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56th U.S. rock Mechanics/Geomechanics Symposium

作者： Chen, Gang Tan, Peng Li, Jiran Jiang, Hailong Fu, Li Yang, Henglin CNPC Engineering Technology R&D Company Limited Beijing China Beijing Petroleum Machinery Co. Ltd. Beijing China Xi'an Petroleum University Xi'an China

ISBN: (纸本)9780979497575

drilling string vibration data is a high-density ancillary data and it has the advantages of low-latency and low-cost which can be acquired in real time. In this study, vibration dataset is used as signal source, and the original vibration signal is filtered by Butterworth (BHPF). vibration time-frequency characteristics are extracted into time frequency images with the application of short-time Fourier transform (STFT). This paper develops lithology classification models using new data sources based on convolutional neural network (CNN) combining with Mobilenet and resNet. This model is used for complex formation lithology including fine gravel sandstone, fine sandstone and mudstone. In order to improve the trustworthiness of decision-making results, the gradient-weighted class-activated thermal localization map is applied to interpret the results of the model. The final vertification test shows that the single-sample decision time of the model is 10ms, the test macro precision rate is 90.0%, and the macro recall rate is 89.3%. The lithology classification model is more efficiency and accessible. In conclusion, The CNN model using drill string vibration supplies a superior method of lithology classification. This study provides low-latency and low-cost lithology judgment methods to ensure safe and rapid drilling. © 2022 ArMA, American rock Mechanics Association.

关键词： Sandstone

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research progress and development direction of low-temperature drilling fluid for Antarctic region

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Petroleum Exploration and development 2022年第5期49卷 1161-1168页

作者： SUN Jinsheng WANG Zonglun LIU Jingping LYU Kaihe HUANG Xianbin ZHANG Xianfa SHAO Zihua HUANG Ning School of Petroleum Engineering China University of Petroleum(East China)Qingdao 266580China CNPC Engineering Technology R&D Company Limited Beijing 102206China

By combing the characteristics of drilling in Antarctic region, performance requirements on drilling fluid for Antarctic low temperature conditions, and research progress of low temperature drilling fluid, current problems of the drilling fluid have been sorted out, and the development direction of the drilling fluid has been pointed out. drilling in the Antarctic region mainly includes drilling in snow, ice and subglacial rock formations, and drilling in Antarctic low temperature conditions will face problems in four aspects:(1) low temperature and large temperature changes in the drilling area;(2) likely well leakage and drillstring-sticking in the snow layer, creep in the ice layer, ice chip gathering jamming in the warm ice layer, well wall collapse in the subglacial rock formations;(3) lack of infrastructure and difficulty in logistical support;(4) fragile environment and low carrying capacity. After years of development, progresses have been made on low-temperature drilling fluids for the Antarctic region. Low-temperature petroleum-based drilling fluid, ethanol/ethylene glycol-based drilling fluid, ester-based drilling fluid and silicone oil-based drilling fluid have been developed. However, these drilling fluids have problems such as insufficient low-temperature tolerance, low environmental performance and weak wellbore stability, etc. In order to meet the performance requirements of drilling fluid under low-temperature conditions in Antarctic region, the working mechanisms of low-temperature drilling fluid must be examined in depth;environment-friendly low-temperature base fluid of drilling fluid and related additives must be developed to prepare environmentally friendly low temperature drilling fluid systems;multi-functional integrated adjustment method for drilling fluid must be worked out to ensure well wall stability and improve cutting-carry capacity when drilling ice formations and ice-rock interlayers;and on-site support operation codes must be establ

关键词： Antarctic region snow and ice formation subglacial rock formation low-temperature drilling fluid drilling fluid system working mechanism regulation method construction specification

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Flow assurance in deep-water gas pipelines: Locating hydrate plugging position in a fast way

Flow assurance in deep-water gas pipelines: Locating hydrate...

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SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition 2021, APOG 2021

作者： Yu, Jing Hui, Cheng Sun, Chao Wen Zou, Zhan Ling Zhuo, Bin Lu Chang, Long Liu, Li Wang, Yuan Zhi Zhang, Bo Jian CNPC Engineering Technology R&D Company Limited College of Petroleum Engineering China U. of Petroleum China

