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High-Resolution Remote Mapping of Thin Sand Lobes with Novel Multilayer Mapping-While-Drilling Tool: A Case Study from Nong Yao Field Offshore Thailand 新型随钻多层成图工具在薄砂叶状体高分辨率遥感成图中的应用——以泰国海上Nong Yao油田为例
Pub Date : 2022-08-08 DOI: 10.2118/209863-ms
Chaiyos Thurawat, W. Teeratananon, T. Ampaiwan, Raweewan Carter, W. Phaophongklai, Pojana Vimolsubsin, R. Watcharanantakul, Haifeng Wang, Trinant Foongthongcharoen, K. Alang
The recent development drilling campaign at Mubadala Petroleum's offshore Nong Yao field faced many challenges, one of which is the complexity of the reservoir which consists of mixed sand-shale sequencies with thin sand lobes of varying thicknesses. To tackle these challenges and to maximize recovery, Mubadala Petroleum planned four horizontal wells for this campaign. However, the conventional methods of geosteering have limitations. For instance, the distance-to-boundary mapping tool typically does not provide large enough depth-of-investigation for the operator to see through the interbedded shale layer to identify the multiple target sand lobes, which could pose limits on the production optimization and ultimately on the final recovery rate. Fortunately, a new technology emerged at the start of the campaign with a potential for a much larger depth of investigation and a better mapping resolution. This multilayer mapping-while-drilling tool was an extension of the previous tool with additional sensors that could read deeper into the formation. Coupled with a new advanced automatic inversion process which utilizes powerful Cloud computing, the subsurface formation resistivity profiles around the wellbore could be mapped clearly up to 25 ft away from the tool, while providing a multilayer mapping with up to 8-layer mapping capability. This new technology was evaluated and applied in two wells in this campaign to resolve the above-mentioned challenges. The result was a resounding success for the Mubadala led drilling team. In this paper, the authors explain the technology, the process of evaluating and applying it to operation, and the results from applying it. This was the first time that this technology was used in Thailand and this case study summarizes a successful outcome. The mapping results from the tool will also be used to update the reservoir model during the post-job phase and provide improvements of the overall reservoir characterization of the field.
Mubadala石油公司海上Nong Yao油田最近的开发钻井活动面临着许多挑战,其中一个挑战是储层的复杂性,储层由混合砂-页岩层序组成,具有不同厚度的薄砂瓣。为了应对这些挑战并最大限度地提高采收率,Mubadala石油公司计划在此次作业中钻4口水平井。然而,传统的地质导向方法存在局限性。例如,距离-边界测绘工具通常不能提供足够大的调查深度,使作业者能够透过互层页岩层来识别多个目标砂体,这可能会限制生产优化,最终影响最终的采收率。幸运的是,一项新技术在竞选之初就出现了,它有可能进行更深入的调查,并提供更好的地图分辨率。这种随钻多层测绘工具是之前工具的扩展,增加了传感器,可以读取更深的地层。再加上利用强大云计算的新型先进自动反演过程,可以在距离工具25英尺的范围内清晰地绘制井筒周围的地下地层电阻率剖面,同时提供多达8层的多层测绘能力。为了解决上述问题,该新技术在该作业的两口井中进行了评估和应用。Mubadala领导的钻井队取得了巨大的成功。本文介绍了该技术、评价和应用的过程以及应用效果。这是该技术首次在泰国使用,本案例研究总结了一个成功的结果。该工具的测绘结果还将用于在作业后阶段更新油藏模型,并改善油田的整体油藏特征。
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引用次数: 0
Application of DNN-TCN Composite Neural Network in Rate of Penetration Prediction DNN-TCN复合神经网络在渗透率预测中的应用
Pub Date : 2022-08-08 DOI: 10.2118/209886-ms
Fei Zhou, H. Fan, Baoping Lu, Hongbao Zhang, Yuhan Liu, Xingang Tao, Kankan Bai
Rate of Penetration (ROP) prediction is the theoretical core of drilling tool selection and drilling parameter optimization. In recent years, researchers have proposed a variety of ROP prediction models, which can usually be divided into the following two types: traditional empirical and theoretical formula methods, and methods based on data-driven or machine learning techniques. However, the above methods only consider the engineering or formation parameters corresponding to the depth to be drilled, while ignoring the force and motion state of the drilling tool of thousands of meters in the irregular wellbore, which makes it difficult to improve the prediction accuracy of the ROP and can't meet the requirements of drilling parameter control in the era of intelligent drilling. This paper proposes a DNN-TCN composite neural network that can handle both non-sequential features and sequential features. The DNN-TCN model not only considers engineering and geological parameters (non-sequential features: weight on bit, revolutions per minute, gamma ray, etc.), but also considers the force and motion states of drilling tools in the wellbore (sequential features: deviation angle, azimuth angle, dog leg, borehole size, diameter of drilling tool, etc.). The first branch of the DNN-TCN model is DNN, which is used to process non-sequential features; the second branch is TCN, which is used to process sequence features. Using a fully connected neural network to fuse the output layers of branch one and branch two, a new network structure can be obtained—DNN-TCN composite neural network. This paper collects data from 50 wells in a specific field to train and test the model. Root mean squared error (RMSE) and a self-definition indicator which named average accuracy (AA) are adopted to evaluate models performance. The results show that the DNN-TCN composite neural network has higher prediction accuracy than traditional theoretical/empirical models and others machine learning models. In addition, because the DNN-TCN model considers the force and motion state of the drilling tool in the wellbore, the accuracy of the ROP prediction for directional wells is greatly improved, which can't be achieved by other models. That is to say, the DNN-TCN model can have better performance, and the model has good universality. The DNN-TCN model combines the following two capabilities: 1, The powerful nonlinear mapping ability of Deep Neural Networks (DNN) in dealing with high-dimensional complex problems; and 2, The long-term memory ability of Temporal Convolutional Neural Network (TCN) in dealing with sequence problems. The model considers the force and motion state of the drilling tool in the wellbore, and effectively improves the prediction accuracy of the ROP. It is an important basis for drilling tool optimization, drilling parameter design and real-time optimization, and helps to improve the intelligence level and construction efficiency of drilling engineering.
