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Establishing Stable Gas Production by Squeezing a Novel Halite Inhibitor into High Temperature Texas Gas Wells 德克萨斯高温气井采用新型盐石抑制剂实现稳定产气
Pub Date : 2018-06-20 DOI: 10.2118/190736-MS
C. Okocha, Suyung Wang, A. Kaiser, J. Wylde
Halite precipitation from gas reservoir brines can cause significant decreases in hydrocarbon production or even complete blockage of the well. This has led to many gas wells either producing at diminished rates or being abandoned. Production decline related to halite scale is routinely treated with water washes either in a continuous system or with "mini squeezes" where water is batched in and held for few hours before production resumes usually with increased pressure. Introduction of halite inhibitors as part of the water wash or squeeze treatment has contributed to increased production by reducing the frequency and quantity of water used for treatment. This paper summarizes the work performed to deliver to the industry a high-temperature, high-performance halite scale inhibitor. The product chemistry offers a true step-change in performance from existing technologies because of its high-temperature stability and halite inhibition efficiency at 420°F (bottom-hole temperature). An industry best-in-class rapid screening technique (kinetic turbidity test) was used to systematically evaluate all current technologies in the market place and to develop a detailed understanding on structure-performance relationships of functional groups. The resulting correlations led to synthesis of novel high-temperature stable chemistries with significantly superior inhibition on halite. This paper also presents field cases of halite squeeze treatments from two different fields; an ultra hot (420°F) deep (17,460ft) dolomite gas well with severe halite deposition that required water washing every 48-72 hours and a shallow (6,000ft) hot (250°F) shale with erratic production where several water washes, work-overs and varied shut in periods did little to improve production. The ultra hot, deep well case history comes from a field in Texas where a detailed program of work was undertaken that led to squeezing in the halite inhibitor. Halite deposition had forced the operator to reduce production rates, with frequent workover to treat the well mainly with fresh water washes every 48 to 72 hours. After the introduction of the halite inhibitor, the gas well had been continuously producing for 40 days at the first instance and 60 days when the halite inhibitor dosage was increased. This is a marked improvement for the well and saves significant operating cost from well entries and deferred/lost production. The paper describes a detailed methodology of halite inhibitor selection and the influence that temperature, pressure and salinity has upon application. Field application case histories share important lesson learned with regards to water washing volumes (small and large water washes) as well as the impact of extended shut in period on squeeze lifetime. These squeeze treatments provide valuable field insights to salt formation and prevention in gas wells and the use of the novel high-temperature inhibitor shows a new industry capability of inhibiting halite formation
从气藏卤水中析出的岩盐会导致油气产量显著下降,甚至导致井完全堵塞。这导致许多气井要么产量下降,要么被废弃。与岩盐结垢相关的产量下降通常采用连续系统水洗或“微型挤压”处理,即将水分批注入并保持几个小时,然后通常在增加压力的情况下恢复生产。作为洗水或挤压处理的一部分,引入卤石抑制剂有助于减少处理用水的频率和数量,从而提高产量。本文总结了为向行业提供高温、高性能盐石阻垢剂所做的工作。由于其高温稳定性和420°F(井底温度)下的岩盐抑制效率,该产品的化学性质与现有技术相比有了真正的阶段性变化。一种业界一流的快速筛选技术(动态浊度测试)被用于系统地评估市场上现有的所有技术,并对官能团的结构-性能关系进行详细的了解。由此产生的相关性导致合成了新的高温稳定的化学物质,对卤石的抑制作用显著优于其他化学物质。本文还介绍了两个不同油田的岩盐挤压处理的现场实例;超高温(420°F)深(17460英尺)白云岩气井,岩盐沉积严重,每48-72小时需要洗一次水;浅层(6000英尺)高温(250°F)页岩,产量不稳定,多次洗水、修井和不同的关井周期对提高产量几乎没有帮助。超高温深井案例来自德克萨斯州的一个油田,该油田进行了详细的工作计划,导致了岩盐抑制剂的挤压。岩盐沉积迫使作业者降低产量,频繁修井,每隔48至72小时进行一次淡水洗井。加入盐石抑制剂后,气井第一次连续生产40天,增加盐石抑制剂用量后连续生产60天。这对井来说是一个显著的改进,并节省了大量的作业成本,包括进井和延迟/漏产。本文详细介绍了盐石抑制剂的选择方法,以及温度、压力和盐度对应用的影响。现场应用案例历史分享了关于洗水量(小水洗量和大水洗量)以及延长关井时间对挤压寿命的影响的重要经验。这些挤压处理为气井的盐层形成和预防提供了有价值的现场见解,新型高温抑制剂的使用显示了在高达450°F的高温气井中抑制岩盐形成的新行业能力。成功的现场试验证明了这一点,在不降低油管/生产压力的情况下,以更高的压降速率增加了天然气产量。
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引用次数: 1
