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Collaborating Authors
Xi'an Shiyou University
A Sequential Feature-Based Rate of Penetration Representation Prediction Method by Attention Long Short-Term Memory Network
Cheng, Zhong (Xi'an Shiyou University / CNOOC Ener Tech-Drilling and Production Co. (Corresponding author)) | Zhang, Fuqiang (Xi'an Shiyou University) | Zhang, Liang (CNOOC Ener Tech-Drilling and Production Co.) | Yang, Shuopeng (Xi'an Shiyou University) | Wu, Jia (Xi'an Shiyou University) | Li, Tiantai (Xi'an Shiyou University) | Liu, Ye (Xi'an Shiyou University)
Summary In the petroleum and gas industry, optimizing cost-effectiveness remains a paramount objective. One of the key challenges is enhancing predictive models for the rate of penetration (ROP), which are intricately tied to the delicate interplay between significant parameters and drilling efficiency. Recent research has hinted at the potential of temporal and sequential elements in drilling, but a detailed exploration and understanding of these dynamics remain underdeveloped. Addressing this research gap, our primary innovation is not just the introduction of a model but rather the employment of the attention-based long short-term memory (LSTM) network as a tool to deeply analyze the role of sequential features in ROP prediction. Beyond merely applying the model, we furnish a robust foundation for sequential analysis, detailing data processing methods and laying out comprehensive data analytics guidelines for such temporal assessments. The utilization of the LSTM network, in this context, ensures meticulous capture of real-time drilling data nuances, providing insights that are both profound and actionable. Through empirical evaluations with real-world data sets, we accentuate the vital importance of time-sequential dynamics in refining ROP predictions. Our methodological approach, tailored for the oilfield domain, is both rigorous and illuminating, achieving an R score of 0.95 and maintaining a relative error under 10%. This effort goes beyond simply proposing a new predictive mechanism. It establishes the centrality of sequential analysis in the drilling process, charting a course for future research and operational optimization in the petroleum and gas sector. We not only offer enhanced modeling strategies but also pioneer insights that can shape the next frontier of industry advancements.
- Asia > China (0.68)
- North America (0.67)
Xinjiang Agricultural University Summary The rotary steerable drilling system is an advanced drilling technology, with stabilized platform toolface attitude control being a critical component. Due to a multitude of downhole interference factors, coupled with nonlinearities and uncertainties, challenges arise in model establishment and attitude control. Furthermore, considering that stabilized platform toolface attitude determines the drilling direction of the entire drill bit, the effectiveness of toolface attitude control will directly impact the precision and success of drilling tool guidance. In this paper, a mathematical model and a friction model of the stabilized platform are established, and an improved deep deterministic policy gradient (I_DDPG) attitude control method is proposed to address the friction nonlinearity problem existing in the rotary steering drilling stabilized platform. A prioritized experience replay based on temporal difference (TD) error and policy gradient is introduced to improve sample usage, and high similarity samples are pruned to prevent overfitting. Furthermore, SumTree structure is adopted to sort samples for reducing computational effort, and a double critic network is used to alleviate the overestimated value. Numerical simulation results illustrate that the stabilized platform attitude control system based on I_DDPG can achieve high control accuracy with both strong anti-interference capability and good robustness.
- Asia > China (1.00)
- North America > Canada > Alberta (0.28)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drilling Equipment (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Neural networks (0.68)
An Adaptive Grid Refinement Method for Flow-Based Embedded Discrete Fracture Models
Li, Junchao (Xi'an Shiyou University) | Tang, Huiying (Southwest Petroleum University) | Zhang, Yongbin (Research Institute of the Tarim Oilfield, CNPC) | Li, Xin (Research Institute of Petroleum Exploration and Development, CNPC)
Abstract Projection-based embedded discrete fracture models (pEDFMs) are proven effective for modeling flow barrier effects of high-conductivity or impermeable fractures. However, local grid refinements are still needed to improve the accuracy of simulation in flow areas near fractures. In recent years, adaptive grid refinement techniques have received a lot of attention for dealing with highly heterogeneous and fractured models. But few of them are capable of EDFMs. In this paper, an adaptive grid refinement method under flow-based EDFMs (fEDFMs) is proposed for fractured models. The method starts from an fEDFM model which is built by a new technique of transmissibility modification by introducing an artificial pseudo-steady flow near fractures. Adaptive grid refinement and coarsening procedures are designed under an adaptive criterion based on both the fracture distribution and flow solutions. A flow-based upscaling procedure is adopted to form transmissibilities of the hybrid grids and the solution is mapped from the former grid system. The adaptive grid refinement method is applied in a validation case and a real field case, respectively. In each case, comparisons are made between the simulation results of the proposed adaptive grid refinement models and traditional uniform pEDFMs. Besides, comparisons are also made with the overall fine-scale models which serve as the reference models. The comparisons show that the numerical results of the proposed models have a better match to that of the reference models. And it is proven that the approach is more robust when applied to more general flow scenarios with extremely high or completely sealed fractures which could have a great impact on the flow. The proposed method aims to improve the accuracy of numerical simulation for fractured reservoirs.
