The Flow Assurance strategy is crucial in the early stages of development of subsea gas fields. The key questions in early development are an optimal tradeoff between managing risk effectively while ensuring deliverability and keeping CAPEX within acceptable project economic limits. The Flow Assurance plan addresses the interaction between production chemistry and multiphase flow and the resulting effects on operability, deliverability, and system performance. This paper focuses on two key aspects of the flow assurance plan for subsea gas developments, the strategies for managing hydrates and the wax deposition. Hydrate management strategy must focus on preventing blockages versus preventing hydrate formation. To this end the engineer must evaluate flow conditions, system geometry, and production profiles, in addition to temperature and pressure conditions. In particular, a realistic water production profile during field life is needed to frame a workable hydrate management strategy. While continuous injection of thermodynamic inhibitor is the traditional solution, thermal management may be deployed effectively for certain fields, resulting in lower CAPEX and OPEX. Operability at restart must also be evaluated, focusing gain on preventing blockage rather than preventing hydrate formation. In several Indonesia deepwater gas developments, as well as elsewhere in Southeast Asia, gas condensate systems have a relatively high amount of wax (>2 w/w%). This high wax content indicates wax problems may occur during production operations. Thermal management may help solve potential deposition problems. The pour point and the wax appearance temperature indicate the potential temperature for stock tank condensate gelation and the highest temperature that the wax typically deposits. These transition temperatures can also be reduced to manageable levels through solution gas content in the produced fluid. For example, typical simulation tools fore cast wax deposition with gas condensates, but these deposits are seldom realized.
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机译：流动保证策略在海底天然气领域发展的早期阶段至关重要。早期发展的关键问题是管理风险有效，同时确保可交付能力和保持资本资本的可接受的项目经济限制之间的最佳权衡。流量保证计划解决了生产化学与多相流与多相流程之间的相互作用以及对可操作性，可传递性和系统性能的产生影响。本文重点介绍了海底气体发展的流动保障计划的两个关键方面，策略管理水合物和蜡沉积。水合物管理策略必须专注于预防封闭性与防止水合物形成。为此，除温度和压力条件外，工程师还必须评估流动条件，系统几何和生产型材。特别是，需要在现场寿命期间进行现实的水生产型材来框架可行的水合物管理策略。虽然连续注射热力学抑制剂是传统的解决方案，但可以针对某些领域有效地部署热管理，从而导致降低支出和OPEX。还必须评估重启时的可操作性，注重防止阻塞而不是防止水合物形成。在若干印度尼西亚深水天然气发展中，以及东南亚的其他地方，气体冷凝物系统具有相对大量的蜡（> 2 w / w％）。这种高蜡含量表示在生产操作期间可能发生蜡问题。热管理可能有助于解决潜在的沉积问题。倾点和蜡外观温度表示储存储量凝胶化的潜在温度和蜡通常沉积的最高温度。这些过渡温度也可以通过生产的流体中的溶液气体含量降低到可管理的水平。例如，典型的仿真工具与气体凝聚物的蜡沉积，但这些沉积物很少实现。
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