, to find an efficient demulsifier specific for this case. At the laboratory scale, the impact of surfactant within produced fluids on oil/water separation (regarding separation kinetics but also oil/water phase qualities) will be evaluated by performing bottle tests. Those laboratory bottle tests enabled us to screen different parameters, such as the surfactant concentration, the water cut that can strongly affect the type of formed emulsion [oil in water (O/W) or water in oil (W/O)], and its stability. The oil/water phase qualities were quantified and correlations with parameters related to the large-scale experiment were drawn, helping us in defining the key parameters for this campaign. Indeed, to get closer to a field case, a semi-industrial-scale test platform was used. The flow loop reproduces separation process conditions encountered in a field treatment facility, including the production separator, the controlled temperature, and the oilfield chemical injection rate. The main operating conditions are liquid flow rates and temperature. The influence of different parameters can be studied, such as the surfactant concentration, mixing conditions, residence time, water cut, and the presence of chemicals that will help the separation process. Different types of emulsions were formed depending on the conditions, and their stability was evaluated through the measurement of separation profiles using a single electrode capacitance probe (SECAP) within the separator. The results obtained show how the surfactant, as well as the demulsifier concentration, have led to different types of emulsions and have affected the oil/water separation processes. These tests have confirmed that separation is more difficult in the presence of surfactant and that water quality was degraded. It has also been shown that separation processes can be greatly improved by adding some EOR-compliant dem
随着化学提高采收率方法的使用,水管理一直是生产操作过程中的一个重点,需要考虑和适应,因为整个水循环将受到后产添加剂的影响。提高采收率(EOR)的化学物质,如碱分子、高分子量聚合物或表面活性剂配方,会显著改变产出流体的pH值、粘度和相行为。油水分离过程中遇到的主要问题与致密乳化液形成的风险直接相关,这可能会使地表水处理过程变得相当复杂。本文的目的是强调这些化学物质中的一种,表面活性剂配方,当它们首先在实验室规模上回采,然后在使用工业规模的流动回路和设备齐全的分离器的大型分离装置上回采时,对产出水循环的影响。我们的目标首先是研究表面活性剂对水/油混合物分离效率的影响,其次是找到一种针对这种情况的高效破乳剂。在实验室规模下,将通过进行瓶试来评估采出液中表面活性剂对油水分离的影响(涉及分离动力学和油水相质量)。这些实验室瓶子测试使我们能够筛选不同的参数,如表面活性剂浓度、对形成的乳化液类型(油包水(O/W)或油包水(W/O))有强烈影响的含水率及其稳定性。对油/水相质量进行了量化,并绘制了与大规模实验相关参数的相关性,帮助我们确定了该活动的关键参数。事实上,为了更接近现场情况,我们使用了半工业规模的测试平台。流动回路再现了现场处理设施中遇到的分离过程条件,包括生产分离器、受控温度和油田化学剂注入速度。主要操作条件是液体流量和温度。可以研究不同参数的影响,如表面活性剂浓度、混合条件、停留时间、含水率和有助于分离过程的化学物质的存在。根据不同的条件形成不同类型的乳液,并通过在分离器内使用单电极电容探头(SECAP)测量分离曲线来评估其稳定性。结果表明,表面活性剂和破乳剂的浓度会产生不同类型的乳剂,并对油水分离过程产生影响。这些试验证实,在表面活性剂存在的情况下,分离更加困难,水质下降。研究还表明,与表面活性剂相比,加入符合eor要求的破乳剂可以大大改善分离过程,获得更好的水质。实验室工作流程,以及使用工业尺寸分离器进行的大规模实验,可以帮助最大限度地降低操作风险,减轻这些分离问题带来的挑战。这项工作表明,对于含有提高采收率化学品的产出液来说,水管理是一个主要挑战,需要一种综合的方法,应该事先进行研究。
{"title":"Effect of Enhanced-Oil-Recovery Chemicals on Oil/Water-Separation Processes, from Laboratory Scale to Flow-Loop Scale","authors":"C. Cassar, A. Mouret, M. Salaün, M. Klopffer","doi":"10.2118/200455-pa","DOIUrl":"https://doi.org/10.2118/200455-pa","url":null,"abstract":"With the use of chemically based enhanced-recovery methods, water management, which has always been a major point in the production-operation processes, needs to be considered and adapted because the whole water cycle will be affected by the backproduced additives. Enhanced-oil-recovery (EOR) chemicals such as alkali molecules, high-molecular-weight polymers, or surfactant formulation will dramatically modify pH, viscosity, and phase behaviors of produced fluids. The main issues encountered in oil/water-separation processes are directly related to the risk of tight emulsion formation, which might considerably complicate the surface-water-treatment processes.\u0000 The objective of this paper is to underline the effect of one of these chemicals, a surfactant formulation, on the produced-water cycle when they are backproduced first at a laboratory scale and second on a large-scale separation unit using an industrial-size flow loop and a well-instrumented separator.