Extending Reservoir Knowledge from the Produced Data 从生产数据中扩展油藏知识
Pub Date : 2018-06-20 DOI: 10.2118/190753-MS
Oleg Ishkov, E. Mackay
Understanding the reservoir connectivity advances engineering and management decisions and enhances overall field performance. A method to investigate injector to producer connectivity from an identified proportion of the injected brine in the produced water is proposed. Chloride, sodium, boron and lithium are ideal tracers: typically they do not participate in geochemical reactions. These ions track injection water without retardation, and if their concentration differences with formation brine are high enough to overcome measurement errors, then they may be used as indicators of the mixing ratio between injection and formation brines. This paper proposes the use of this mixing ratio to distinguish brines and to calculate the normalised contribution of injected water in the cumulative produced water volume. A producer to injector connectivity plot allows engineers to categorise the pressure support for production wells in one plot. This approach was applied to North Sea field data. A mineral scaling risk analysis was performed using the Injector Contribution characteristic plot. Wells being supported by commingled injected seawater and aquifer water were most at risk of BaSO4 precipitation. Historic data for a field case were analysed to examine potential scaling regimes. A set of well candidates for enhanced oil recovery to reduce residual oil in the oil leg was also identified. Most of the water produced in these wells came from injectors, rather than from the aquifer. Those wells have good communication throughout the oil leg and as a result quick water breakthrough occurs. As well as resulting in an early onset of BaSO4 scaling, an Enhanced Oil Recovery (EOR) chemical that is injected would more quickly reach the producers and therefore the potential for chemical EOR applications can be measured. This suggested metric helps to identify that other wells do not experience much seawater production, but are more strongly supported by the aquifer, and so there would be no apparent benefit in reducing residual oil by injecting chemical. This set of wells might benefit potentially from infill drilling nearby, or conformance control methods. The proposed technique does not require additional sampling to be performed over and above the measured historical produced water compositions that are routinely collected by operators during offshore production for scale management purposes. The analysis to select well candidates for EOR or areas for infill drilling is significantly more challenging using a conventional approach, and we propose that this novel metric of "Producer to Injector connectivity" will be beneficial for the decision making process.
了解储层连通性有助于制定工程和管理决策,并提高整体油田性能。提出了一种从采出水中确定比例的注入盐水来研究注入器与采出器连通性的方法。氯化物、钠、硼和锂是理想的示踪剂:它们通常不参与地球化学反应。这些离子无阻滞地跟踪注入水,如果它们与地层盐水的浓度差异足够大,可以克服测量误差,那么它们可以作为注入水与地层盐水混合比的指标。本文建议使用该混合比例来区分盐水,并计算注入水在累积采出水量中的归一化贡献。生产井与注入井连通性图允许工程师将生产井的压力支持划分为一个图。该方法已应用于北海油田数据。利用注入器贡献特征图进行了矿物结垢风险分析。混合注入海水和含水层水的井最容易发生BaSO4降水。分析了一个现场案例的历史数据,以检查潜在的结垢机制。还确定了一组提高采收率以减少油腿剩余油的候选井。这些井产出的大部分水来自注入器,而不是含水层。这些井在整个油腿上具有良好的连通,因此可以快速见水。除了导致BaSO4结垢的早期发生外,注入一种提高石油采收率(EOR)的化学物质可以更快地到达生产商,因此可以测量化学EOR应用的潜力。这一指标有助于确定其他油井的产海水量不大,但受含水层的支持更强,因此通过注入化学物质来减少剩余油没有明显的好处。这组井可能会从附近的填充钻井或一致性控制方法中获益。该技术不需要在测量的历史产出水成分之外进行额外的采样,这些成分是由作业者在海上生产过程中为规模管理目的而常规收集的。使用常规方法分析选择EOR候选井或填充钻井区域的难度要大得多,我们提出这种“生产者到注入器连通性”的新指标将有利于决策过程。
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引用次数: 0
Scale Deposition and Hydrodynamics - Benchtop to Pilot Rig 水垢沉积和流体动力学-从台式到先导钻机
Pub Date : 2018-06-20 DOI: 10.2118/190756-MS
N. Goodwin, M. May, D. Nichols, G. Graham