机械钻速预测是钻具选择和钻井参数优化的理论核心。近年来,研究人员提出了多种ROP预测模型,通常可分为以下两类:传统的经验和理论公式方法,以及基于数据驱动或机器学习技术的方法。然而,上述方法只考虑了拟钻深度对应的工程或地层参数,而忽略了不规则井筒中数千米钻具的受力和运动状态,使得ROP预测精度难以提高,不能满足智能钻井时代钻井参数控制的要求。提出了一种既能处理非顺序特征又能处理顺序特征的DNN-TCN复合神经网络。DNN-TCN模型不仅考虑了工程地质参数(非序贯特征:钻头重量、每分钟转数、伽马射线等),还考虑了钻具在井筒中的受力和运动状态(序贯特征:井斜角、方位角、狗腿、井眼尺寸、钻具直径等)。DNN- tcn模型的第一个分支是DNN,用于处理非顺序特征;第二个分支是TCN,用于处理序列特征。利用全连通神经网络将分支一和分支二的输出层融合,得到一种新的网络结构——dnn - tcn复合神经网络。本文收集了某油田50口井的数据,对模型进行了训练和测试。采用均方根误差(RMSE)和自定义指标平均精度(AA)来评价模型的性能。结果表明,DNN-TCN复合神经网络的预测精度高于传统的理论/经验模型和其他机器学习模型。此外,由于DNN-TCN模型考虑了钻具在井筒中的受力和运动状态,大大提高了定向井机械钻速预测的精度,这是其他模型无法实现的。也就是说,DNN-TCN模型可以有更好的性能,并且模型具有很好的通用性。DNN- tcn模型结合了以下两种能力:1、深度神经网络(DNN)在处理高维复杂问题时强大的非线性映射能力;2、时序卷积神经网络(TCN)处理序列问题的长期记忆能力。该模型考虑了钻具在井筒中的受力和运动状态,有效提高了机械钻速的预测精度。它是钻井工具优化、钻井参数设计和实时优化的重要依据,有助于提高钻井工程的智能化水平和施工效率。
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引用次数: 0
Combination of Side Entry Sub, Pad Eye Sub, and Swivel Sub Prevents Damage to Wireline Cable and Allows Heave Compensation on a Semi-submersible Rig for Pipe Recovery Operation 侧入短节、垫眼短节和旋转短节的组合可防止电缆损坏,并可在半潜式钻井平台上进行升沉补偿,以便进行管道回收作业
Pub Date : 2022-08-08 DOI: 10.2118/209905-ms
V. Pinprayong, Myo Htet, M. A. Seleman, Annie Lim, Kevin Riaz
Wireline pipe recovery operation on a floater type offshore rig such as a semi-submersible or drillship can be challenging when heave motion affects the wireline cable, depth accuracy, cable tension, rig-up equipment positions, and well control. The heave motion compensator (HMC) unit connected on top of the top-drive system (TDS) has a narrow gap that allows a wireline cable to pass through and could cause damage to the wireline cable. Conventional processes in performing pipe recovery operations only permit operations to occur on the open end of the drillpipe while on the rotary table. With a long bailer arm, the cable will have enough clearance to pass through the elevator then enter the TDS body, but this process also prevents the operator from establishing a barrier for well control situations because the top of the drillpipe remains open. The other issue is depth accuracy, where heave motion causes both upward and downward movement on the cable while wireline is being run in hole (RIH) or pulled out of the hole (POOH). The depth shifts due to heaving motion could cause a back-off string shot to be fired off at depth. To overcome these issues, the Smart Sub system—a combination of a special side-entry sub (SES), pad eye sub, and a swivel sub—allows heave motion to be compensated to the top sheave and enables the wireline cable to be positioned in front of the TDS unlike the conventional method where the cable remains in contact with the TDS. The real result of this combination is studied from the pipe recovery operation performed on semi-submersible rig in Myanmar.
