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Changes of Operating Procedures and Chemical Application of A Mature Deepwater Tie-back – Aspen Field Case Study

机译:成熟深水系留装置的操作程序和化学应用的变化-阿斯彭油田案例研究

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The Aspen field is located in about 3050 ft water in the Gulf of Mexico on GC243 block and tied back to Bullwinklernproduction facilities on GC65 block via dual 16-mile wet-insulated pipelines. Its first production began in December 2002.rnThe project was a fast-track, marginal field with an assumption of quick reservoir pressure decline. Hydrate is managedrnprimarily by MeOH injection during startup and shutdowns. The reservoir fluids are complex. Downhole sample testsrnshowed asphaltene onset pressure was 6500 psig (~500 psi above bubble point). An asphaltene inhibitor was continuouslyrninjected downhole as well as scale inhibitor since the field was suspected with scale and asphaltene issues in the earlierrnproduction life. The produced water has a total dissolved salt of 230,000 mg/l. The oil production has declined significantlyrnfrom initial production while the water cut reaches up to 80%.rnThe characteristics of field production have been changed significantly since the initial production date. A review wasrnconducted by flow assurance team working with its chemical supplier. During the study period a large amount of fluid testsrnwere conducted and chemical application program were reviewed by chemical supplier’s experts along with the operator’srnengineering team. Planning to field execution took more than one year, resulting in termination of downhole injection ofrnasphaltene inhibitor and scale inhibitor. Additionally there was a reduction in methanol usage and other topside chemicals,rnand the operating guidelines were revised. The financial benefits include cost reduction, as well as quicker startup andrnshutdown.rnThis paper will present the methodologies, organization, tests, recommendations, field execution plan and results afterrnimplementation of the recommendations. The case study also demonstrates how the operation team and engineering supportrnteam of an operator can work with suppliers, utilizing the industry experience, to achieve best results.
机译:Aspen油田位于墨西哥湾GC243区块约3050英尺的水域中,并通过双16英里湿绝缘管道与GC65区块的Bullwinklern生产设施绑在一起。它的第一批生产于2002年12月开始。该项目是一个快速通道的边际油田,假定油藏压力会迅速下降。在启动和关闭过程中,水合物主要通过注入MeOH进行管理。储层流体很复杂。井下样品测试显示沥青质起始压力为6500 psig(比起泡点高约500 psi)。沥青质抑制剂和防垢剂被连续注入井下,因为怀疑该油田在较早的生产寿命中存在水垢和沥青质问题。采出水的总溶解盐为230,000 mg / l。从最初的生产开始,石油的产量已大大下降,而含水率高达80%。从最初的生产日期起,油田的生产特性发生了显着变化。流量保证团队与其化学品供应商一起进行了审核。在研究期间,进行了大量的流体测试,化学供应商的专家以及操作人员的工程团队对化学应用程序进行了审查。计划实施到现场需要花费一年多的时间,导致井下注射萘萘酚抑制剂和阻垢剂终止。此外,减少了甲醇使用量和其他上层化学物质,并修订了操作指南。财务收益包括降低成本,以及更快地启动和关闭计算机。本文将介绍方法,组织,测试,建议,现场执行计划以及建议实施后的结果。案例研究还演示了运营商的运营团队和工程支持团队如何利用行业经验与供应商合作,以达到最佳效果。

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