Scale deposition in oilfield production systems is influenced by thermodynamic supersaturation and kinetics, but also by hydrodynamic effects such as surface shear stress and turbulence. Results from experimental work investigating the impact of these hydrodynamic factors on scale location and correlating them to field flow regimes are presented. Laboratory tests have been conducted using both a benchtop jet impingement method and large-scale, high flow rate "pilot rig" apparatus. Both of these systems result in high shear stress conditions and can simulate hydrodynamic regimes representative of those expected in devices such as inflow control valves, inflow control devices, and sand control screens. The pilot rig is able to reproduce field-representative flow rates and fluid flow dynamics through full-size test pieces containing nozzles and restrictions. The results of this work demonstrate that the hydrodynamic regime has a significant influence on scale deposition. Increased levels of surface shear stress and turbulence result in a greater potential for scale formation than low shear, laminar flow conditions. This is particularly apparent in systems which are mildly supersaturated. The location of scale deposits was found to correlate with local shear stress and the pilot rig tests confirmed field observations that zones experiencing the highest level of shear are not necessarily those with the greatest deposit; the induced scale may deposit downstream in areas of lower surface shear. Additionally, the presence of these high shear locations upstream of the lower shear regime may lead to scaling in the lower shear region which would otherwise not be experienced. Supportive Computational Fluid Dynamic modelling of fluid flow within the pilot rig system correlated with the experimental findings is also described. This work allows a greater understanding of the hydrodynamic factors, in particular surface shear stress, influence oilfield scale deposition and has demonstrated the utility of both benchtop and pilot-scale methods for testing under appropriate conditions.
油田生产系统中的结垢沉积不仅受到热力学过饱和和动力学的影响,还受到表面剪切应力和湍流等流体动力学效应的影响。实验研究了这些水动力因素对水垢定位的影响,并将其与场流型相关联。使用台式射流撞击法和大型大流量“先导钻机”装置进行了实验室测试。这两种系统都会产生高剪切应力条件,并且可以模拟流体动力学状态,代表流入控制阀、流入控制装置和防砂筛管等设备所期望的状态。该试验钻机能够通过包含喷嘴和限制的全尺寸测试件再现具有现场代表性的流速和流体流动动力学。研究结果表明,水动力机制对水垢沉积有重要影响。与低剪切、层流条件相比,表面剪切应力和湍流水平的增加导致结垢的可能性更大。这在轻度过饱和的系统中尤为明显。发现鳞状沉积物的位置与局部剪切应力有关,试点钻机试验证实了现场观测结果,即剪切水平最高的区域不一定是沉积物最多的区域;诱导水垢可能在下游的下表面剪切区沉积。此外,这些低剪切区上游的高剪切位置的存在可能导致低剪切区结垢,否则将不会经历这种情况。还描述了与实验结果相关的先导钻机系统内流体流动的支持性计算流体动力学模型。这项工作可以更好地了解影响油田规模沉积的流体动力因素,特别是地表剪切应力,并证明了在适当条件下,台式和中试规模测试方法的实用性。
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引用次数: 3
Impact of Gas Hydrate Inhibitors on Halite Scale Precipitation: An Experimental and Morphological Investigation 气体水合物抑制剂对盐垢沉淀的影响:实验和形态学研究
Pub Date : 2018-06-20 DOI: 10.2118/190707-MS
S. Hosseini, E. Joonaki, J. Buckman, B. Ruggeri, B. Tohidi
Inorganic scale deposition is one of the most serious flow assurance problems. One of these exotic scales is halite (NaCl). Injection of hydrate inhibitors (HIs) [methanol, monoethylene glycol (MEG), triethylene glycol (TEG)] to prevent plugging of flow lines and tubing could induce precipitation of halite scales. Thus, utilizing these chemicals might adversely affect salt solubility, causing scaling problems, particularly halite scales, in high total dissolved solid (TDS) brines. In this study, the influence of HIs on scaling of a supersaturated NaCl solution with and without inhibitor was experimentally investigated. The results of these experiments show that increasing the concentration of HIs results in a higher amount of halite precipitation. Moreover, the effect of methanol on halite precipitation is more severe compared to MEG and TEG. On the other hand, the static efficiency results illustrate that raising the concentration of HI reduces the scale inhibition efficiency in the presence of methanol and TEG to a lower extent, while the inhibitor could have a 100% inhibition efficiency in the MEG solution. Furthermore, in the case of methanol, the optimum inhibition efficiencies at HI concentrations of 10 and 40 wt% were observed at SI concentrations of 500 and 200 ppm, respectively. Alterations in the morphology of halite in the presence of HIs were analyzed using optical microscopy and environmental scanning electron microscopy (ESEM) techniques. In this study, the effect of morphology changes of halite due to the addition of HI is addressed for the first time. These investigations can help provide a better understanding of the mechanism of halite scaling in the presence of HIs.
