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基于OLGA一体化模型的新井接入流动模拟
引用本文:苏羽,张兵,魏超,甘霖临,陈思佳,冷吉辉,陈璐. 基于OLGA一体化模型的新井接入流动模拟[J]. 科技和产业, 2024, 24(14): 220-226
作者姓名:苏羽  张兵  魏超  甘霖临  陈思佳  冷吉辉  陈璐
作者单位:中联煤层气有限责任公司,北京 100016;中海艾普油气测试(天津)有限公司,天津 300450;西南石油大学石油与天然气工程学院,成都 610500
摘    要:针对A气田地面管网出现较为严重的积液和段塞流的问题,根据A气田现场数据,建立了基于OLGA软件的油藏-井筒-管网一体化模型,研究了新井接入条件下相邻井的压力变化和集输管线中积液与段塞流的变化情况。结果表明,建立的油藏-井筒-管网OLGA一体化模型最大误差为6.92%,满足生产模拟;新井产量增加到一定条件时(11 万m3/d),相邻井平台汇压明显下降(从3.75 MPa降至2.56 MPa),其他井平台的汇压变化不大(0.1 MPa范围内波动),主要原因是新井和相邻井汇合后的管线压降出现明显降低。而汇合管线压降降低的原因是新井汇入后管线输量增大,管内积液量、持液率、段塞流数量明显降低,增大了汇合管线的输送效率。同时,模拟发现管网积液高风险位置主要为低洼段,段塞流高风险位置主要为上坡段。

关 键 词:新井接入;OLGA;一体化模型;积液;段塞流预测

Flow Simulation of New Well Access Based on OLGA Integrated Model
Abstract:Given the serious problems of liquid accumulation and slug flow in the surface pipe network of A gas field with high water production (the water/gas ratio reaches 3 m3/104 m3 gas), a reservoir-wellbore-pipe network integration OLGA model was established based on the field data of A gas field and the changes of pressure in adjacent wells and the changes in liquid accumulation and slug flow in gathering and transportation pipelines under the conditions of new well access were studied. The results shows that the maximum error of the OLGA model established in this paper is 6.92%, which can satisfy the production simulation. When the production of the new well increases to a certain condition (such as 110 000 m3/d), the converge pressure of the adjacent well platform decreases significantly (3.75 MPa to 2.56 MPa), while the converge pressure of other well platforms do not change much (fluctuating within 0.1 MPa), mainly because the pressure drop of the confluent pipeline along the new well and the adjacent well confluent decreases significantly. The reason for the decrease in the pressure drop of the confluent pipeline is that after the new well is merged into the pipeline, the pipeline liquid accumulation, liquid holdup, and slug flow quantity are significantly reduced, which increase the transportation efficiency of the confluent pipeline, reduce the pressure drop along the pipeline, and reduce the converge pressure of the adjacent well. At the same time, it is found that the high-risk locations of fluid accumulation are mainly low-lying sections and the high-risk locations of slug flow are mainly uphill sections.
Keywords:new well access   OLGA   integrated model   liquid accumulation   slug flow prediction
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