Modeling of a Gas-Lift Well Operation with an Automated Gas-Lift Gas Supply Control System

E. Yudin, R. Khabibullin, I. Galyautdinov, A. Andrianova, K. Goridko, N. Smirnov, V. Babin, G. Chigarev, I. Lomukhin, Y. Murzaev
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Abstract

Gaslift operation faces several challenges - optimizing the amount of gas pumped, ensuring that the gas is pumped to the maximum possible depth, combating salt and hydrate formation and, finally, the instability of the flow. The timely detection of these problems and the optimisation of the system requires information on the dynamics of the main parameters (flow rates, pressure measurements at each unit and the amount of gas pumped). In the conditions of high cost of multiphase flowmeters at the Orenburg field well flow rates are not measured often enough, and the task of identification of the most unstable wells in real time by auxiliary parameters measured with greater discreteness becomes urgent. Often important production decisions based on monthly data, and less often on daily measurements. In the paper the necessity to go down to the level of analysis of highly discrete information (dozens of measurements per day) is proved by the example of the Orenburg field, because in conditions of unstable operation the averaging inside the day can lead to distortion of the general view of the operating mode. Within the framework of the analysis of dynamic parameters of gas-lift wells operation in unstable conditions, the notion of well operation quality index was introduced, i.e. a normalized metrics reflecting the general state of stability of a gas-lift well operation. This metric considers uncoordinated changes in the main parameters of the system. The wells with the lowest index are the first candidates to search for hidden production losses (not achieving the regime flow rate). Modelling of well performance, adaptation of models to historical data - a typical approach to production management in the field. But in the conditions of unstable gas-lift wells modeling of their work is much more complicated. In this regard, the authors of the article developed an approach to modeling wells through the approximation relationship between the flow rate of wells and the flow rate of gas-lift gas and linear pressure with further integration of well models with the collection system. To solve well operation modes optimization problem, an integrated Proxy-model of the asset was created, which consists of a simplified reservoir model, developed well models and infrastructure model. The Proxy model was adapted and verified to the actual operating data. The task of finding the optimal distribution of gas injection between the wells from the point of view of oil production was solved.
采用自动气举供气控制系统的气举井作业建模
气举作业面临着几个挑战:优化抽气量,确保气体被抽到最大可能的深度,对抗盐和水合物的形成,最后,解决流动的不稳定性。及时发现这些问题并优化系统需要有关主要参数动态的信息(流量,每个单元的压力测量和抽气量)。在Orenburg油田多相流量计成本较高的情况下,由于对井流量的测量不够频繁,利用测量的离散性较大的辅助参数实时识别最不稳定井的任务变得迫切。通常重要的生产决策是基于每月的数据,而不是每天的测量。文中以奥伦堡油田为例,证明了深入到高度离散信息(每天几十次测量)分析的必要性,因为在不稳定的运行条件下,一天内的平均会导致对运行模式的一般看法的扭曲。在分析不稳定条件下气举井运行动态参数的框架下,引入了气举井运行质量指标的概念,即反映气举井运行总体稳定状态的归一化指标。该度量考虑系统主要参数的不协调变化。指数最低的井是寻找潜在生产损失(未达到稳态流量)的首选井。建立油井动态模型,使模型适应历史数据,这是油田生产管理的典型方法。但在不稳定的气举井条件下,其工作的建模要复杂得多。在这方面,本文的作者开发了一种通过井流量与气举气体流量和线性压力之间的近似关系来建模井的方法,并进一步将井模型与收集系统集成。为解决井作业模式优化问题,建立了由简化油藏模型、开发井模型和基础设施模型组成的综合代理模型。根据实际运行数据对代理模型进行了调整和验证。解决了从采油角度寻找井间注气最佳分布的问题。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
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