无机水垢沉积是最严重的流动保障问题之一。这些外来鳞片之一是盐石(NaCl)。注入水合物抑制剂(HIs)[甲醇、单乙二醇(MEG)、三甘醇(TEG)]以防止管线和油管堵塞,可引起岩盐垢的沉淀。因此,使用这些化学物质可能会对盐的溶解度产生不利影响,在高总溶解固体(TDS)盐水中引起结垢问题,特别是盐石结垢。在本研究中,实验研究了HIs对有和无抑制剂的过饱和NaCl溶液结垢的影响。这些实验结果表明,增加HIs浓度会导致更多的盐石沉淀。此外,甲醇对岩盐沉淀的影响比MEG和TEG更严重。另一方面,静态效率结果表明,在甲醇和TEG存在的情况下,提高HI浓度会降低阻垢效率,而在MEG溶液中可以达到100%的阻垢效率。此外,在甲醇的情况下,在SI浓度分别为500和200 ppm时,观察到HI浓度为10%和40 wt%时的最佳抑制效率。利用光学显微镜和环境扫描电子显微镜(ESEM)技术分析了HIs存在下岩盐形态的变化。本研究首次探讨了HI的加入对岩盐形态变化的影响。这些研究有助于更好地理解在HIs存在下岩盐结垢的机制。
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引用次数: 5
Management of Scale Control in Produced Water Reinjection - The Near Wellbore Scale Challenge Overcome 采出水回注中结垢控制的管理——克服近井眼结垢难题
Pub Date : 2018-06-20 DOI: 10.2118/190713-MS
M. Jordan
Formation of sulphate and carbonate scale is well understood within the hydrocarbon extraction industry with injection of incompatible water such as seawater into reservoir with significant concentration of barium, strontium and calcium. To overcome this challenge chemical inhibition has been utilized for many decades and in the past 15 years elimination/reduction of the sulphate ion source from injection seawater using sulphate reduction membranes has been employed. This paper present laboratory work to qualify a scale inhibitor and field results of its application to prevent scale formation when an operator had to change from low sulphate seawater (LSSW) mixed with produced water (PW) for their water injection source to a blend of LSSW/PW and full sulphate seawater (SW). The increased level of sulphate presented a significant scale risk within the topside process on fluid mixing but more significantly increased the risk of scale formation within the near wellbore region of the injector wells which were under matrix injection rather than fracture flow regime. The qualification of a suitable inhibitor required assessment of the retention of a potentially suitable vinyl sulphonate co polymer scale inhibitors to ensure it had low adsorption and was able to propagate deep into the formation before being adsorbed from the supersaturated brine. Coreflood studies using reservoir core were carried out to assess the scale risk of the LSSW/PW/SW brine, propagation and release characteristic of the short-listed scale inhibitors. The recommendation that followed the laboratory studies was to apply a batch treatment of concentrated scale inhibitor to each injector well to provide a high concentration pad of scale inhibitor that would be transported into the reservoir when the scaling LSSW/PW/SW fluid was injected. Protection was provided by continuous application of the same chemical at minimum inhibitor concentration to prevent scale formation within the topside and the desorption of the batched inhibitor within the near wellbore would prevent scale formation within this critical region. Thirteen injection wells were treated with a pad of 10% vinyl sulphonate co polymer scale inhibitor to a radial distance of 3 ft. prior to the start of LSSW/PW/SW injection. Highly scaling brine has been injected now for 16 months into the thirteen wells at an average rate of 25,000 BWPD per well with no decline in injector performance observed. The lessons learned from this study are that changes in scaling potential within a PWRI system can be controlled by carrying out an assessment of location of scale formation and adoption of more typical production well scale squeezes treatment technology to protect the critical near wellbore region around PWRI injection wells.