- Asia > China (0.28)
- North America > United States > Texas (0.28)
An Optimal Design Algorithm for Proppant Placement in Slickwater Fracturing
Wang, HaiYang (Xi'an Shiyou University) | Zhou, Desheng (Xi'an Shiyou University) | Xu, Jinze (Xi'an Shiyou University) | Liu, Shun (Xi'an Shiyou University) | Liu, Erhu (Yanchang Petroleum Group ExplorationCompany) | Gao, Qian (Xi'an Shiyou University) | Liu, Xiong (Xi'an Shiyou University) | Guo, Minhao (Northwest University) | Wang, Panfeng (China Petroleum Pipeline Engineering Co.,Ltd.)
Abstract Slickwater fracturing technology is one of the significant stimulation measures for the development of unconventional reservoirs. An effective proppant placement in hydraulic fractures is the key to increase the oil production of unconventional reservoirs. However, previous studies on optimizing proppant placement are mainly focused on CFD numerical simulation and related laboratory experiments, and an optimization design method that comprehensively consider multiple influencing factors has not been established. The objective of this study is to establish an optimal design algorithm for proppant placement based on the construction characteristics of slickwater fracturing combined with Back Propagation (BP) neural network. In this paper, a proppant placement simulation experimental device was built to analyze proppant placement form data. We established a BP neural network model that considers multiple influencing factors and used the proppant placement form data to train and calibrate the model, which the proppant placement form prediction model is finally obtained. Using the proppant placement form prediction model, we designed an algorithm that can quickly select the three groups of construction schemes with the best proppant-filling ratio based on the massive construction schemes. The results indicate that the prediction results of the algorithm for proppant placement form are consistent with the CFD simulation results and experimental results, and the numerical error of the balanced height and the distance between the front edge of the proppant sandbank and the fracture entrance is within 5%. After using this algorithm to optimize the design of the fracturing construction scheme for the C8 oil well in Changqing Oilfield, the stimulation performance of the C8 oil well after fracturing is 2.7 times that of the adjacent well. The optimal design algorithm for proppant placement established in this paper is an effective, accurate, and intelligent optimization algorithm. This algorithm will provide a novel method for hydraulic fracturing construction design in oilfields.
- Asia > China > Shaanxi Province (0.35)
- Asia > China > Shanxi Province (0.25)
- Asia > China > Ningxia Hui Autonomous Region (0.25)
- (2 more...)
- Asia > China > Shanxi > Ordos Basin > Changqing Field (0.99)
- Asia > China > Shaanxi > Ordos Basin > Changqing Field (0.99)
- Asia > China > Ningxia > Ordos Basin > Changqing Field (0.99)
- (2 more...)
Efficient Preparation of Nano-Starch Particles and Its Mechanism of Enhanced Oil Recovery in Low-Permeability Oil Reservoirs
Zhang, Lei (China University of Geosciences (Wuhan) and Xi'an Key Laboratory of Tight Oil (Shale Oil) Development (Xi'an Shiyou University)) | Jing, Cheng (Xi'an Shiyou University) | Khan, Nasir (Balochistan University of Information Technology, Engineering & Management Sciences) | He, Yanlong (Xi'an Shiyou University) | Gu, Xiaoyu (Xi'an Shiyou University) | Zheng, Liming (Yanshan University)
Summary As development of low-permeability oil reservoirs continues to increase, it urgently needs an efficient enhanced oil recovery (EOR) technology to adapt to the new situation and requirement of oilfield exploitation. Although the application of nanomaterials for the EOR of low-permeability oil reservoirs has initially obtained good results, the types of currently used nanomaterials in the field of EOR are limited, and the mechanism of EOR is still unclear. In this paper, a type of nanosized starch particle is efficiently prepared using the method of precipitation with the help of ultrasonic oscillation. Under ultrasonic oscillation, the viscosity of starch paste can be significantly decreased, which is beneficial for the precipitation of starch nanoparticles. After ultrasonic oscillation, the size of the developed nanoparticles is smaller and controlled during the precipitation of starch paste using ethanol as the precipitating agent. The developed nanosized starch particles are suitable for the lowpermeability oil reservoirs with low-salinity water. Subsequently, the mechanism of EOR of the developed nanosized starch particles is systematically studied through laboratory experiments. In addition to changing the wettability of rock surface and decreasing oil/water interfacial tension (IFT), the nanosized starch particles can effectively change the motion state of water molecules and cause the change of the structure of water molecules. In the low-permeability core, the displacement front of the nanosized starch solution is uniform, and the sweep volume of the nanosized starch solution flooding is large. Because of a higher sweep volume and a smaller adsorption loss, nanosized starch solution flooding can achieve a better effect of oil recovery than surfactant flooding in 30 m of low-permeability porous medium. The conclusions can provide a new guidance for EOR technology to support the efficient development of low-permeability oil reservoirs. Introduction Presently, oil production of low-permeability oil reservoirs occupies an important role in the global oil and gas industry (Teklu et al. 2018; Wang et al. 2018a).
