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Rheological Method To Describe Metastable Hydrate-in-Oil Slurries

机译:描述亚料水合物浆料的流变方法

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摘要

Gas hydrates are ice-like solids that may form and aggregate in crude oil pipelines; in severe cases, the increase in frictional pressure drop may exceed the available driving force, resulting in a non-flowing (blockage) condition. To assess the severity of hydrate formation in oil- or condensate-dominant lines, a slurry viscosity model must be applied to and validated for hydrate-laden suspension. A well-known model, applied in industrial situations for hydrate slurry rheology, has been suggested to significantly underpredict apparent viscosity during the early and intermediate stages of hydrate blockage formation. Because hydrate particles suspended in the slurry may aggregate, this study interrogates their suspension rheology in two parts: The underlying suspension behavior was tested by injecting industrial anti-agglomerant (AA) chemicals, thereby identifying the contribution of particle aggregation for identical systems without AAs. A temperature-controlled high-pressure rheometer with a vane blade rotor was deployed, where hydrate-in-oil suspensions were formed from a metastable water-in-oil emulsion pressurized with methane. The results first illustrate that, at similar operating conditions, the addition of AAs reduced the hydrate growth rate by an order of magnitude and decreased the steady-state relative viscosity order of magnitude. After the hydrate volume fraction achieved a steady-state condition, the addition of AA suppressed the magnitude of the hydrate-in-oil slurry viscosity flow curve by an order of magnitude. Extrapolated to the infinite shear rate, the apparent viscosity behavior of hydrate-in-oil suspensions was compared to a range of rheological suspension models. The current industry model was indeed found to perform poorly, which may be due to assumptions of rigid and spherical particles; a revised suspension model considering arbitrarily shaped particles improved experimental predictions by between 50 and 60% for two crude oil systems.
机译:天然气水合物是冰状固体,可在原油管道中形成和聚集;在严重的情况下,摩擦压降的增加可能超过可用驱动力,导致不流动(堵塞)条件。为了评估油状物或冷凝物 - 优势线中水合物形成的严重程度,必须施加浆料粘度模型并验证水合物悬浮液。已经提出了在水合物浆液流变学的工业情况下应用的众所周知的模型,以显着低于水合物阻断形成期间的表观粘度。因为悬浮在浆料中的水合物颗粒可以聚集,所以该研究在两部分中询问它们的悬浮流变学:通过注入工业抗聚物(AA)化学物质来测试潜在的悬浮行为,从而鉴定颗粒聚集的颗粒聚集在没有AA的情况下的贡献。展开了具有叶片转子的温度控制的高压流变仪,其中水合物悬浮液由用甲烷加压的亚稳态水乳液形成。结果首先说明,在类似的操作条件下,添加AA的添加将水合物生长速率降低,并降低了稳态相对粘度阶数。在水合物体积分数达到稳态条件之后,加入AA抑制了水合物浆料粘度流动曲线的幅度,其数量级。将水合物悬浮液的表观粘度行为与一系列流变悬浮液模拟。目前的行业模式确实发现表现不佳,这可能是由于刚性和球形颗粒的假设;考虑任意形状的颗粒的修正悬架模型改善了两个原油系统的实验预测50%至60%。

著录项

  • 来源
    《Energy & fuels》 |2020年第7期|7955-7964|共10页
  • 作者单位

    Univ Western Australia Dept Chem Engn Fluid Sci & Resources Crawley WA 6009 Australia;

    Univ Western Australia Dept Chem Engn Fluid Sci & Resources Crawley WA 6009 Australia;

    Univ Western Australia Dept Chem Engn Fluid Sci & Resources Crawley WA 6009 Australia;

    Univ Western Australia Dept Chem Engn Fluid Sci & Resources Crawley WA 6009 Australia;

    Univ Western Australia Dept Chem Engn Fluid Sci & Resources Crawley WA 6009 Australia;

  • 收录信息 美国《科学引文索引》(SCI);美国《工程索引》(EI);美国《生物学医学文摘》(MEDLINE);
  • 原文格式 PDF
  • 正文语种 eng
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  • 关键词

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