在油气开采行业中,通过向含有大量钡、锶和钙的储层注入海水等不相容水,可以形成硫酸盐和碳酸盐水垢。为了克服这一挑战,化学抑制已经使用了几十年,在过去的15年里,使用硫酸盐还原膜消除/减少了注入海水中的硫酸盐离子源。本文介绍了一种阻垢剂的实验室工作,以及当作业者不得不将低硫酸盐海水(LSSW)与采出水(PW)的混合注入水源改为LSSW/PW与全硫酸盐海水(SW)的混合注入水源时,该阻垢剂用于防止结垢的现场应用结果。硫酸盐含量的增加在上部过程中对流体混合产生了显著的结垢风险,但在基质注入而非压裂流动状态下,更显著地增加了注入井近井眼区域结垢的风险。确定合适的阻垢剂需要评估潜在合适的乙烯磺酸共聚物阻垢剂的保留率,以确保其具有低吸附性,并且能够在从过饱和盐水中吸附之前深入地层。利用储层岩心进行了岩心驱替研究,以评估LSSW/PW/SW卤水的结垢风险,以及入围阻垢剂的扩散和释放特性。实验室研究之后的建议是,对每口注入井进行一次浓缩阻垢剂的批量处理,以提供高浓度的阻垢剂垫块,当注入LSSW/PW/SW结垢液时,这些阻垢剂将被输送到储层中。在最小的抑制剂浓度下,连续使用相同的化学物质,以防止上层结垢,在近井内的批处理抑制剂的解吸可以防止这一关键区域的结垢。在开始注入LSSW/PW/SW之前,对13口注入井进行了10%乙烯磺酸共聚物阻垢剂的处理,井眼径向距离为3英尺。目前,高结垢盐水已在13口井中注入了16个月,平均每口井的速度为25000 BWPD,未观察到注入器性能下降。从这项研究中得到的经验教训是,PWRI系统中结垢潜力的变化可以通过对结垢地层的位置进行评估和采用更典型的生产井结垢挤压处理技术来控制,以保护PWRI注水井周围的关键近井区域。
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引用次数: 3
Development and Improvement of a Novel IC-MS Technique for Phosphonate Scale Inhibitors 膦酸盐阻垢剂新型IC-MS技术的发展与改进
Pub Date : 2018-06-20 DOI: 10.2118/190719-MS
Lei Cheng, C. Durnell, S. Linares-Samaniego, I. Littlehales, J. Fidoe, E. Casado-Rivera
Accurate and precise analysis of scale inhibitor residuals is important to managing oilfield squeeze treatments. Phosphonate scale inhibitors are effective for the prevention and control of scale problems in oilfields. The traditional analytical technique for monitoring phosphonate scale inhibitor residuals is inductively coupled plasma optical emission spectroscopy (ICP-EOS). ICP-OES is simple and has been used for monitoring squeeze treatments for decades. However, it can only measure the total phosphorus in the system and is unable to differentiate the different forms of phosphonates in commingled samples. This paper presents a novel technique using ion chromatography and mass spectrometry (IC-MS and IC-MS/MS) for monitoring and quantifying different phosphonate scale inhibitors with high sensitivity and specificity. Ion chromatography efficiently separates phosphonate ions from other salt ions, and mass spectrometry speciates and quantitates molecular ions or fragment ions of each phosphonate. Previous work in our group (Zhang, et.al., 2014) had shown that IC-MS could be used to differentiate two phosphonates in a squeeze treatment using the characteristic molecular ions of each phosphonate. As the complexity of the squeeze treatment increases with the addition of other phosophates to the local oilfield, the development of an advanced IC-MS/MS method has been required to differentiate up to four phosphonates in a single commingled sample. This innovative technique has a detection limit of <1 ppm for each phosphonate in the mixture. The technique has been validated using both synthetic brine and field brine. Solid phase extraction cleanup work has also been performed to improve the capability of the technique in high-salinity brines. This novel analytical method will provide a powerful tool in squeeze scale management for subsea and deepwater oilfields.