- North America > United States (1.00)
- Asia > China > Shaanxi Province (0.46)
- Africa > Middle East > Egypt (0.28)
- Geology > Mineral (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Geology > Rock Type (0.93)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Asia > China > Shanxi > Ordos Basin > Changqing Field (0.99)
- Asia > China > Shaanxi > Ordos Basin > Changqing Field (0.99)
- Asia > China > Ningxia > Ordos Basin > Changqing Field (0.99)
- (5 more...)
Rapid Development of Multi-Source Heterogeneous Drilling Data Service System
Cheng, Zhong (CNOOC Ener Tech-Drilling &Production Co.) | Xu, Rongqiang (CNOOC Ener Tech-Drilling &Production Co.) | Chen, Jianbing (CNOOC Ener Tech-Drilling &Production Co.) | Li, Ning (CNOOC Ener Tech-Drilling &Production Co.) | Yu, Xiaolong (CNOOC Ener Tech-Drilling &Production Co.) | Ding, Xiangxiang (CNOOC Ener Tech-Drilling &Production Co.) | Cao, Jie (Xi'an Shiyou University)
Abstract Digital oil and gas field is an overly complex integrated information system, and with the continuous expansion of business scale and needs, oil companies will constantly raise more new and higher requirements for digital transformation. In the previous system construction, we adopted multi-phase, multi-vendor, multi-technology and multi-method, resulting in the problem of data silos and fragmentation. The result of the data management problems is that decisions are often made using incomplete information. Even when the desired data is accessible, requirements for gathering and formatting it may limit the amount of analysis performed before a timely decision must be made. Therefore, through the use of advanced computer technologies such as big data, cloud computing and IOT (internet of things), it has become our current goal to build an integrated data integration platform and provide unified data services to improve the company's bottom line. As part of the digital oilfield, offshore drilling operations is one of the potential areas where data processing and advanced analytics technology can be used to increase revenue, lower costs, and reduce risks. Building a data mining and analytics engine that uses multiple drilling data is a difficult challenge. The workflow of data processing and the timeliness of the analysis are major considerations for developing a data service solution. Most of the current analytical engines require more than one tool to have a complete system. Therefore, adopting an integrated system that combines all required tools will significantly help an organization to address the above challenges in a timely manner. This paper serves to provide a technical overview of the offshore drilling data service system currently developed and deployed. The data service system consists of four subsystems. They are the static data management system including structured data (job report) and unstructured data (design documentation and research report), the real-time data management system, the third-party software data management system integrating major industry software databases, and the cloud-based data visual application system providing dynamic analysis results to achieve timely optimization of the operations. Through a unified logical data model, it can realize the quick access to the third-party software data and application support; These subsystems are fully integrated and interact with each other to function as microservices, providing a one-stop solution for real-time drilling optimization and monitoring. This data service system has become a powerful decision support tool for the drilling operations team. The learned lessons and gained experiences from the system services presented here provide valuable guidance for future demands E&P and the industrial revolution.
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Data Science & Engineering Analytics > Information Management and Systems > Artificial intelligence (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Geologic modeling (0.94)
- (3 more...)