\u0000 Our goal is first to investigate the impact of surfactant on the water/oil mixture separation efficiency, and second, to find an efficient demulsifier specific for this case. At the laboratory scale, the impact of surfactant within produced fluids on oil/water separation (regarding separation kinetics but also oil/water phase qualities) will be evaluated by performing bottle tests.\u0000 Those laboratory bottle tests enabled us to screen different parameters, such as the surfactant concentration, the water cut that can strongly affect the type of formed emulsion [oil in water (O/W) or water in oil (W/O)], and its stability. The oil/water phase qualities were quantified and correlations with parameters related to the large-scale experiment were drawn, helping us in defining the key parameters for this campaign.\u0000 Indeed, to get closer to a field case, a semi-industrial-scale test platform was used. The flow loop reproduces separation process conditions encountered in a field treatment facility, including the production separator, the controlled temperature, and the oilfield chemical injection rate. The main operating conditions are liquid flow rates and temperature. The influence of different parameters can be studied, such as the surfactant concentration, mixing conditions, residence time, water cut, and the presence of chemicals that will help the separation process. Different types of emulsions were formed depending on the conditions, and their stability was evaluated through the measurement of separation profiles using a single electrode capacitance probe (SECAP) within the separator.\u0000 The results obtained show how the surfactant, as well as the demulsifier concentration, have led to different types of emulsions and have affected the oil/water separation processes. These tests have confirmed that separation is more difficult in the presence of surfactant and that water quality was degraded. It has also been shown that separation processes can be greatly improved by adding some EOR-compliant dem","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-10-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/200455-pa","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"42808086","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 3
Productivity Improvement by Reperforation of Multistage-Fractured Wells in High-Pressure/High-Temperature Tight Gas Reservoirs: A Case History 高压高温致密气藏多级压裂井再射孔提高产能的实例研究
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-09-01 DOI: 10.2118/197590-pa
Ryosuke Kidogawa, N. Yoshida, K. Fuse, Yuta Morimoto, K. Takatsu, Keisuke Yamamura
Productivity of multistage-fractured gas wells is possibly degraded by conductivity impairments and non-Darcy flow during long-term production. Such degradations are pronounced by flow convergence to short perforated intervals, while it is challenging to identify degraded stages for remediation. Moreover, remedial actions can be expensive under a high-pressure/high-temperature (HP/HT) environment. A field case demonstrates successful application of reperforation as a cost-effective way to mitigate the flow convergence by prioritizing targets with multirate production-logging (PL) results. This work presents theoretical investigations using numerical simulations and field execution of reperforation for a well with six-stage fracturing treatments in a HP/HT volcanic gas reservoir onshore Japan. Apparent conductivity reduction was suspected during more than 15 years of production, and it was pronounced by non-Darcy flow effects associated with flow convergence to short perforated intervals. Multirate PL was used to identify impaired stages by quantifying the inflow-performance relationship (IPR) of each stage under transient flow-after-flow (FAF) testing. The impaired stages were reperforated, adding perforation intervals with wireline-conveyed perforators. Pressure-buildup (PBU) tests before and after the job and post-job