准确、精确地分析阻垢剂残留对油田挤压治理具有重要意义。膦酸盐阻垢剂是防治油田结垢的有效药剂。传统的监测膦酸盐阻垢剂残留量的分析技术是电感耦合等离子体发射光谱(ICP-EOS)。ICP-OES很简单,几十年来一直用于监测挤压处理。然而,它只能测量系统中的总磷,无法区分混合样品中不同形式的磷酸盐。本文提出了一种离子色谱-质谱联用技术(IC-MS和IC-MS/MS)监测和定量不同膦酸盐阻垢剂的新方法,具有较高的灵敏度和特异性。离子色谱法有效地将磷酸盐离子从其他盐离子中分离出来,质谱法对每种磷酸盐的分子离子或片段离子进行定性和定量。在我们小组之前的工作(张等)。, 2014)表明,IC-MS可以在挤压处理中使用每种磷酸盐的特征分子离子来区分两种磷酸盐。随着其他磷酸盐的加入,挤压处理的复杂性增加,需要开发一种先进的IC-MS/MS方法来区分单个混合样品中的多达四种磷酸盐。这种创新技术对混合物中每种膦酸盐的检测限< 1ppm。该技术已在合成盐水和现场盐水中进行了验证。还进行了固相萃取净化工作,以提高该技术在高盐度盐水中的能力。这种新颖的分析方法将为海底和深水油田的挤压垢管理提供有力的工具。
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引用次数: 2
Application of Electroless Nickel Coating as a Scaling Resistant Alloy in Thermal Production 化学镀镍作为抗结垢合金在热生产中的应用
Pub Date : 2018-06-20 DOI: 10.2118/190749-MS
Da Zhu, L. Gong, Xiaoyong Qiu, Wenjihao Hu, Jun Huang, Ling Zhang, Vahidoddin Fattahpour, Mahdi Mahmoudi, Jingli Luo, Hongbo Zeng
The scaling has been found to be a major problem in thermal production, such as in the Steam-Assisted Gravity Drainage (SAGD) operation. In addition to providing a favorite environment for corrosion, scaling could result in extreme plugging in sand control devices. Therefore, any coatings for the equipment and completion in thermal production should provide significant anti-scaling surface properties. This paper presents a detailed study, including field and laboratory testing, on application of the Electroless Nickel Coating (EN-coating) in thermal production environment. Initially, EN-coated and uncoated carbon steel samples were tested in laboratory to assess the scale, hardness and adhesion of inorganic and organic materials. Successful laboratory testing lead to a field testing plan, which involves deploying the EN-coated and uncoated samples into a horizontal well for thermal production. The specimens were recovered after certain time and a comprehensive X-ray Photoelectron Spectroscopy (XPS) and Energy-Dispersive Spectroscopy (EDS) were performed to assess accumulation of fouling substances on EN-coated and uncoated carbon steel. This study suggests the application of the EN-coating technology to solve the problems caused by scale, and adhesion of organic and inorganic material in thermal production. The comprehensive laboratory testing and field data from the SAGD wells shows that EN-coating significantly improves the well integrity in the harsh thermal production environment.
结垢是热采作业中的一个主要问题,例如蒸汽辅助重力泄油(SAGD)作业。除了提供良好的腐蚀环境外,结垢还可能导致防砂装置严重堵塞。因此,用于热采设备和完井的任何涂层都应具有显著的抗结垢表面性能。本文对化学镀镍(EN-coating)在热工环境中的应用进行了详细的研究,包括现场和实验室测试。最初,在实验室对涂覆和未涂覆的碳钢样品进行测试,以评估无机和有机材料的结垢、硬度和附着力。成功的实验室测试会导致现场测试计划,其中包括将en涂层和未涂层样品下入水平井进行热采。样品在一定时间后回收,用x射线光电子能谱(XPS)和能量色散能谱(EDS)综合分析涂层和未涂层碳钢上污垢物质的积累情况。本研究建议应用en涂层技术来解决热生产中有机和无机材料的结垢和粘附问题。综合实验室测试和SAGD井的现场数据表明,在恶劣的热采环境下,en涂层显著提高了油井的完整性。
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引用次数: 1
Evaluating Evaporative Processes - Gas Lift Chemical Applications, Halites and Gunking 评价蒸发过程。气举化学应用,盐和蒸发
Pub Date : 2018-06-20 DOI: 10.2118/190712-MS
N. Goodwin, G. Graham
This paper describes a number of different evaporative processes which can cause flow assurance issues within oilfield production systems including chemical application via gas lift systems, halite deposition and gunking in injection lines. Similarities and differences are described and laboratory test methods are presented for each case. While the challenges all involve evaporative processes, each system is different and requires suitable approaches to evaluate and mitigate the risks. These attempt to mimic the field system in the laboratory and allow observation under controlled conditions. Laboratory test methods vary from basic static bottle tests, through glass capillaries in autoclaves to dynamic tests using brine and a partially saturated gas phase, or neat chemical and dry gas lift media. In particular, the challenges when applying a chemical via a gas lift system will be described including field case studies. Static tests with unlimited volume to evaporate produce a worst case for any evaporative process. However, it is frequently too severe to produce any useful results. Instead a test regime should be designed to mimic the field conditions. For example, evaporation within a pressure vessel can mimic the self-limiting process within a downhole injection line. Application of a chemical via a gas lift system requires a dynamic test where hot pressurised dry gas and neat chemical are co-injected with continual monitoring of gunking as indicated by flow path restrictions. Halites require a similar dynamic test method but with extensive modelling of the in situ saturation ratio to fully understand the system. This paper will present case studies, summarise our understanding of the different evaporative processes, and give best practice guidelines for laboratory evaluation of the risks and mitigation strategies.