Physical Simulation of Hydraulic Fracturing of Large-Sized Tight Sandstone Outcrops
Guo, Tiankui (China University of Petroleum (Huadong)) | Tang, Songjun (China University of Petroleum (Huadong)) | Liu, Shun (Xi'an Shiyou University) | Liu, Xiaoqiang (China University of Petroleum) | Xu, Jianchun (China University of Petroleum) | Qi, Ning (China University of Petroleum) | Rui, Zhenhua (Massachusetts Institute of Technology and China University of Petroleum (Beijing))
Summary Hydraulic fracturing is an indispensable technology in developing tight oil and gas resources. However, the development of tight oil and gas is not consistently satisfactory. Further understanding of hydraulic fracturing of tight sandstone is required, which increases the production of tight oil and gas reservoirs, particularly in China. Currently, there are a few true triaxial hydraulic fracturing physical simulations of large tight sandstone outcrops. To weaken the boundary effect, this study performed simulations using large tight sandstone outcrops (500โรโ500โรโ500โmm and 500โรโ500โรโ800โmm) in the Shahezi Formation (Fm.), Jilin Province, China. The effect of natural fracture (NF) development degree, in-situ stress conditions, fracturing treatment parameters, and temporary plugging on fracture propagation were investigated. Furthermore, fracture propagation was investigated based on post-fracturing fine reconstruction, high-energy computed tomography (CT) scan, acoustic emission monitoring (AEM), and analysis of a fracturing pressure curve. Finally, suggestions on fracturing treatment were proposed. The results show that the NF is a key factor in determining the hydraulic fracture (HF) morphology in the tight sandstone reservoir. Further, the number, approaching angle, and cementation strength of the preexisting NF affect the HF propagation path; these are the key factors for forming complex fractures. In the tight sandstone reservoir with well-developed NFs, the fracture morphology is dominated by the NF under horizontal differential stressโโคโ9โMPa. A single fracture is more likely to occur under horizontal differential stressโโฅโ12โMPa, which is less affected by the NF. In the fracturing at variable injection rates, a low rate facilitates fluid penetration into the NF, while a high rate facilitates deep HF propagation. A low-viscosity fracturing fluid at a high rate facilitates further propagation of the temporary plugging agent (TPA), thus achieving deep temporary plugging and fracture diversion. A high-viscosity fluid does not facilitate accumulation and plugging of particulate TPA. Higher horizontal differential stress leads to a smaller diversion radius of new HF, which is closer to the original HF, leading to poorer stimulation effect. The results provide a reference for the fracturing design of the tight sandstone.
- Asia > China > Jilin Province (0.34)
- North America > United States > Texas (0.28)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- Asia > China > Northeast China > Songliao Basin > Shahezi Formation (0.99)
- Asia > China > Heilongjiang > Songliao Basin > Daqing Field > Yian Formation (0.99)
- Asia > China > Heilongjiang > Songliao Basin > Daqing Field > Mingshui Formation (0.99)
Digital Documentation and Data Management for Offshore Drilling
Cheng, Zhong (Xi'an Shiyou University and CNOOC Ener Tech-Drilling & Production Co.) | Xu, Rongqiang (CNOOC Ener Tech-Drilling &Production Co.) | Yu, Xiaolong (CNOOC Ener Tech-Drilling &Production Co.) | Hao, Zhouzheng (CNOOC Ener Tech-Drilling &Production Co.) | Ding, Xiangxiang (CNOOC Ener Tech-Drilling &Production Co.) | Li, Man (CNOOC Ener Tech-Drilling &Production Co.) | Li, Mingming (CNOOC Ener Tech-Drilling &Production Co.) | Li, Tiantai (Xi'an Shiyou University) | Gao, Jiaxuan (Xi'an Shiyou University)
Abstract Upstream Oil & Gas industry recognizes that there are significant gains to be had by the implementation of new digital technologies. For offshore exploration and development, the goal is to bring together all domains, all data, and all engineering requirements in a seamlessly interconnected solution. The industry is putting significant efforts into using instrumentation and software to optimize operations in all domains for exploration and production (E&P) to move towards the digital oil field of the future. an innovative digital solution has been designed and implemented to cover all different aspects of the well planning and engineering workflows, delivering a step change in terms of capabilities and efficiency. As part of this transformation process, CNOOC have implemented integrated data management project of geological engineering for covering all different aspects of the well engineering workflows, delivering a step change in terms of capabilities and efficiency. The objective is to provide a continuous improvement platform to users for: Digitalization can reduce the time spent with daily documentation and simultaneously increase the quality by removing an error prone way of work. Technological solution enabling real-time data transmission from all rigs to CNOOC onshore headquarters and enabling real-time visualizations of the drilling data. This includes workload, number of needed rigs, daily performance, key performance indicators and even operation time forecasts based on real data. Engineering solution to transform expert experience and accident cases into information to easily identify the areas of operational improvement allowing to implement specific measures to reduce intangible loss time (ILT) and non-productive time (NPT) which can help in reducing costs. This project has also provided a real geological drilling environment where high frequency real-time drilling data is utilized along with low frequency daily drilling report data to provide better insights for well planning and generate ideas for improving performance and reducing risk. This paper presents a full description of a new industry standard digital well construction solution that has the potential to transform the well operation process by providing a step change in collaboration, concurrent engineering, automation, and data analytics. Furthermore, the cloud-deployed solution challenges will be briefly discussed. The learned lessons and gained experiences from this project construction presented here provide valuable guidance for future demands E&P and digital transformation.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > China Government (0.70)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Management > Asset and Portfolio Management > Field development optimization and planning (1.00)
- (4 more...)