ISBN: (纸本)9781613997833

Hydrate-associated issues are of great significance to the oil and gas sector when advancing the development of offshore reservoir. Gas hydrate is easy to form under the condition featuring depressed temperature and elevated pressure within deep-water gas pipeline. Once hydrate deposition is formed within the pipelines, the energy transmission efficiency will be greatly reduced. An accurate prediction of hydrate-obstruction-development behavior will assist flow-assurance engineers to cultivate resource-conserving and environment-friendly strategies for managing hydrate. Based on the long-distance transportation characteristics of deep-water gas pipeline, a quantitative prediction method is expected to explain the hydrate-obstruction-formation behavior in deep-water gas pipeline throughout the production of deep-water gas well. Through a deep analysis of the features of hydrate shaping and precipitation at various locations inside the system, the advised method can quantitatively foresee the dangerous position and intensity of hydrate obstruction. The time from the start of production to the dramatic change of pressure drop brought about by the deposition of hydrate attached to the pipe wall is defined as the Hydrate Plugging Alarm Window (HPAW), which provides guidance for the subsequent hydrate treatment. Case study of deep-water gas pipeline constructed in the South China Sea is performed with the advised method. The simulation outcomes show that hydrates shape and deposit along pipe wall, constructing an endlessly and inconsistently developing hydrate layer, which restricts the pipe, raises the pressure drop, and ultimately leads to obstruction. At the area of 700m-3200m away from the pipeline inlet, the hydrate layer develops all the more swiftly, which points to the region of high risk of obstruction. As the gas-flow rate increases, the period needed for the system to shape hydrate obstruction becomes less. The narrower the internal diameter of the pipeline is,

关键词： drops

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Prediction of in-situ stresses by using machine learning and intelligent optimization algorithms 57

Prediction of in-situ stresses by using machine learning and...

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57th US rock Mechanics/Geomechanics Symposium

作者： Zhang, Haoze Wu, Bisheng Nie, Yuanxun Zhang, Xi Chen, Zhaowei Xingjian College Tsinghua University Beijing100084 China State Key Laboratory of Hydroscience and Engineering Department of Hydraulic Engineering Tsinghua University Beijing100084 China Faculty of Engineering China University of Geosciences Wuhan430074 China CNPC Engineering Technology R&D Company Limited Beijing102206 China

ISBN: (纸本)9780979497582

In-situ stresses play an important role in affecting many geological processes such as hydraulic fracturing and CO2 storage, and a good understanding of the magnitude and direction of in-situ stresses is very important for deep energy exploitation. In this study, a machine learning model consisting of generative adversarial networks (GAN), particle swarm optimization (PSO) and support vector regression machine (SVrM) is proposed to predict the minimum in-situ horizontal principal stress (Shmin) from a series of existing experimental breakout data. First, the GAN and PSO are used to improve the quantity and quality of training data and to optimize the hyperparameters of the SVrM. Second, the enhanced training data are used to train the SVrM that predicts the Shmin based on the wellbore breakout geometries. In order to examine the reliability of this technique, the Shmin predicted from the proposed model is compared against the experimental data and it is found that the proposed model has a high accuracy with an average relative error of less than 10%. In addition, the proposed model requires only a few seconds to run on a laptop computer, thus providing a useful tool for accurate and efficient prediction of the Shmin. © 2023 57th US rock Mechanics/Geomechanics Symposium. All rights reserved.

关键词： Generative adversarial networks

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Experimental and Numerical Study on Transient Heat and Mass Transfer of Cryogenic Fluid in Wellbore during Cryogenic Fracturing 55

Experimental and Numerical Study on Transient Heat and Mass ...

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55th U.S. rock Mechanics / Geomechanics Symposium 2021

作者： Zhang, Hongyuan Zou, Lingzhan Zhuo, Lubin Bi, Wenxin Li, Bing Yu, Jing Huang, Zhongwei CNPC Engineering Technology R&D Company Limited Beijing China China University of Petroleum Beijing China

ISBN: (纸本)9781713839125

Cryogenic nitrogen is a promising hydraulic fracturing fluid with high cracking efficiency for tight formation reservoir. Predicting the temperature field in wellbore accurately is of great importance for the feasibility evaluation and parameters design of cryogenic fracturing. A laboratory experiment is conducted to investigate the heat transfer intensity of liquid nitrogen (LN2) in a circular tube under conditions similar to fracturing. A prediction model of heat transfer coefficient for LN2 is derived. A transient numerical model is developed to simulate the fluid flow and thermal behaviors of liquid nitrogen in the tubing. The transient heat and mass transfer characteristics of liquid nitrogen in tubing during cryogenic fracturing is simulated. The downhole fluid temperature is calculated and the temperature distributions in the fracturing string and annulus are obtained as a function of time. The typical temperature curve for downhole fluid is presented as well. The results showed that the co-injection fracturing pattern adopted in filed for cryogenic fracturing has inherent shortcomings. It can’t transport LN2 effectively to well bottom. High pressure in annulus improves the heat transfer between annulus fluid and fracturing string, which result in a dramatic decrease on the casing temperature, and would induce a low temperature damage to cement sheath. © 2021 ArMA, American rock Mechanics Association.

