Delivering Horizontal Wells in a Deepwater Borneo Field within a Heavily Faulted Reservoir Using State-of-the-Art Navigation Tools by a Multi-Disciplinary Integrated Team

Valsan Vevakanandan, A. Numpang, Doreen Dayah, Sze-Fong Kho, A. Tan, A. Ting
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引用次数: 0

Abstract

The X field is a mature oil field producing with water injection in place. As part of a phased development, in Phase Two, two infill wells were planned and drilled to extract incremental recovery from a discovered undeveloped reservoir. This includes planning two horizontal producer wells requiring active real time geosteering utilizing deep resistivity tool technology. The wells’ objectives are to ensure the well placement was in an optimal location and to maintain the trajectory within a reservoir that is approximately 100ft thick and was believed to be homogenous field wide. The main challenge to this feat is the faulted nature of the field and the uncertainty in reservoir thickness and extend due to limited well penetrations at this reservoir level. During the planning phase, it was identified early that a deep resistivity tool would be beneficial in geosteering the wells. Prior to drilling, an integrated pre-job model was designed to test multiple tool settings and subsurface scenarios to strategize an execution plan identifying key points where there is a need for real time trajectory adjustments and to pre-plan alternative trajectories based on subsurface scenarios to enable efficient turnaround time to react to real-time results. Conventional navigation tools yield only a shallow to medium depth of measurement (~15ft) which would not have met the objectives of the well given the geological complexities (high fault offsets, laminated reservoirs) and well design (high angle to horizontal). The ultra-deep resistivity (UDR) tool was employed instead to enable trajectory optimization with up to ~100ft depth of investigation (DOI), using a multi-frequency, multi-spaced antenna design from medium and long spaced transmitter receiver spacings providing up to 9 vector components. In real time, the 1D inversion (using 5 of the vector components) was used for early sand and fluid contact detection. During execution, the same integrated team was monitoring the well and close interaction between the subsurface, geosteering and directional drilling team was a key requirement to ensure drilling of the well was safely and objectively executed, especially with the challenges posed with virtual working through a pandemic. As is when dealing with subsurface uncertainties, there were numerous surprises encountered during the drilling of the horizontal wells. Particularly in the matter of fault throw uncertainty and sand distribution. The initial 1D real-time UDR results were able to assist in real-time trajectory adjustments and to provide some geological understandings with regards to fault throw and location of possible faults along the well bore which were then confirmed with borehole image logs. Additionally, 3D inversion images were processed post drilling, and further geological insights were discovered with regards to the depositional trends on the reservoir. In a reservoir that was initially thought to be sand-rich and homogenous, 3D inversion suggests evidence of possible channels. This revelation could explain the varying thickness of the reservoir that was observed during drilling on the 1D UDR canvass. There are plans for future work to incorporate the observations and the analysis of the UDR products for deeper reservoir understanding of the field. Studies to include full integration with seismic data and production data would prove beneficial in well and reservoir management. Additionally, insights gleaned from the optimized selection of tool frequency for real time use and calibration with azimuthal dips and images proved invaluable especially in resolving unexpected structural and depositional complexities. The challenges in delineating fluid contacts in a structurally complex reservoir was also apparent with multiple realizations (and associated probabilities) of contacts seen from the real time results, which proved valuable in re-affirming the difficulties in characterizing the uncertainties in the field
由多学科综合团队使用最先进的导航工具,在Borneo深水油田的严重断层油藏中交付水平井
X油田是一个成熟的就地注水油田。作为分阶段开发的一部分,在第二阶段,计划和钻探了两口填充井,以从已发现的未开发油藏中提取增量采收率。这包括规划两口水平井,需要利用深部电阻率工具技术进行主动实时地质导向。这些井的目标是确保井位在最佳位置,并在大约100英尺厚的储层内保持轨迹,并且被认为是均匀的油田宽度。该技术面临的主要挑战是该油田的断层性质,以及由于该储层的井眼有限,导致储层厚度和延伸的不确定性。在规划阶段,人们很早就认识到深部电阻率工具将有助于井的地质导向。在钻井之前,设计了一个集成的作业前模型,用于测试多种工具设置和地下场景,以制定执行计划,确定需要实时轨迹调整的关键点,并根据地下场景预先规划替代轨迹,从而实现有效的周转时间,以对实时结果做出反应。传统的导航工具只能产生浅层至中等深度的测量(~15英尺),考虑到地质复杂性(高断层偏移、层状油藏)和井设计(高水平角),这无法满足井的目标。采用超深电阻率(UDR)工具,利用多频率、多间隔的天线设计,从中长间隔的发射机和接收机间隔中提供多达9个矢量分量,实现了高达100英尺的探测深度(DOI)的轨迹优化。实时利用一维反演(利用5个矢量分量)进行早期砂体和流体接触检测。在施工过程中,同一综合团队对井进行监控,地下、地质导向和定向钻井团队之间的密切互动是确保钻井安全、客观进行的关键要求,特别是在疫情期间虚拟作业所带来的挑战。与处理地下不确定性一样,水平井钻井过程中也会遇到许多意外情况。特别是在断层落差不确定性和砂分布问题上。最初的1D实时UDR结果能够帮助实时轨迹调整,并提供有关断层间距和沿井筒可能断层位置的一些地质信息,然后通过井眼图像测井进行确认。此外,钻井后对三维反演图像进行了处理,进一步发现了有关储层沉积趋势的地质信息。在一个最初被认为是富砂且均质的储层中,3D反演显示了可能存在通道的证据。这一发现可以解释在1D UDR区域钻井过程中观察到的储层厚度的变化。未来的工作计划包括对UDR产品的观察和分析,以加深对油田储层的了解。将地震数据和生产数据充分整合的研究将有助于油井和油藏管理。此外,通过优化工具频率,实时使用和校准方位倾角和图像,获得了宝贵的见解,特别是在解决意外的结构和沉积复杂性方面。从实时结果中可以看出,在结构复杂的储层中,流体接触圈定的挑战也很明显,因为接触的多重实现(以及相关概率),这对于再次确认描述油田不确定性的困难是有价值的
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