在浮式海上钻井平台(如半潜式钻井船或钻井船)上,当升沉运动影响电缆、深度精度、电缆张力、起吊设备位置和井控时,电缆管回收作业可能会具有挑战性。连接在顶驱系统(TDS)顶部的升沉运动补偿器(HMC)单元有一个狭窄的间隙,允许电缆通过,但可能会损坏电缆。传统的管道回收作业流程只允许在钻杆的开放端进行作业,同时在旋转台上进行作业。由于采用了长筒臂,电缆将有足够的间隙穿过提升机,然后进入TDS本体,但由于钻杆顶部保持打开状态,这一过程也使作业者无法在井控情况下建立屏障。另一个问题是深度精度,当电缆下入井(RIH)或出井(POOH)时,升降运动会导致电缆向上和向下移动。由于起伏运动引起的深度变化可能导致在深度处发射回射孔。为了克服这些问题,Smart Sub系统——一个特殊的侧入式短节(SES)、垫眼短节和旋转短节的组合,可以将升沉运动补偿到顶轮,并使电缆能够定位在TDS的前面,而不像传统方法那样电缆仍然与TDS接触。通过在缅甸半潜式钻井平台上进行的管道回收作业,研究了这种组合的实际效果。
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引用次数: 0
Integrating the Fully Coupled 3D Geomechanical Modeling for Hydraulic Fracturing Optimization of Unconventional Resources 集成全耦合三维地质力学建模的非常规资源水力压裂优化
Pub Date : 2022-08-08 DOI: 10.2118/209847-ms
Leiming Cheng, Ying-wei Wang, Haiyan Zhao, Jiacheng Li, Xiao Liu, Qiyao Liu, Xingning Huang, Thanapol Singjaroen, Piyanuch Kieduppatum
The unconventional oil and gas resources continuously discovered in China are mainly concentrated in the Junggar Basin, Ordos Basin, Sichuan Basin and Songliao Basin. However, the porosity and permeability of its shale reservoirs are extremely low, which brings relatively great difficulties and challenges to the economic development of shale oil reservoir. Long horizontal well section drilling and multi-stage hydraulic fracturing are the key technologies of unconventional resources development. The operations can increase the stimulated volume and ultimately achieve the goal of improving production. In addition, shale reservoirs natural fractures and horizontal bedding are developed, leading to shear slip and tensile failure during the fracturing propagation process. Moreover, the hydraulic fracture is no longer a single symmetrical two-wing fracture, and it is very likely to form a relatively very complex fracture network. This will bring many inconveniences to shale hydraulic fracturing design, fracture monitoring and interpretation, and post-fracturing productivity prediction. Geomechanics is the important influencing parameter that affects the design of hydraulic fracturing. This research is mainly based on the research results of 3D geomechanics to continuously optimize hydraulic fracturing design for horizontal wells. In addition, the implementation of hydraulic fracturing can significantly reduce the seepage resistance of fluids in the formation near the bottom of the well. This will be a very effective mean to increase well production for unconventional resources. Hydraulic fracturing optimization technique fully-coupling 3D geomechanical modeling was applied in the unconventional reservoir in the northeast of Junggar Basin. The shale oil reservoir of Permian Lucaogou formation is one of the main unconventional resources in China. This case study discusses the multi-stages fracturing optimization of horizontal well-A based on the fully coupled 3D Geomechanical modeling. The research result clearly characterizes the stress model variation and reduces the uncertainties in horizontal well-A1 for hydraulic fracturing operation. The uncertainty of the fracture modeling geometry was greatly reduced, and fracture geometry was verified by micro-seismic patterns. The geomechanical modeling helps to optimize the pressure pumping rate, the volume of proppant and fracturing fluids, eventually maximizes the increase of fracture flow conductivity and post-stimulation production.
中国连续发现的非常规油气资源主要集中在准噶尔盆地、鄂尔多斯盆地、四川盆地和松辽盆地。然而,其页岩储层的孔隙度和渗透率极低,给页岩油藏的经济开发带来了较大的困难和挑战。长水平井分段钻井和多级水力压裂是非常规资源开发的关键技术。这些操作可以增加增产量,最终达到提高产量的目的。此外,页岩储层天然裂缝和水平层理发育,导致裂缝扩展过程中出现剪切滑移和张拉破坏。而且水力裂缝不再是单一对称的两翼裂缝,很可能形成一个相对非常复杂的裂缝网络。这将给页岩水力压裂设计、裂缝监测与解释、压裂后产能预测带来诸多不便。地质力学是影响水力压裂设计的重要影响参数。本研究主要基于三维地质力学的研究成果,对水平井水力压裂设计进行持续优化。此外,实施水力压裂可以显著降低井底附近地层流体的渗流阻力。这将是提高非常规资源油井产量的有效手段。将水力压裂优化技术全耦合三维地质力学建模应用于准噶尔盆地东北部非常规储层。二叠系芦草沟组页岩油储层是中国主要非常规油气资源之一。以a水平井为例,探讨了基于全耦合三维地质力学模型的分段压裂优化问题。研究结果清晰地刻画了a1水平井水力压裂应力模型的变化特征,降低了a1水平井水力压裂作业的不确定性。大大降低了裂缝建模几何形状的不确定性,并通过微地震模式验证了裂缝几何形状。地质力学建模有助于优化压力泵送速率、支撑剂和压裂液的体积,最终最大限度地提高裂缝导流能力和增产后产量。
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引用次数: 0
Pragmatic Strategy for Operational and Cost Efficiency Improvement: A Case Study of Rig Selection Strategy for Hydraulic Fracturing Operation in S1 Oil Field Thailand 提高作业效率和成本效益的实用策略:以泰国S1油田水力压裂作业钻机选择策略为例
Pub Date : 2022-08-08 DOI: 10.2118/209843-ms
Thum Sirirattanachatchawan, Sukrit Kanjanarat, Pavin Pirom, Kanwisa Siriphruek, Anan Tantianon, Apiwat Nadoon, Meth Follett, Chatchai Paramart, Arisara Kukiattikoon