关键词： Flow of fluids

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Study on the loss control performance of smart adhesive lost circulation materials with ethylene vinyl acetate copolymer (EVA) 2

Study on the loss control performance of smart adhesive lost...

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2nd International Conference on Advanced Materials and Intelligent Manufacturing, ICAMIM 2021

作者： Lei, Shaofei Bai, Yingrui Sun, Jinsheng Lv, Kaihe Zhang, Shupei Qiu, Jiaxian Shandong Qingdao266580 China CNPC Engineering Technology R&D Company Limited Beijing102206 China

The conventional lost circulation materials (LCMs) particles of seal in the formation are in linear contact. Therefore, there is no cohesive force interaction, which is susceptible to pressure fluctuations, resulting in lost circulation and control failure. In response to these problems, this paper tested the high-temperature adhesion properties of EVA in the viscous flow transition zone through high-temperature adhesion experiments;then a smart adhesive LCMs is prepared using thermoplastic EVA resin with conventional LCMs;finally, through the high-temperature and high-pressure plugging experiment, the system's performance for sealing fractures was tested. The experiment results show that the smart adhesive LCMs have good plugging performance and can bond LCMs in the fracture to form a high-strength sealing with a pressure-bearing capacity of up to 9.3MPa. © 2021 Institute of Physics Publishing. All rights reserved.

关键词： Adhesives

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Efficient drilling technology of Horizontal Wells in the duverney Block in Canada

Efficient Drilling Technology of Horizontal Wells in the Duv...

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2021 Abu dhabi International Petroleum Exhibition and Conference, AdIP 2021

作者： Han, Haochen Yang, Guobin Zhang, Guobin Chen, Jia Chen, Peter Fu, Jin Wang, Siqi CNPC Engineering and Technology R&D Company CNPC Materials Procurement Center CNPC GreatWall Drilling Company Ltd.

ISBN: (纸本)9781613998342

recent years, both exploration and development have made considerable progress in the duverney block shale gas in Canada. However, technical problems exposed in horizontal drilling engineering need to be optimized: 1) Loss is common in shallow formations;2) High downhole friction torque, low rOP and drilling cuttings accumulation in long horizontal well section;3) Borehole instability leads to hanger or packer failure;4) drill bits and PdM have short servicing life and low efficiency. Optimization comes from three aspects: (1) Based on previous drilling experience and latest formation condition and development requirement, we design a new well profile for the block taking into drilling safety and further development account;(2) Optimize strong inhibitive, easy-maintenance and high cutting-carrying capacity OBM to ensure the safety requirements in the ultra-long open hole section;(3) BHA and parameters optimization. Optimize drill bit with high-abrasiveness and axial efficiency according to logging data, drillability and UCS. Upgrade conventional PdM into high-performance PdM with even-wall thickness. By means of simulation and calculation, drilling parameters suitable for duverney block has been optimized. Based on the optimization above, a stable and efficient well profile has been improved solving hanger failure on-site efficiently and complete with composite casing design (4-1/2 inch plus 5 inch) in reservoir section;a 90/10 oil-water ratio OBM has been optimized and applied onsite;Combined with high performance PdC bit and even-wall PdM as well as optimized drilling parameters, higher rOP and longer horizontal section have been achieved. The optimization has made successful field application results:(1) Completion depth has been deepened gradually, from 18,080 ft in 2013 to 23,208 ft at present, with an increase of 28.3%;(2) Horizontal section length has been increasing dramatically, from 6,190 ft in 2013 to 10,301 ft at present, with an increase of 66.4%;(3) Th

关键词： Horizontal wells

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Slot recovery Based on the 3d dubins Curve Method

Slot Recovery Based on the 3D Dubins Curve Method

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2025 SPE/IAdC International drilling Conference and Exhibition, dC 2025

作者： Liu, Haoge Aadnøy, Bernt Sigve Gjersvik, Tor Berge Kaarstad, Eirik CNPC R&D DIFC Company Limited Department of Geoscience and Petroleum Norwegian University of Science and Technology Trondheim Norway Department of Geoscience and Petroleum Norwegian University of Science and Technology Trondheim Norway Department of Energy and Petroleum Technology University of Stavanger Stavanger Norway Three60 Energy Norway Bjørn Schmidt Krossnes Vår Energi AS Norway