PL were used to validate productivity improvements. Target zones for reperforations were identified and prioritized with results of the multirate PL conducted. The stage IPRs were drawn, and relatively large non-Darcy effects were identified in three stages by shapes of the IPRs and/or decreasing inflow contributions as the surface rate increased. Also, a temperature log showed steep temperature change at the bottom of the fourth stage; the fracture might propagate below the perforated interval. Ranges of production increment were estimated using a numerical model calibrated against the estimated stage IPRs. The estimated increment was in the range of 15 to 30% with the planned reperforation program, while its magnitude depended on the connection between new perforations and existing fractures. Afterward, the reperforation job was performed and the gas rate was confirmed to be increased by 26% with the same wellhead pressure after 1 month of production. The post-job PL was conducted 3 months after the reperforation. The well IPR was improved, implying reduction of the non-Darcy effects. Results of PBU tests also indicated reduction of skin factor. The stage IPRs were redrawn with the post-job PL, and they suggested clear improvements in two stages where screenout occurred during fracturing treatments and a stage where significant non-Darcy effect was suspected. The workflow and strategy in this paper can be applied for productivity restoration in a cost-effective way to multistage-fractured gas wells with short perforated intervals and impaired apparent conductivity during long-term production. Especially, the interpreted res
在长期生产过程中,多级压裂气井的产能可能会因导电性受损和非达西流动而降低。这种退化通过流收敛到短穿孔间隔而明显,而确定修复的退化阶段具有挑战性。此外,在高压/高温(HP/HT)环境下,补救措施可能是昂贵的。一个现场案例表明,通过对具有多速率生产测井(PL)结果的目标进行优先级排序,再射孔作为一种经济高效的方法成功应用,可以缓解流量收敛。本工作采用数值模拟和现场执行的方法,对日本陆上高压/高温火山气藏中一口采用六阶段压裂处理的井进行了理论研究。在超过15年的生产过程中,人们怀疑表观电导率降低,并且与流收敛到短射孔层段相关的非达西流效应使其显著。多速率PL用于通过量化瞬态流量(FAF)测试下每个阶段的流入性能关系(IPR)来识别受损阶段。受损阶段重新射孔,用钢丝绳输送的射孔器增加射孔间隔。使用作业前后和作业后PL的压力累积(PBU)测试来验证生产力的提高。根据进行的多速率PL的结果,确定了再穿孔的目标区域并确定了优先顺序。绘制了阶段IPR,通过IPR的形状和/或随着地表速率的增加而减少的流入贡献,在三个阶段中确定了相对较大的非达西效应。此外,温度日志显示第四阶段底部的温度变化剧烈;裂缝可能在射孔层段下方扩展。使用根据估计阶段IPR校准的数值模型来估计产量增量的范围。根据计划的再射孔计划,估计增量在15%至30%的范围内,而其大小取决于新射孔和现有裂缝之间的连接。之后,进行了重新穿孔工作,并确认在生产1个月后,在相同的井口压力下,气体速率增加了26%。术后PL在再穿孔后3个月进行。井IPR得到改善,意味着非达西效应的减少。PBU测试结果也表明皮肤因子降低。用作业后PL重新绘制了阶段IPR,它们表明在压裂处理期间出现筛选的两个阶段和怀疑存在显著非达西效应的一个阶段有明显的改进。本文的工作流程和策略可以以一种具有成本效益的方式应用于长期生产中射孔间隔短、表观电导率受损的多级压裂气井的产能恢复。特别是,解释的结果表明,在压裂处理过程中出现筛选的阶段,所提出的方法对提高生产力是有效的。此外,还讨论了仔细的PL测试设计的重要性,因为它们是成功的关键。
{"title":"Productivity Improvement by Reperforation of Multistage-Fractured Wells in High-Pressure/High-Temperature Tight Gas Reservoirs: A Case History","authors":"Ryosuke Kidogawa, N. Yoshida, K. Fuse, Yuta Morimoto, K. Takatsu, Keisuke Yamamura","doi":"10.2118/197590-pa","DOIUrl":"https://doi.org/10.2118/197590-pa","url":null,"abstract":"\u0000 Productivity of multistage-fractured gas wells is possibly degraded by conductivity impairments and non-Darcy flow during long-term production. Such degradations are pronounced by flow convergence to short perforated intervals, while it is challenging to identify degraded stages for remediation. Moreover, remedial actions can be expensive under a high-pressure/high-temperature (HP/HT) environment. A field case demonstrates successful application of reperforation as a cost-effective way to mitigate the flow convergence by prioritizing targets with multirate production-logging (PL) results.\u0000 This work presents theoretical investigations using numerical simulations and field execution of reperforation for a well with six-stage fracturing treatments in a HP/HT volcanic gas reservoir onshore Japan. Apparent conductivity reduction was suspected during more than 15 years of production, and it was pronounced by non-Darcy flow effects associated with flow convergence to short perforated intervals. Multirate PL was used to identify impaired stages by quantifying the inflow-performance relationship (IPR) of each stage under transient flow-after-flow (FAF) testing. The impaired stages were reperforated, adding perforation intervals with wireline-conveyed perforators. Pressure-buildup (PBU) tests before and after the job and post-job PL were used to validate productivity improvements.