This paper aims to elaborate the strategy for operational and cost efficiency improvement by providing an example of a successful case of rig selection strategy for Hydraulic Fracturing Operation in S1 oil field Thailand. The integrated workflow proposed involves all concerned parties to specify the scope of work, analyze internal and external strengths and weaknesses, evaluate possible scenarios, and identify the procurement strategy. As a case of rig selection for fracturing operation in the heterogeneous sandstone, committing the number of candidates before drilling is impossible. Therefore, the typical criteria for fracturing rig selection consider rig move mobility and flexibility in candidate selection. However, in a proven area, the uncertainty of candidate confirmation is manageable. Reservoir engineers provide the number of candidates in 3 scenarios for sensitivity analysis. SWOT analysis and the market survey reveal the possibility to improve both performance and cost by using a warm-stack skidding rig instead of a truck-mounted rig. The sensitivity analysis by using the historical data of each type, indicates that the number of candidates and rig cost play a significant role in cost saving. As a result of analysis and strategy, the operation performance improvesby 34% (2 months reduction) leading to cost-saving by 1MM USD or 24% of the time-dependent cost.
本文旨在通过提供泰国S1油田水力压裂作业钻机选择策略的成功案例,阐述提高作业和成本效率的策略。拟议的综合工作流程涉及所有有关方面,以指定工作范围,分析内部和外部的优缺点,评价可能的情况,并确定采购战略。以非均质砂岩压裂作业的钻机选择为例,在钻井前确定候选钻机的数量是不可能的。因此,压裂钻机选择的典型标准是在选择候选钻机时考虑钻机移动的灵活性。然而,在一个成熟的领域,候选人确认的不确定性是可控的。油藏工程师在3种情况下提供备选方案的数量以进行敏感性分析。SWOT分析和市场调查显示,使用热烟囱钻机代替卡车钻机,可以提高性能和成本。利用每种类型的历史数据进行敏感性分析,表明候选钻机数量和钻机成本对成本节约有显著作用。通过分析和策略,作业性能提高了34%(减少了2个月),节省了100万美元的成本,相当于时间相关成本的24%。
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引用次数: 0
Old Field, New Well: Well Design Challenge for Long-Terms CO2 Storage in a Depleted Field 老油田,新井:枯竭油田长期二氧化碳储存的井设计挑战
Pub Date : 2022-08-08 DOI: 10.2118/209861-ms
Wararit Toempromraj, C. Grant, C. Chanpen, Kittipat Wejwittayaklung, Pornchuda Konganuntragul, P. Bandyopadhyay, Noppadon Kosiri, Naruttee Kovitkanit, Prapapor Jantasuwanna, S. Buapha, Pat Kachondham, Wich Huengwattanakul, Teerath Srikijkarn, Matus Pulsawat, Anucha Thippayawarn, Maneenapang Bunnag, Ghazanfar Shahid, Shelagh J. Baines, Christie Usun Ngau, S. Obrien, Shraddha Chattopadhyay, Lim Sook Fun, Reawat Wattanasuwankorn
Interest in CCS project development is accelerating in SE Asia, driven by the need to monetize emission-intensive assets in the region while complying with increasingly ambitious GHG emissions targets. Depleted hydrocarbon fields represent an attractive storage option for early CCS project due the enhanced understanding of the reservoir, its dynamic behavior, and proven storage capability. Re-use of existing infrastructure also presents the potential to reduce both project costs and time to first injection, however, these brownfield sites also carry significant risk to the long-term, safe containment of injected CO2 through risk of leakage via legacy wells. A methodology is presented in this paper to investigate the risk-reward balance of developing a depleted gas field as a storage site in the Gulf of Thailand. A screening process to assess all abandoned, suspended, and active wells is used to identify wells with re-use potential as CO2 injectors or CO2 plume monitoring wells, and those which represent a leakage risk to the project. A set of legacy well risk identifiers is generated for the field based on well construction records, descriptions of current well barriers, well utilization history, and current best practice guidelines. Southeast Asia has significant remaining reserves of oil and gas, and coal, and an active liquefied natural gas (LNG) export industry. The region's energy demand is increasing rapidly and is forecast to continue to grow over the next decades (World Economic Forum, 2019). To date, fossil fuels have supplied nearly 90% of this growth in the demand for energy in the region (IEA, 2021). To meet this growing energy demand, several new gas projects are under development across Southeast Asia, but many of these are associated with high CO2 gas fields where the produced gas contains significant (up to 70% by volume) CO2 (GCCSI, 2020). In Thailand, where nearly 94% of the primary energy is met by fossil fuels (BP Statistical Review, 2022), the energy sector represents the biggest contributor (74% in 2013) to the country's greenhouse gas emissions (GHG; UNFCCC, 2020). However, as per the nationally determined contribution to the United Nations Framework Convention on Climate Change (UNFCCC), Thailand intends to reduce its GHG emissions by at