ISBN: (纸本)9781959025641

This paper introduces the application of the 3d dubins curve method for sidetrack trajectory design in slot recovery. With the constraints and the objective given, the method can quickly determine the optimal sidetrack kickoff point (KOP) location and generate the optimal sidetrack trajectory in just seconds. robustness and efficiency of the method are demonstrated in the case studies with both synthetic data and real field data with various constraints such as location limits, angle limits and anticollision. The case studies also demonstrate how different constraints or objectives affect optimal sidetrack trajectory. Compared to the conventional sidetrack design process when complex constraints are involved, our method can be a game changer as it only cost seconds to investigate the objective subjected to the target and various constraints information. Copyright 2025, SPE/IAdC International drilling Conference and Exhibition.

关键词： Trajectories

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damage character and fracture propagation study of Longmaxi shale in southern Sichuan Basin during hydraulic fracturing 56

Damage character and fracture propagation study of Longmaxi ...

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56th U.S. rock Mechanics/Geomechanics Symposium

作者： Fu, Li Yang, Henglin Xi, Yunlong Chen, Gang Zhang, Guangqing Lv, Yanjun CNPC Engineering Technology R&D Company Limited Beijing China China Petroleum Technical Service Corporation Limited Beijing China State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum Beijing China

ISBN: (纸本)9780979497575

Longmaxi S1l11 layer is main shale gas reservoir formation in southern Sichuan Basin, the difference of sublayer post-fracture response is significant. In this paper, we make triaxial tests with Longmaxi shale samples from southern Sichuan Basin layers to study damage character during hydraulic fracturing. Cohesive unit numerical simulation method is used to study the characteristics of hydraulic fracture (HF) propagation considering shale damage. The results show that in Longmaxi shale compression damage is divided into three stages: compaction, linear damage and rock failure. reservoir shale damage due to HF concentrated in the linear damage stage. The degree of S1l13, S1l14 shale damage is greater than that of S1l11, S1l12 shale with the same strain. Fracture propagate straight into S1l12 layer after S1Ⅰ11 layer fracture initiation, most fractures propagate into S1Ⅰ11 layer, and few fractures propagate into S1l13 layer after S1l12 layer fracture initiation, which is the similar HF in S1l13 layer. The fracture propagation of S1l11 and S1l12 layers is highly sensitive to the liquid injection displacement. With the increase of liquid injection displacement, the total length of the fracture increases significantly and the number of damage and failure units increases significantly. during HF propagation, more plane bedding and natural weak surfaces can be better connected and opened to form more branch fractures;The fracture propagations of S1l13 and S1l14 sublayers are highly sensitive to the liquid injection displacement. With the increase of liquid injection displacement, the total length of fractures and the number of damage and failure units are significantly reduced. during the fracture propagation of S1l13 and S1l14 sublayers, the fracture shape is relatively straight, and only a small amount of plane bedding and natural weak surfaces in the formation are connected and opened, forming a small number of inconspicuous branch fractures. © 2022 ArMA, American rock

关键词： Fracture

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Anomalous Behavior detection for Cloud Infrastructures via Transformer-represented Prior Knowledge

Anomalous Behavior Detection for Cloud Infrastructures via T...

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IEEE International Conference on Smart Cloud (SmartCloud)

作者： Fei Zhao Mian Chen Bo Gao Yi Cui reyu Gao Yan ding College of Petroleum Engineering China University of Petroleum Beijing China CNPC Engineering Technology R&D Company Limited Beijing China

With the rapid progression and increasing industrial relevance of cloud computing, the stability of cloud systems has become increasingly critical as they are handling a vast number of requests. To ensure this stability, the operational status of cloud servers, indicated by key performance indicators such as CPU load, network bandwidth, memory allocation, and disk 1/0 operations, must be continuously monitored. Any changes in these metrics could signify potential system malfunctions like network intrusion or hardware faults due to user activities. However, given the cyclical nature of the utilization metrics, which often exhibit, minute, hour, or daily patterns, merely setting thresholds may not effectively detect these anomalous behaviors. To address this, our research capitalizes on the advantages of the Transformer model, incorporating cyclical prior knowledge to extract these periodic patterns from the metrics, thereby enhancing the detection efficacy. Experimental results show that our proposed approach outperforms the Transformer model, improving the anomalous detection accuracy by 1.7 %, with the comprehensive evaluation metric (Fl score) surpassing 0.88.

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