本文介绍了一些不同的蒸发过程,这些过程可能会导致油田生产系统中的流动保证问题,包括气举系统中的化学应用、岩盐沉积和注入管线中的堵塞。描述了相似性和差异,并为每种情况提出了实验室测试方法。虽然所有挑战都涉及蒸发过程,但每个系统都是不同的,需要适当的方法来评估和减轻风险。这些尝试在实验室中模拟现场系统,并允许在受控条件下进行观察。实验室测试方法各不相同,从基本的静态瓶测试,通过高压灭菌器中的玻璃毛细管,到使用盐水和部分饱和气相,或纯化学和干气举介质的动态测试。特别是,当通过气举系统应用化学品时,将描述包括现场案例研究在内的挑战。对于任何蒸发过程来说,无限体积的静态测试都会产生最坏的情况。然而,它往往过于严重,无法产生任何有用的结果。相反,应该设计一个模拟现场条件的测试制度。例如,压力容器内的蒸发可以模拟井下注入管线内的自我限制过程。通过气举系统应用化学品需要进行动态测试,其中热压干气体和纯化学品共同注入,并根据流动路径限制连续监测堵塞情况。岩盐岩需要类似的动态测试方法,但需要对原位饱和比进行广泛的建模,以充分了解该系统。本文将介绍案例研究,总结我们对不同蒸发过程的理解,并为实验室评估风险和缓解战略提供最佳实践指南。
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引用次数: 1
A Novel View of Barium Sulfate Deposition in Stainless Steel Tubing 不锈钢管中硫酸钡沉积的新观点
Pub Date : 2018-06-20 DOI: 10.2118/190696-MS
A. Lu, G. Ruan, K. Harouaka, Dushanee Sriyarathne, Wei Li, Guannan Deng, Yue Zhao, Xing-lei Wang, A. Kan, M. Tomson
Deposition of inorganic scale has always been a common problem in oilfield pipes, especially in raising safety risk and producing cost. However, the fundamentals of deposition mechanism and the effect of various surface, temperature, flow rate and inhibitors on deposition rate has not been systematically studied. The objective of this research is to reveal the process of barium sulfate deposition on stainless steel surfaces. In this work a novel continuous flow apparatus has been set up to enable further investigation of deposition rate, crystal size and morphology and the effect of scale inhibitor. In this apparatus supersaturate barium sulfate solution is mixed and passed through a 3 feet stainless steel tubing with ID = 0.04 inch or 0.21 inch at 70 to 120 degree C. The barium concentration is measured at the effluent to quantify the concentration drop. After 1 to 200 hours the tubing is cut into pieces to measure the barite deposition amount and observe the barite crystal morphology using SEM. Under the experimental conditions, the deposition rate along the stainless steel tubing can be modelled by second order crystal growth kinetics, the SEM micrograph also shows that most of deposited barite is micrometer sized crystals. The highest deposition rate happens at the beginning of the tubing even before the expected induction time of bariums sulfate. The results indicated that the deposition happens even before the mixed solution is expected to form particles, which suggest that the heterogeneous nucleation might be the dominate mechanism in the initial stage, then crystal growth takes place and governs the deposition. The mechanism of scale attachment to tubing surface has never been well-understood. The apparatus in this work provides a reliable and reproducible method to investigate barium sulfate deposition. The findings in this research will enhance our knowledge of mineral scale deposition process, and aid the use of inhibitors in mineral scale control.