least 20% from projected business as usual levels by the year 2030 (UNFCCC, 2020). Carbon capture and storage (CCS) represents one option to help meet this increased demand in fossil energy while also reducing GHG emissions. An approach which is gaining traction across the region is to utilize the high concentrations of CO2 stripped out of the raw gas streams at gas processing plants and, instead of venting to atmosphere, the CO2 can be compressed, dehydrated, and transported to suitable long-term storage locations. Depleted oil and gas fields form an attractive opportunity for long-term storage of CO2 due to the wealth of both static and dynamic knowledge available from appraisal throu
由于需要将该地区的排放密集型资产货币化,同时符合日益雄心勃勃的温室气体排放目标,东南亚地区对CCS项目开发的兴趣正在加速。由于对储层及其动态行为的进一步了解,以及已证实的储存能力,枯竭的油气油田为早期CCS项目提供了一个有吸引力的储存选择。现有基础设施的再利用也有可能降低项目成本和首次注入的时间,然而,这些棕地也存在通过旧井泄漏的风险,对注入的二氧化碳的长期安全控制存在重大风险。本文提出了一种方法来研究在泰国湾开发枯竭气田作为储存地点的风险-回报平衡。评估所有废弃井、暂停井和活动井的筛选过程,用于识别具有重复利用潜力的井,作为二氧化碳注入井或二氧化碳羽流监测井,以及对项目构成泄漏风险的井。根据井的施工记录、当前井的障碍描述、井的利用历史和当前的最佳实践指南,为油田生成一套遗留井风险标识符。东南亚拥有大量剩余的石油、天然气和煤炭储量,以及活跃的液化天然气(LNG)出口行业。该地区的能源需求正在迅速增长,预计未来几十年将继续增长(世界经济论坛,2019年)。迄今为止,化石燃料提供了该地区近90%的能源需求增长(IEA, 2021年)。为了满足日益增长的能源需求,东南亚正在开发几个新的天然气项目,但其中许多项目与高二氧化碳气田有关,这些气田的产出气体含有大量(高达70%的体积)二氧化碳(GCCSI, 2020)。在泰国,近94%的一次能源来自化石燃料(BP统计评论,2022年),能源部门是该国温室气体排放的最大贡献者(2013年为74%)。联合国气候变化框架公约》,2020年)。然而,根据《联合国气候变化框架公约》(UNFCCC)的国家自主贡献,泰国打算到2030年将其温室气体排放量从预计的正常水平减少至少20% (UNFCCC, 2020)。碳捕获与封存(CCS)是帮助满足化石能源日益增长的需求,同时减少温室气体排放的一种选择。一种在该地区越来越受欢迎的方法是利用天然气处理厂从原料气流中剥离出来的高浓度二氧化碳,而不是向大气中排放,二氧化碳可以被压缩、脱水并运输到合适的长期储存地点。由于从评估到生产活动中可以获得丰富的静态和动态知识,枯竭的油气田形成了长期储存二氧化碳的诱人机会。枯竭油田还有一个优势,即它们具有有效的碳氢化合物初级密封,经过地质时间的验证,因此通常可以认为通过地质手段泄漏的风险较低。然而,由于遗留井的存在,棕地油田也会增加注入二氧化碳的风险,从而对项目的成功构成挑战。根据井龄、井类型、井历史、井设计以及所采用的封井和弃井方法的不同,现有井的封井风险也不尽相同。本文介绍了泰国湾一个枯竭凝析气田二氧化碳储存可行性研究的结果。该研究的主要目的是:1)确定与现场遗留井完整性相关的项目风险;2)评估二氧化碳注入项目中油井再利用的潜力。重新利用现有油田可以为即将结束生命的资产提供新的生命,从而逐步走向退役和站点关闭。由于在枯竭的油气油田进行商业规模的二氧化碳储存是一个“首创”项目,因此可行性研究旨在评估油田和地面设施在二氧化碳注入和长期储存方面的现状。作为一项可行性研究,技术工作的重点是确定任何可能表明所选地点不适合长期储存二氧化碳的“阻碍因素”,如果确定了足够的积极储存指标,则选择最合适的方案进行概念选择研究,其中将完成更详细的工程研究。
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引用次数: 0
Storage Development Plan SDP for Abandoning High Risk Development Wells and Drilling Fit-For-Purpose CO2 Injectors Offshore Carbon Capture Storage CCS Project 海上碳捕集储存CCS项目:放弃高风险开发井和钻探适合用途的二氧化碳注入器
Pub Date : 2022-08-08 DOI: 10.2118/209884-ms
Mahesh S. Picha, Anil Chuttani
Operators are majorly focusing on zero carbon emission to comply environmental rules and regulations. This paper aims to give insights on world's major CCS project Storage Development Plan (SDP), where CO2 injection wells will be drilled to inject, and store produced CO2 from contaminated fields. To safeguard the CO2 storage containment, the integrity of all wells needs to be scrutinized. Ensuring long-term wells integrity of existing Plug and Abandonment (P&A) and active wells that penetrated the selected CO2 storage reservoir is the key to reduce leakage risks along the wellpath for long-term containment sustainability. Development wells in the identified depleted gas field are more than 30-40 years old and were not designed with any consideration of high CO2 concentration in the reservoir. Possibility of leakage along the wellbores due to accelerated corrosion, channeling, cracks, cannot be ignored and requires careful evaluation. Rigorous process has been adopted in assessing the feasibility for converting existing producers into CO2 injector. Wells disparity between the required defined basis of designs for gas producer and CO2 injection wells governs the re-usability for CO2 injection or needs to be abandoned. New three (3) CO2 injectors with fat to slim design approach, corrosion resistant alloy (CRA) material and CO2 resistant cement are designed in view to achieve lifecycle integrity. Optimum angle of 60deg and maintaining the injection pressure of 50 bar at 90MSCFD rate is required for the injection of supercritical CO2 for 25 years. On top, during well execution, challenges such as anti-collision risk, total loss scenarios while drilling in Carbonate reservoir needs to be mitigated. The completion design is also focusing on having minimal number of completion jewelries to reduce pressure differential & potential leak paths all the way from tubing hangar down to the end of lower completion. Well design optimization from fat to slim has been carried out based on WellCat sensitivity analysis output. Well integrity life cycle monitoring using in country value latest generation fiber optic as well as acquiring seismic for CO2 plume development.