\u0000 Target zones for reperforations were identified and prioritized with results of the multirate PL conducted. The stage IPRs were drawn, and relatively large non-Darcy effects were identified in three stages by shapes of the IPRs and/or decreasing inflow contributions as the surface rate increased. Also, a temperature log showed steep temperature change at the bottom of the fourth stage; the fracture might propagate below the perforated interval. Ranges of production increment were estimated using a numerical model calibrated against the estimated stage IPRs. The estimated increment was in the range of 15 to 30% with the planned reperforation program, while its magnitude depended on the connection between new perforations and existing fractures. Afterward, the reperforation job was performed and the gas rate was confirmed to be increased by 26% with the same wellhead pressure after 1 month of production. The post-job PL was conducted 3 months after the reperforation. The well IPR was improved, implying reduction of the non-Darcy effects. Results of PBU tests also indicated reduction of skin factor. The stage IPRs were redrawn with the post-job PL, and they suggested clear improvements in two stages where screenout occurred during fracturing treatments and a stage where significant non-Darcy effect was suspected.\u0000 The workflow and strategy in this paper can be applied for productivity restoration in a cost-effective way to multistage-fractured gas wells with short perforated intervals and impaired apparent conductivity during long-term production. Especially, the interpreted res","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/197590-pa","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"48934531","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
引用次数: 4
Benchmarking of Pulsed Field Gradient Nuclear Magnetic Resonance as a Demulsifier Selection Tool with Arabian Light Crude Oils 脉冲场梯度核磁共振作为阿拉伯轻质原油破乳剂选择工具的标杆试验
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-09-01 DOI: 10.2118/203820-pa
D. S. Marques, R. White, Sajjad Al-Khabaz, Mustafa Al-Talaq, Jabr Al-Buainain
The use of chemical demulsifiers in the treatment of crude oil emulsions is an essential step in processing facilities worldwide. Each production facility requires specific demulsifier reformulations as the crude characteristics change. The assessment of candidate demulsifiers before online field trials is currently done with bottle tests. Such tests are manual, based on water dropout visually measured by operators. The development of a method that can automatically determine the speed and amount of water dropout without the laborious need to manually record water separation would significantly decrease human error. Pulsed field gradient nuclear magnetic resonance (PFG-NMR) is used as a classification tool to qualitatively rank the efficiency of different demulsifiers in breaking Arabian Light emulsions. This imaging method can evaluate demulsifier action based on the emulsion characteristics; for example, rate of sedimentation and coalescence and formation of a dense packed zone (rag layer). The results are validated against field trials performed in gas-oil separation plants (GOSPs) at two Saudi Arabian facilities. There was good agreement between the PFG-NMR method and field trials. The results were found to correspond to the water dropout in the first stage of crude oil treatment in processing plants (production traps).
在世界各地的加工设施中,使用化学破乳剂处理原油乳液是必不可少的一步。随着原油特性的变化,每个生产设施都需要特定的破乳剂配方。在线现场试验之前对候选破乳剂的评估目前是通过瓶子测试进行的。这种测试是手动的,基于操作员目测的水滴。开发一种可以自动确定滴水速度和水量的方法,而无需手动记录分水情况,这将大大减少人为误差。脉冲场梯度核磁共振(PFG-NMR)作为一种分类工具,用于对不同破乳剂破乳剂的效率进行定性排序。这种成像方法可以根据乳状液的特性来评价破乳剂的作用;例如沉积和聚结的速率以及致密填充区(碎布层)的形成。该结果通过在沙特阿拉伯两个设施的油气分离厂(GOSP)进行的现场试验进行了验证。PFG-NMR方法与现场试验之间有很好的一致性。发现结果与加工厂(生产阱)原油处理第一阶段的失水情况一致。
