Production Integrated Sand Control Benchmark for Field Development
Production Integrated Sand Control Benchmark for Field Development
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DOI：
10.2523/iptc-16449-ms
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发表时间：
2013-03
期刊：
影响因子：
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通讯作者：
K. Chan;Danny Chong;R. Masoudi;M. Othman;N. S. B. M. Nordin
中科院分区：
文献类型：
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作者：
K. Chan;Danny Chong;R. Masoudi;M. Othman;N. S. B. M. Nordin
马来西亚目前的海上边际油田开发和成熟油田再开发一直面临着开发成本高、采收率低或递增采收率低的问题。钻井和完井的成本很高，每口井15至30万美元，而每口井的估计最终采收率(EUR)低至40万桶。相关的油井开发成本(WDC)可能高于75美元/桶。如果需要昂贵的防砂方法来降低出砂风险，完井成本的大幅增加可能会进一步加剧WDC的高成本。储集层中岩石的力学性质、应力和压力分布可能会有很大的不同，不同的层、不同的岩相。在整个生产生命周期中，储层孔隙压力及其分布也会发生巨大变化。本文以现场实例研究结果为例，分享了我们的工程方法，即首先根据所选井型、井型和完井的地质力学无砂临界压降(CDP)评价，确定需要防砂的地点和时间。生成的CDP稍后将与油藏模拟模型预测的当前压力和流体分布相耦合，并与成熟油田的井型、完井和防砂策略的历史压力和生产数据进行确认。通过将CDP与达到预期产量目标所需的最低压降压力(MDP)进行比较，可以做出实施适当防砂的决定。因此，防砂方法的选择不仅要根据砂粒粒度分布、井的寿命和井的生产方式(单井选择或混合开采)，而且要根据最大限度地增加油层接触和每口井的油气采收率。所提出的工作流程和方法旨在为油井设计和生产优化建立一个新的防砂基准，并为马来西亚防砂成本的优化提供工程指导。
Current offshore marginal field development and mature field re-development in Malaysia consistently encountered high development cost and low recovery or incremental recovery. Wells are being drilled and completed at a high cost of 15 to 30 M$ per well while the estimated ultimate recovery (EUR) per well is as low as < 0.4 M Bbl. The associated well development cost (WDC) can be higher than 75 $/Bbl. This high WDC cost can be further aggravated by a significant increase in completion cost if an expensive sand control method is required to mitigate risk of sand production. Rock mechanical properties, stress and pressure distribution can vary widely, from layer to layer, rock facies to facies in the reservoir. Reservoir pore pressure and its distribution could also change drastically during the entire production life cycle. With results of field case studies as examples, this paper is to share our engineering approach in first determining where and when we need sand control based on the geo-mechanical sand-free critical drawdown pressure (CDP) evaluation for the selected well type, configuration and completion. The generated CDP will be later coupled with the current pressure and fluid distribution predicted from the reservoir simulation model and confirmed with the historical pressure and production data for well type, completion and sand control strategy in mature fields. Decision to implement a proper sand control can be made by comparing the CDP with the minimum drawdown pressure (MDP) required to meet the expected production rate target. Sand control method selection shall then be based not only on the sand particle size distribution, well life and the mode of well production (single selective or commingle) but also on maximizing reservoir contact and oil and gas recovery per well. The presented workflows and methodologies is to constitute a new sand control benchmark for well design and production optimization and serve as an engineering guide for optimizing the sand control cost in Malaysia.