运营商主要关注零碳排放,以遵守环境法规。本文旨在深入了解全球主要的CCS项目存储发展计划(SDP),该计划将钻探二氧化碳注入井,以注入和储存污染油田产生的二氧化碳。为了保护二氧化碳储存容器,需要仔细检查所有井的完整性。确保现有封井弃井(P&A)和穿透选定二氧化碳储层的活动井的长期完整性,是降低沿井径泄漏风险、实现长期密封可持续性的关键。在已确定的枯竭气田中,开发井的井龄超过30-40年,并且在设计时没有考虑到储层中高浓度的二氧化碳。由于加速腐蚀、窜流、裂缝,沿井筒发生泄漏的可能性不容忽视,需要仔细评估。在评估将现有的生产者转变为二氧化碳注入器的可行性时,采用了严格的程序。产气井和注二氧化碳井的设计要求之间的差异决定了注二氧化碳井的可重复使用性,或者需要放弃。新型三(3)CO2喷射器采用从肥到瘦的设计方法,采用耐腐蚀合金(CRA)材料和耐CO2水泥,以实现生命周期的完整性。注入超临界二氧化碳需要60度的最佳角度,并以90MSCFD的速率保持50 bar的注入压力,持续25年。最重要的是,在钻井过程中,需要减轻诸如防碰撞风险、碳酸盐岩储层钻井时的全漏失等挑战。完井设计还注重最小化完井珠宝的数量,以减少从油管库到下部完井末端的压差和潜在泄漏路径。基于WellCat灵敏度分析输出,进行了从胖到瘦的井设计优化。利用最新一代光纤进行油井完整性生命周期监测,并获取二氧化碳羽流发展的地震信息。
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引用次数: 1
Aquatic Animal Monitoring System 水生动物监测系统
Pub Date : 2022-08-08 DOI: 10.2118/209933-ms
Jakkawan Sakirin, Thaniyaporn Rapeethasanaphong, Parichat Maleewong
Aquatic Animal Monitoring Systemis initiated as part of PTTEP's Ocean for Life strategy as we thrive in enhancing Ocean Health & Biodiversity Monitoring to ensure that PTTEP's offshore operations are friendly and safe to the surrounding environment and aquatic animals. The basis of the Aquatic Animal Monitoring Systemproject focuses on conservation survey and tracking of rare aquatic animals as well as marinebiodiversity. As part of the process, an underwater camera was installed on a jacket leg of PTTEP's platform to allow the video recording of underwater lives. The video footage was then analyzed by Artificial Intelligence (AI)software using an object detection method for determining the animal's categorization, then using machine learning algorithm for more accuracy. This concept can visualize aquatic animals around the platform and the surrounding environment. Moreover, the AI software can shorten the video by cutting off any non-life appearing period. Therefore, this technique can support a processor during the video analysis from the platform, contributing to a better work efficiency as it can save time, manpower, and most importantly cost. For the detection algorithm, all targets generatea large amount of data in the form of images with labels in order to train a software to memorize the target objects. The AI software was able to detect and identify nine species of aquatic animals which are fish, turtle, whale, dolphin, shark, seal, sea lion, stingray, and seahorse. With AI software in place, the video raw file can be shortened up to 85% by removing non-life periods in the original video and tracking only animal life in the video frame. This is a significant milestone for PTTEP in creating sustainable values to the ocean, which is considered as PTTEP's second home. Adopting artificial intelligence and machine learning technology to this project, it helps categorizing aquatic animal types and shorten a videofile. Moreover, it can save manpower and time.