无机水垢的沉积一直是油田管道生产中普遍存在的问题,尤其会增加管道的安全风险和生产成本。然而,沉积机理的基本原理以及不同表面、温度、流速和抑制剂对沉积速率的影响尚未得到系统的研究。本研究的目的是揭示硫酸钡在不锈钢表面沉积的过程。本文建立了一种新型的连续流动装置,以进一步研究沉积速率、晶体尺寸和形态以及阻垢剂的效果。在该装置中,过饱和硫酸钡溶液混合并在70至120摄氏度下通过直径为0.04英寸或0.21英寸的3英尺不锈钢管。在流出处测量钡浓度以量化浓度下降。1 ~ 200小时后,将管材切成片,测量重晶石沉积量,用扫描电镜观察重晶石晶体形貌。在实验条件下,沿不锈钢管的沉积速率可以用二级晶体生长动力学来模拟,SEM显微图也表明,沉积的重晶石大部分是微米级的晶体。最高沉积速率发生在管道的开始,甚至在预期的硫酸钡诱导时间之前。结果表明,在混合溶液形成颗粒之前,沉积就已经发生了,这表明在初始阶段,非均相成核可能是主要的机制,然后发生晶体生长并控制沉积。结垢在油管表面的附着机理一直没有得到很好的理解。本装置为研究硫酸钡沉积提供了一种可靠、重复性好的方法。本研究结果将增强我们对矿物结垢过程的认识,并有助于抑制剂在矿物结垢控制中的应用。
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引用次数: 1
Effect of Squeeze Treatment Stages Mixing During Injection on Lifetime 注射过程中挤压处理阶段混合对寿命的影响
Pub Date : 2018-06-20 DOI: 10.2118/190751-MS
O. Vazquez, E. Mackay, Manuel Raga, G. Ross
Scale inhibitor squeeze treatments are used to prevent scale deposition in production wells. A treatment consists of injecting a scale inhibitor slug at a concentration between 5 and 15%, referred to as the main treatment, followed by an overflush, which will push the chemical slug deeper into the reservoir. During injection, the stages might undergo some degree of mixing in the tubing. This paper addresses the impact such mixing would have on the squeeze lifetime. A consequence of mixing between main treatment and overflush stages in the well tubing would be that although the same overall mass of scale inhibitor was injected, it would be distributed over a larger volume of water and therefore be exposed to the rock formation at a lower concentration than planned in the design. The degree of mixing in the tubing depends on a number of factors, such as tubing length and diameter, and the pumping rate. The phenomenon is described by the longitudinal dispersion coefficient, which may be calculated. The resulting calculation may be defined as the spreading of a solute along the longitudinal axis, which leads to the spread of an initial high concentration slug with a low spatial variance to a final stage of low concentration with high spatial variance. The main objective of the paper is to study the effect of the degree of mixing of the main and overflush stages on the squeeze treatment lifetime. The net effect of full mixing would be that instead of there being two different stages at very different scale inhibitor concentration, a single stage at a lower concentration might be exposed to the rock formation. Two mixing profiles were considered, a short and long tubing; where the total injected volume is greater than and less than the total tubing volume, respectively. A number of levels of mixing were considered and compared to the base case, where no mixing was allowed. The results showed that squeeze lifetime is not significantly reduced if mixing occurs in a short tubing interval, whereas it can be reduced by up to 20% in a longer tubing interval.
为了防止生产井中结垢,采用了阻垢剂挤压处理。一种处理方法包括注入浓度在5%至15%之间的阻垢段塞,即主处理方法,然后进行溢流处理,将化学段塞推进储层深处。在注入过程中,这些阶段可能会在油管中发生一定程度的混合。本文讨论了这种混合对挤压寿命的影响。主处理阶段和溢流阶段在油管中混合的结果是,尽管注入的阻垢剂的总质量相同,但它会分布在更大体积的水中,因此暴露在岩层中的浓度低于设计计划。油管中的混合程度取决于许多因素,如油管长度和直径,以及泵送速率。这种现象可以用纵向色散系数来描述,并可以计算得到。由此产生的计算可以定义为溶质沿纵向轴的扩散,导致初始高浓度低空间方差的段塞扩散到低浓度高空间方差的最后阶段。本文的主要目的是研究主级和溢流级的混合程度对挤压处理寿命的影响。完全混合的净效果是,不再存在两个不同阻垢剂浓度的不同阶段,而是一个浓度较低的单一阶段可能暴露在岩层中。考虑了两种混合剖面,短油管和长油管;总注入体积分别大于和小于总油管体积。考虑了若干混合水平,并与不允许混合的基本情况进行了比较。结果表明,如果混合发生在短油管间隔内,挤压寿命不会显著缩短,而在较长的油管间隔内,挤压寿命最多可缩短20%。
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引用次数: 0
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