水下增压泵在陆丰22-1油田的应用研究
Research on the application of subsea booster pump in Lufeng 22-1 oilfield
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- 引用格式:
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刘飞龙,陈文峰,曾树兵,李伟,邢天健.水下增压泵在陆丰22-1油田的应用研究[J].天然气与石油,2023,41(5):16-21.doi:10.3969/j.issn.1006-5539.2023.05.003
LIU Feilong, CHEN Wenfeng, ZENG Shubing, LI Wei, XING Tianjian.Research on the application of subsea booster pump in Lufeng 22-1 oilfield[J].Natural Gas and Oil,2023,41(5):16-21.doi:10.3969/j.issn.1006-5539.2023.05.003
- DOI:
- 10.3969/j.issn.1006-5539.2023.05.003
- 作者:
- 刘飞龙 陈文峰 曾树兵 李伟 邢天健
LIU Feilong, CHEN Wenfeng, ZENG Shubing, LI Wei, XING Tianjian
- 作者单位:
- 海洋石油工程股份有限公司, 天津 300451
Offshore Oil Engineering Co., Ltd., Tianjin, 300451, China
- 关键词:
- 陆丰22-1油田;边际油气田;水下增压泵;海管;在线清管
Lufeng 22-1 oilfield; Marginal oil and gas fields; Subsea booster pump; Subsea pipeline; Online pigging
- 摘要:
- 为了高效开发边际油气田和深水油气田,水下增压已成为全球海上油气田开发的重要技术手段之一。陆丰221油田属于二次开发,具有含水率高、井口压力低等特点,为充分利用油田的剩余开采储量和提高油田的商业价值,采用全水下生产系统开发模式,利用水下增压泵将井口流体增压后输送至平台进行处理。应用多相流动态模拟OLGA软件建立了陆丰221油田从水下井口至平台的流体输送模型。首先针对单海管工况和双海管运行工况进行了模拟分析,结果表明陆丰221油田双海管运行时水下增压泵均在最佳运行区域内,且流体温度高于原油凝点;而单海管运行输量＜300 m3/h时,水下增压泵工作点处于最佳运行区域外；然后通过调节水下增压泵转速对双海管在线清管进行了动态模拟,结果表明在平台用200 m3/h的生产水推动清管球对第一条海管清管时,需将水下井口的流量限产至420 m3/h,待清管球通过第一条海管后在平台停止注入生产水,同时水下井口恢复至正常产量,双海管在线清管总时间约11.4 h。研究结果对深水油气田应用水下增压泵解决流动安全问题具有指导意义。
To efficiently develop marginal and deep-water oil and gas fields, subsea boosting has emerged as one of the crucial techniques in offshore oil and gas field development. The Lufeng 22-1 oilfield, characterized by a high water cut and low wellhead pressure, is undergoing secondary development for enhanced oil recovery. To maximize the utilization of its remaining reserves and enhance its commercial value, a subsea production system (SPS) approach has been adopted. This involves pressurizing the wellhead fluid using a subsea booster pump before transporting it to the platform for processing. In this study, the OLGA software is used to develop a fluid transport model from the subsea wellhead to the platform specific to the Lufeng 22-1 oilfield. Simulations were initially conducted for two operating scenarios: a single subsea pipeline and a dual subsea pipeline configurations. The findings indicate that, with the dual subsea pipelines in operation, the subsea booster pump operates optimally in its operating envelop, and the fluid temperature remains above the crude oil's freezing point. Conversely, when the flowrate drops below 300 m3/h in the single subsea pipeline operation, the booster pump's operating point deviates from the optimal range of the operating envelop. Subsequent dynamic simulations of online pigging for the dual subsea pipelines were performed by modulating the speed of the subsea booster pump. The results revealed that when the pig is launch by a 200 m3/h production water flow from the platform into the first subsea pipeline, the flowrate at the subsea wellhead should be capped at 420 m3/h. Once the pig navigates through the first subsea pipeline, the injection of production water should cease, allowing the subsea wellhead to revert to its standard production rate. The entire online pigging process of the dual subsea pipelines takes approximately 11.4 hours. The research results provide significant guidance on the application of subsea booster pumps to address flow assurance issues in deepwater oil and gas fields.
