应用最优油藏管理:Campos盆地的现场案例经验

D. Oliveira, Diogo Ferreira Alves Pereira, Gustavo Echenique Silveira, P. A. L. S. D. Melo
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引用次数: 2

摘要

海上油田的储层管理是一项具有挑战性的任务,特别是对于成熟油田,因为通常会产生过多的水和/或气。由于设施能力的限制,辅助油藏管理过程可以为海上油田的正常操作提供解决方案,通过更好地评估水和气的生产和注入,寻求增加石油产量。最优油藏管理(ORM)可以用于最大限度地提高油藏性能,并提供适用于现场作业的井控。在这项工作中,我们实施了一个辅助优化程序,以最大限度地提高巴西Campos盆地海上油田的总产油量。我们将ORM技术应用于巴西海上的一个重要油田,通过注入井优化控制水量,实现了累积产油量的最大化。注入速度可以随时间变化,以满足操作的平稳性要求。注入压力的地质力学限制被认为是为了避免岩石完整性的损失,并且平台对整体生产和注入的限制一直都是强加的。我们的方法处理大量校准模拟模型中描述的油藏不确定性,以确定最佳注入速率,同时考虑可能存在的风险。我们开发的基于不确定性模型的ORM显示,与目前应用的基本策略相比,20年的总产油量增加了7.2%。平均而言,结果表明石油产量增加了约4%,同时总产水量和总注入水量减少。为了验证模型与实际(数据观测)的一致性,我们在实际现场进行了中试,以保证我们研究预测的收益是可行的。我们在现场选择了一个区域进行最优注入控制试验,目的是通过与实际观测数据的比较来检查不确定模型的质量。试验区域的选择是基于地质描述、储层预期连通性和操作限制等方面。8个月的试点结果表明,在储层预期的不确定性范围内,模型与现实之间存在明显的一致性。据我们所知,这是第一次在海上油田实际操作中使用一套由辅助最优油藏管理程序获得的控制措施,尽管它仍处于试点阶段。结果表明,考虑到储层不确定性和大规模应用将很快产生可观的效益,但这超出了本工作的范围。该试验为现场应用提供了更多信心,为全油田实施带来了更广阔的前景。
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Applied Optimal Reservoir Management: A Field Case Experience in Campos Basin
Reservoir management in offshore fields is a challenging task, particularly for mature fields because of a typical excessive production of water and/or gas. Due to several constraints on facilities capacity, assisted reservoir management process can deliver solutions to operate properly offshore fields, seeking for increasing oil production with better assessment of water and gas production and injection. Optimal Reservoir Management (ORM) can be applied aiming to maximize reservoir performance and to deliver well controls applicable to field operations. In this work, we implemented an assisted optimization procedure to maximize overall oil production for a field offshore Brazil in Campos Basin. We applied our ORM technique in an important field offshore Brazil, where cumulative oil production is maximized by optimally controlling water rates through injecting wells. Injection rates can vary in time, honoring operational requirements of smoothness. Geomechanical limits on injection pressures are considered to avoid loss of rock integrity and platform constraints on overall production and injection are imposed all times. Our approach deals with reservoir uncertainties described within a large set of calibrated simulation models to decide on optimal injection rates, taking into account possible risks. The model-based ORM under uncertainty that we developed has shown gains in total oil production over 20 years of operation up to 7.2% with respect to the base strategy currently applied. On average, results show an increase around 4% in oil production, with concomitant reduction in total water production and in the overall water injection. A pilot test in the actual field has been implemented to verify the consistency between modeling and reality (data observation), in order to guarantee that the gains forecasted by our study are feasible. We have chosen an area in the field to proceed an optimal injection control pilot, aiming to check the quality of the uncertain models in comparison with the observed data in practice. The pilot area has been selected based on aspects related with geological description, connectivity expected in the reservoir and operational constraints. The results of 8 months of pilot show clear coherence between models and reality within the uncertainty range expected to the reservoir of interest. To the best of our knowledge, it is the first time that an offshore field is actually operated based on a set of controls obtained by an assisted optimal reservoir management procedure, although it was performed still in a pilot scale. Results suggest robust benefits under reservoir uncertainties consideration and large-scale application shall take place soon, but it is out of the scope of this work. The pilot provided more confidence on field applications, leading to broader perspective for full-field implementations.
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