水生动物监测系统是PTTEP海洋生命战略的一部分,因为我们在加强海洋健康和生物多样性监测方面蓬勃发展,以确保PTTEP的海上作业对周围环境和水生动物是友好和安全的。水生动物监测系统项目的基础是珍稀水生动物的养护调查和跟踪以及海洋生物多样性。作为这个过程的一部分,一个水下摄像机被安装在PTTEP平台的夹克腿上,以便对水下生命进行视频记录。然后,人工智能(AI)软件使用物体检测方法对视频片段进行分析,以确定动物的分类,然后使用机器学习算法提高准确性。这个概念可以将平台周围的水生动物和周围环境形象化。此外,人工智能软件可以通过切断任何非生命出现的时间段来缩短视频。因此,该技术可以在平台上支持处理器进行视频分析,从而提高工作效率,节省时间、人力,最重要的是节省成本。在检测算法中,所有目标都会以带有标签的图像形式产生大量数据,以训练软件记忆目标对象。人工智能软件能够检测并识别鱼、海龟、鲸鱼、海豚、鲨鱼、海豹、海狮、黄貂鱼、海马等9种水生动物。有了人工智能软件,通过删除原始视频中的非生命周期,只跟踪视频帧中的动物生命,视频原始文件可以缩短85%。这是PTTEP在为海洋创造可持续价值方面的一个重要里程碑,海洋被视为PTTEP的第二个家园。该项目采用人工智能和机器学习技术,帮助对水生动物类型进行分类,并缩短视频文件。此外,它可以节省人力和时间。
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引用次数: 0
Innovative Monobore Solid Expandable Tubular System for Isolating Severe Losses 用于隔离严重漏失的创新单孔固体膨胀管系统
Pub Date : 2022-08-08 DOI: 10.2118/209852-ms
G. Zhan, Abdulwahab S. Aljohar, Jianhui Xu, Bodong Li, Huijuan Guo
The monobore solid expandable tubular (MSET) system, which maintains the same drift as the previous casing and enables the operator to maintain an original drilling plan to total depth, is the next generation solid expandable tubular technology - the most advanced expandable liner system available typically to isolate severe losses or trouble zones while drilling. To address the major technical challenges of a large expansion ratio required to meet MSET requirement, and able to deliver potential longer MSET liner without a concern of premature expansion problem, this paper presents an innovative solution consisting of a safe release mechanism (SRM) for running MSET incorporating a dual-stage expansion mechanism. This paper presents an innovative approach to the reliability of this mechanism based on Finite Element Analysis (FEA) simulation and indoor tests, as well as a dual-stage expansion process. The dual-stage expansion offers the advantage of a relative ease on the expandable thread when undergoing a large physical expansion, and therefore leads to a less risk of thread failure during the expansion process. The new SRM transfers the weight of the MSET from the cone surface to a collet-finger type plug-in structure, which can be unlocked by hydraulic pressure when the MSET is run to the intended depth. Based on the result of simulation, an indoor test was conducted and the load capacity of SRM was up to 109 tons, which is safe for at least 1,000 ft MSET. The newly developed tubular with proprietary expandable thread was successfully deployed with a better than expected quality, enabling a successful run of quite long 2,250 feet expandable liner with a steady expansion pressure, and post expansion pressure test without any problem, and as expected, delivered a designed post expansion pipe ID. Most importantly the deployment of expandable liner resolved the severe loss drilling problem, enabled to raise mud weight from 1.05g/cm3 to 1.78g/ cm3,met the requirement of allowing drilling with 190.5mm (7-1/2″) bit and enabled drilling operation to resume and continue drilling a horizontal section without any major problem. This paper presents a combined (computer simulation and indoor tests for calibration) approach to conducting an advanced monobore solid expandable tubular technology development. The innovative safe release mechanism and dual-stage expansion process assures the application success of the MSET system in optimizing well casing designs for effectively addressing challenges in severe drilling losses.
单孔固体膨胀管(MSET)系统是下一代固体膨胀管技术,它与以前的套管保持相同的进深,使作业者能够保持原始的钻井计划到总深度,是目前最先进的膨胀尾管系统,通常用于隔离钻井过程中的严重漏失或故障区域。为了解决满足MSET要求所需的大膨胀比的主要技术挑战,并能够在不担心过早膨胀问题的情况下提供更长的MSET尾管,本文提出了一种创新的解决方案,该解决方案包括用于运行MSET的安全释放机构(SRM),该机构包含双级膨胀机构。本文提出了一种基于有限元分析(FEA)仿真和室内试验的创新方法,以及双阶段扩展过程。双级膨胀的优点是,在进行大的物理膨胀时,可膨胀螺纹相对容易,因此在膨胀过程中降低了螺纹失效的风险。新型SRM将MSET的重量从锥面转移到夹指式插入式结构上,当MSET下入到预定深度时,可以通过液压解锁。基于模拟结果,进行了室内试验,SRM的承载能力高达109吨,对于至少1,000 ft的MSET是安全的。新开发的具有专有可膨胀螺纹的管成功下入,质量好于预期,在稳定的膨胀压力下,成功下入了2250英尺长的可膨胀尾管,并进行了膨胀后压力测试,没有出现任何问题,并且如预期的那样,提供了设计的膨胀后管径。最重要的是,可膨胀尾管的使用解决了严重的钻井漏速问题,使泥浆比重从1.05g/cm3提高到1.78g/ cm3,满足了190.5mm(7-1/2″)钻头的钻井要求,并使钻井作业得以恢复,并在没有任何重大问题的情况下继续钻井水平段。本文介绍了采用计算机模拟与室内试验校准相结合的方法进行先进的单孔固体膨胀管技术开发。创新的安全释放机制和双级膨胀工艺确保了MSET系统在优化套管设计方面的成功应用,从而有效应对严重钻井漏失的挑战。
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引用次数: 0