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引用次数: 1
Experimental Investigation of Polymer-Induced Fouling of Heater Tubes in the First-Ever Polymer Flood Pilot on Alaska North Slope 阿拉斯加北坡首次聚合物驱试验中加热管聚合物诱导结垢的实验研究
IF 1.2 4区 工程技术 Q2 Energy Pub Date : 2020-08-30 DOI: 10.2118/200463-ms
Anshul Dhaliwal, Yin Zhang, A. Dandekar, S. Ning, J. Barnes, R. Edwards, W. Schulpen, D. Cercone, J. Ciferno
Polymer flooding is being pilot tested for the first time in the Schrader Bluff viscous oil reservoir at the Milne Point Field on Alaska North Slope (ANS). One of the major concerns of the operator is the impact of polymer on the oil production system after polymer breakthrough, especially the polymer-induced fouling issues in the heat exchanger. This study investigates the propensity of polymer fouling on the heater tubes as a function of different variables, with the ultimate goal of determining safe and efficient operating conditions. A unique experimental setup was designed and developed in-house to simulate the fouling process on the heating tube. The influence of heating tube skin temperature, tube material, and polymer concentration on fouling tendency was investigated. Each test was run five times with the same tube, and in each run, the freshly prepared synthetic brine and polymer solution was heated from 77°F to 122°F to mimic field-operating conditions. The heating time and fouling amount were recorded for each run. Cloud point measurement has also been conducted to find the critical temperature at which the polymer in solution becomes unstable and precipitates out. The morphology and composition of the deposit samples were analyzed by environmental scanning electron microscopy (ESEM) and X-ray diffraction (XRD), respectively. It was found that the presence of polymer in produced fluids would aggravate the fouling issues on both carbon steel and stainless steel surfaces at all tested skin temperatures. Only higher skin temperatures of 250°F and 350°F could cause polymer-induced fouling issues on the copper tube surface, and the fouling tendency increased with polymer concentration. At the lower skin temperatures of 165°F, no polymer-induced fouling was identified on the copper tube. A critical temperature that is related to the cloud point of the polymer solution was believed to exist, below which polymer-induced fouling would not occur and only mineral scale was deposited but above which the polymer would aggravate the fouling issue. The cloud point of the tested polymer solution was determined to be between 220°F and 230°F. From a practical safer design standpoint, we recommend a value of 220°F for operational purposes on the pilot site. The heating efficiency of the tube would be decreased gradually as more fouling material accumulates on its surface. If polymer precipitated and deposited on the surface, it would bond to the mineral crystals to form a robust three-dimensional network structure, resulting in a rigid polymer-induced fouling. The study results have provided practical guidance to the field operator for the ongoing polymer flooding pilot test on ANS.
聚合物驱首次在阿拉斯加北坡Milne Point油田的Schrader Bluff稠油油藏进行了试点测试。作业公司主要关注的问题之一是聚合物突破后对采油系统的影响,特别是聚合物引起的热交换器结垢问题。本研究探讨了聚合物污染在加热管上的倾向作为不同变量的函数,最终目标是确定安全和有效的操作条件。设计并开发了一套独特的实验装置来模拟加热管的结垢过程。研究了热管表面温度、管材和聚合物浓度对结垢倾向的影响。每次测试使用同一管进行5次,每次测试中,将新制备的合成盐水和聚合物溶液从77°F加热到122°F,以模拟现场操作条件。记录每次运行的加热时间和污垢量。还进行了云点测量,以确定溶液中的聚合物变得不稳定并析出的临界温度。采用环境扫描电子显微镜(ESEM)和x射线衍射仪(XRD)对样品的形貌和成分进行了分析。研究发现,在所有测试的表面温度下,生产液中聚合物的存在都会加剧碳钢和不锈钢表面的污垢问题。只有较高的表面温度(250°F和350°F)才会引起铜管表面聚合物诱导的结垢问题,并且随着聚合物浓度的增加,结垢倾向增加。在较低的表面温度为165°F时,铜管上没有发现聚合物引起的污染。认为存在一个与聚合物溶液的浊点有关的临界温度,低于该温度聚合物诱导的结垢不会发生,只会沉积矿物垢;高于该温度聚合物会加剧结垢问题。被测聚合物溶液的浊点在220°F和230°F之间。从实际安全设计的角度来看,我们建议在试验现场的操作中使用220°F的值。随着积垢物的增多,热管的热效率会逐渐降低。如果聚合物沉淀并沉积在表面,它将与矿物晶体结合形成坚固的三维网络结构,从而导致刚性聚合物诱导的污垢。研究结果为现场作业人员在ANS上进行聚合物驱先导试验提供了实用指导。
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引用次数: 10
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