A Comprehensive Workflow for Propagation Simulation and Structural Characterisation of Multiple Hydraulic Fractures in Naturally Fractured Unconventional Oil Reservoirs
Ren, Long (Xi'an Shiyou University) | Zhan, Shiyuan (Shaanxi Key Laboratory of Advanced Stimulation Technology for Oil & Gas Reservoirs) | Zhou, Desheng (University of Alberta) | Su, Yuliang (China University of Petroleum, East China) | Wang, Wendong (Xi'an Shiyou University) | Chen, Mingqiang (Shaanxi Key Laboratory of Advanced Stimulation Technology for Oil & Gas Reservoirs) | Jing, Cheng (China University of Petroleum, East China) | Sun, Jian (China University of Petroleum, East China) | Tang, Kang (Xi'an Shiyou University)
Abstract Multiple hydraulic fractures in naturally fractured unconventional oil reservoirs have often induced complex fracture network growth, as revealed by microseismic monitoring data by Maxwell et al. (2002), Fisher et al. (2005) and Daniels et al. (2007). History matching and production forecasting from an unconventional oil reservoir is possible only if a complex fracture network can be clearly described through the engineering parameters. However, currently, the integration technology of propagation simulation and structural characterization of the complex fracture network is still an extreme challenge. A new propagation modeling and characterization technique has been developed for these complex fracture network expansion that combines improved displacement discontinuity method (DDM) and pseudo-3D fracture propagation model to simulate the propagation process of complex fracture network and improve stimulation accuracy. This is very important for modeling and simulation of multi-fracture propagation in a unconventional oil reservoir with natural fractures. The theoretical model include the calculation model of combined stress field, the mechanical model of fracture propagation patterns and the corresponding propagation criteria, the injection fluid distribution model, and the mathematical model for structural description and morphological characterization as a post-processing program. The propagation simulation results of complex fracture network are implicitly and directly entered into the post-processing program and characterized by some engineering parameters as well. Simulation results show that the different propagation patterns of fracture network are produced, which is governed by the in-situ stress anisotropy, hydraulic fracture density, and distribution modes of pre-existing natural fracture as well as fractures interaction angle. More importantly, the simulation results can be characterized as different engineering parameters containing the fracture network bandlength, bandwidth, stimulated reservoir area (SRA) and fracture width. The presented comprehensive workflow could assists the reservoir engineers in clearly understanding and evaluating the complex fracture network, including geometrical morphology, spatial distribution, and conductivity of complex fracture networks. The propagation simulation and structural characterization technique presented in this paper can help identify stimulation and forecasting strategies that will significantly improve well performance and ultimate recovery from an unconventional oil reservoir.
- North America > United States > Texas (0.28)
- Asia > China > Shaanxi Province (0.28)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Information Technology > Modeling & Simulation (1.00)
- Information Technology > Communications > Networks (0.94)
Development of a New Parallel Polymer Flooding Simulator for Conventional and Naturally Fractured Reservoirs
Liu, Hui (University of Calgary) | Chen, Zhangxin (University of Calgary) | Shen, Lihua (University of Calgary) | Zhong, He (University of Calgary) | Liu, Huaqing (AMSS, Chinese Academy of Sciences) | Yang, Bo (University of Calgary) | Ji, Dongqi (University of Calgary) | Zhu, Zhouyuan (China University of Petroleum) | Zhan, Jie (Xi'an Shiyou University)
Abstract This paper deals with the development of our parallel reservoir simulator that is designed for giant reservoir models. It considers oil, water and polymer, and a reservoir can be a conventional reservoir without fractures or a naturally fractured reservoir. For polymer flooding, the simulator can model polymer retention, adsorption, an aqueous phase permeability reduction and viscosity increase, and an inaccessible pore volume. Here fractures are modeled by the dual porosity and dual permeability method. The finite difference (volume) method is applied to discretize the model, upstream techniques are employed to deal with rock-fluid properties, and the fully implicit method in time is applied. The linear systems from the Newton method are ill-conditioned and a scalable CPR-type preconditioner is employed to accelerate the solution of these linear systems. The computed results are compared with those from commercial simulators, and they match very well. The scalability of the simulator is good.