Innovative Automated Data Driven Daily Drilling Reporting Using Automated Data-Driven Models and a Digital Execution Platform 采用自动化数据驱动模型和数字执行平台的创新自动化数据驱动每日钻井报告
Pub Date : 2022-08-08 DOI: 10.2118/209894-ms
Hamdi Mohamad, Felicity Anai Anak Michael Mulok, Douwe Franssens, Nurfitrah Mat Noh, Diego Patino, Janna Tiong Mang Ing
Currently, Automated Reporting leverages rig-sensors to produce ‘Activity’ and populated the Daily Drilling Report (DDR), replacing the labour-intensive manual entries. However, Surface and non-drilling activities cannot be detected in this way. The case study documents the complimentary use of a digital execution platform in filling these gaps. The automated daily drilling reporting solely on real-time rig sensors input causes a substantial number of non-drilling activities to be excluded and the data is not sufficient to produce solid 24-hour activities as required. Therefore, this paper presents a reporting solution that combines both real-time rig sensors input and activity tracking from a digital execution platform thus enabling the next level of reporting automation. Furthermore, the combination of these two sources ensures reporting accuracy and provides granularity for the next level of performance benchmarking. The paper documents the vision, methodology, implementation steps, challenges, and benefits of automating daily drilling reporting. The results of the case study were thoroughly discussed. The overall approach that was undertaken is straightforward where observation was conducted by identifying the similarity and differences of activities detected in the manual DDR and the improved automated reporting activities. The gap between the drilling activities (rig states) and non-drilling activities is corrected through a process of "cut and split" to capture the 24 hours activities. The planned activities were imported and monitored in the Digital Execution Platform, translated into WITSML (Wellsite Information Transfer Standard Markup Language) Drillreport object. Simultaneously, the real-time rig sensors data are available as WITSML log objects. DrillOps Report executes three tasks: Populate the sensor activities (Referred to as Automated Rig State Activity) by utilizing the "Fixed Text Remark" capability.Filter DrillReport object for actual activities on the rig marked as completed (Referred to as External Activity) by supervisors on the rig to populate all valid activities on rig.Overlapped activities in (1) and (2) will be cut and split accordingly where (1) supersedes the (2) as the single source of truth is the rig states detected by the rig sensors. On non-drilling days, (2) supersedes. This is referred to as Machine Activity Record (MAR). Other DDR information required is populated via FileBridge where the readily available information is parsed from the contractors' own reports into Automated Operational Reporting Solution. By utilizing the automated daily drilling reporting capabilities, rigsite users were able to reduce the time spent in capturing and entering the information required as part of the DDR. The rigsite personnel was then able to direct their attention on running daily data QA/QC prior to the daily report submission. This then allows them to put more focus on optimizing their wellsite operational performan
目前,自动化报告利用钻机传感器生成“活动”并填充每日钻井报告(DDR),取代了劳动密集型的人工输入。然而,地面和非钻井活动无法通过这种方式检测到。该案例研究记录了数字执行平台在填补这些空白方面的免费使用。仅根据实时钻机传感器输入的自动每日钻井报告导致大量非钻井活动被排除在外,数据不足以产生所需的24小时稳定活动。因此,本文提出了一种报告解决方案,结合了实时钻机传感器输入和数字执行平台的活动跟踪,从而实现了更高水平的报告自动化。此外,这两个来源的组合确保了报告的准确性,并为下一级性能基准测试提供了粒度。该文件记录了自动化每日钻井报告的愿景、方法、实施步骤、挑战和好处。对案例研究的结果进行了深入的讨论。所采取的总体方法是直接的,通过确定在手动DDR和改进的自动报告活动中检测到的活动的相似性和差异性来进行观察。钻井活动(钻机状态)和非钻井活动之间的差距通过“切割和分割”过程来纠正,以捕获24小时的活动。计划的活动在数字执行平台中被导入和监控,并转化为WITSML(井场信息传输标准标记语言)钻井报告对象。同时,实时钻机传感器数据可作为WITSML测井对象使用。drilllops Report执行三个任务:利用“Fixed Text Remark”功能填充传感器活动(称为自动化钻机状态活动)。过滤DrillReport对象,将钻机上的实际活动标记为已完成(称为外部活动),以填充钻机上的所有有效活动。(1)和(2)中的重叠活动将被相应地切割和分割,其中(1)取代(2),因为事实的单一来源是钻机传感器检测到的钻机状态。在非钻井日,(2)取代。这被称为机器活动记录(MAR)。其他所需的DDR信息通过FileBridge进行填充,在FileBridge中,可以将承包商自己的报告中的现成信息解析为自动化操作报告解决方案。通过利用自动化的每日钻井报告功能,现场用户能够减少捕获和输入DDR所需信息所花费的时间。在提交日常报告之前,现场人员可以将注意力集中在运行日常数据QA/QC上。这使得他们能够更加专注于优化井场作业性能,并计划当前活动的任何潜在结果。结构化数据将使钻井后的可操作洞察分析成为可能。
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