Predicting Hydrate Plugging Risk in Oil Dominated Systems using a Transient Hydrate Film Growth Prediction Tool
Predicting Hydrate Plugging Risk in Oil Dominated Systems using a Transient Hydrate Film Growth Prediction Tool
复制标题
使用瞬态水合物膜生长预测工具预测以石油为主的系统中的水合物堵塞风险
DOI：
--
复制
发表时间：
2020
期刊：
影响因子：
--
通讯作者：
K. Mateen
中科院分区：
文献类型：
--
作者：
Hao Qin;A. Qu;Yan Wang;L. Zerpa;C. Koh;S. Bodnar;S. Daly;T. Palermo;K. Mateen
天然气水合物的形成被认为是深水开发石油生产过程中高压和低温条件造成的主要流动保证问题（Sloan 和 Koh 2007）。气体水合物是固体结晶化合物，当压力和温度达到热力学稳定水合物区时即可形成。水合物会堵塞深水输油管，从而可能导致输油管破裂以及石油和天然气的溢出或泄漏（Sloan 2010）。因此，在运行过程中可能存在生产和经济损失。
说明了以石油为主的管道中水合物引起的以石油为主的管道堵塞机制。该过程相当复杂，存在以下现象：（1）由于油中的流体剪切和表面活性成分，水滴在连续油相中夹带或分散； (2)水合物形成，在一定的热驱动力作用下，水合物在水-油/水-气界面生长； (3)水合物的团聚和沉积； (4)颗粒干扰和水合物堵塞。在这些机制中，薄膜生长、沉积（层理）可以归类为水合物沉积。
传统上，热力学方法用于防止流线中形成水合物，包括注入热力学水合物抑制剂（THIs），例如甲醇或乙二醇。 THI 的工作原理是将水合物相平衡条件转移到更低的温度和更高的压力，这使得该条件不利于水合物的形成（Sloan 和 Koh，2007）。然而，对于 THI，需要大量的化学品，这将带来高运营成本和资本支出（Creek 等，2011）。水合物风险管理方法已广受欢迎，因为它们将大大降低成本。后者较新的概念表明，通过注入低剂量水合物抑制剂（LDHI），包括动力水合物抑制剂（KHI）和抗凝聚剂（AA），即使流线可能进入水合物稳定区，也可以控制流线堵塞的风险。为了支持这一概念，综合模拟工具对于预测上述不同的水合物堵塞机制至关重要。
The formation of gas hydrates is considered a major flow assurance issue resulting from high pressure and low temperature conditions during petroleum production in deep water developments (Sloan and Koh 2007). Gas hydrates are solid crystalline compounds, which can be formed when the pressure and temperature reaches the thermodynamically stable hydrate zone. Hydrates can plug deepwater flowlines, which may lead to the rupture of flowlines and spill or leakage of oil and gas (Sloan 2010). As a result, production and economic losses may exist during operation.
illustrates the oil-dominated pipeline plugging mechanism caused by hydrates in an oil dominated pipeline. The process is fairly complex, with phenomena such as: (1) water entrainment or dispersion of water droplets in the continuous oil phase due to fluid shear and surface-active components in the oil; (2) hydrate formation, with hydrate growth at the water-oil/water-gas interface under a certain degree of thermal driving force; (3) hydrate agglomeration and deposition; (4) particle jamming and hydrate plugging. Among these mechanisms, film growth, deposition (bedding) can be categorized into hydrate deposition.
Traditionally, thermodynamic approaches are used to prevent the formation of hydrates in flowlines, including the injection of thermodynamic hydrate inhibitors (THIs), such as methanol or glycols. THIs work by shifting the hydrate phase equilibrium conditions to a lower temperature and higher pressure, which makes the condition unfavorable for hydrates to form (Sloan and Koh, 2007). However, for THIs, large amounts of chemicals are needed, which will introduce high OPEX and CAPEX (Creek, et al. 2011). Hydrate risk management methods have gained popularity, as they will largely reduce the cost. The latter more recent concept suggests that by injecting low dosage hydrate inhibitors (LDHIs), including kinetic hydrate inhibitors (KHIs) and anti-agglomerants (AAs), the risk of flowline blockage can be controlled, even though the flowline may enter the hydrate stability zone. To support this concept, a comprehensive simulation tool is critical to predict the different hydrate plugging mechanisms mentioned above.