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

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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High temperature resistant Portland cement slurry and production method thereof

High temperature resistant Portland cement slurry and produc...

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作者： Hua Zhang Jianzhou Jin Shuoqiong Liu Fengzhong Qi Yongjin Yu Ming Xu Jinping Yuan Zhiwei ding Chongfeng Zhou Chi Zhang Zishuai Liu Yusi Feng Yuchao Guo

标准号: US11618844(B2)

The invention provides a high temperature resistant Portland cement slurry and a production method thereof. The high temperature resistant Portland cement slurry comprises the following components by weight: 100 parts of an oil well Portland cement, 60-85 parts of a high temperature reinforcing material, 68-80 parts of fresh water, 1-200 parts of a density adjuster, 0.1-1.5 parts of a suspension stabilizer, 0.8-1.5 parts of a dispersant, 3-4 parts of a fluid loss agent, 0-3 parts of a retarder and 0.2-0.8 part of a defoamer. The high temperature resistant Portland cement slurry has a good sedimentation stability at normal temperature, and develops strength rapidly at a low temperature. The compressive strength is up to 40 MPa or more at a high temperature of 350° C., and the long-term high-temperature compressive strength develops stably without degradation. Therefore, it can meet the requirements for field application in heavy oil thermal recovery wells, reaching the level of Grade G Portland cement for cementing oil and gas wells.

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Improvement of rheological and filtration properties of water-based drilling fluids using bentonite-hydrothermal carbon nanocomposites under the ultra-high temperature and high pressure conditions

Improvement of rheological and filtration properties of wate...

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

作者： Zhong, Hanyi Guan, Ying Qiu, Zhengsong Feng, Jie Liu, Wenlei Wan, Yuan Zhang, Yubin China University of Petroleum East China China CNPC Engineering Technology R&D Company Limited

ISBN: (纸本)9781613997833

With the depletion of the conventional shallow oil/gas reservoirs and the increasing demand for oil and gas, deep drilling become more and more essential to extract the oil/gas from deep formations. However, deep drilling faces many complex challenges. One of the complexities is the degradation of polymers and flocculation of bentonite particles, leading to hardly control the rheological and filtration properties of water-based drilling fluids, especially under ultra-high temperature and high pressure (HTHP) conditions. Therefore, an experimental investigation is performed to study how bentonite-hydrothermal carbon nanocomposites will influence the rheological and filtration properties of water-based drilling fluids under ultra-HTHP conditions. Bentonite-hydrothermal carbon nanocomposites are proposed as non-polymer additives to solve the ultra-HTHP challenge in water-based drilling fluid. The nanocomposites are synthesized by facile hydrothermal reaction, in which biomass starch and sodium bentonite are used as the precursor and template, respectively. In this study, the effect of the nanocomposites on the rheology and filtration properties of water-based drilling fluid are investigated before and after hot rolling at 220 °C and 240 °C. The structure characterization indicates that carbon nanospheres can successfully deposit on the bentonite surface after hydrothermal reaction and finally form as nanocomposites. The elemental carbon content, zeta potential and particle size distribution of the nanocomposites could be adjusted according to the reaction conditions. After thermal aging at 220 °C and 240 °C, addition of nanocomposites can improve the rheological properties significantly where a stable and minor change of rheological properties is observed, which is desirable for ultra-HTHP drilling. regarding filtration control, after adding 1.0 wt% nanocomposite materials, the filtration loss is reduced by 41% and 44% respectively after aging at 220 °C and 240 °C, whi

关键词： Nanocomposites

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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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Coupling Prediction Model and Influencing Factors Analysis of Injection and Production Gas Flow rate and Wellhead Pressure for Compressed Air Energy Storage in Salt Cavern

SSRN

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SSrN 2024年

作者： ren, Qianyu Wang, Jiangshuai Fu, Pan School of Energy School of Oil and Gas Engineering Changzhou University China CNPC Engineering Technology R&D Company Limited National Engineering Research Center for Oil & Gas Drilling and Completion Technology

In order to accurately predict the injection and production gas flow rate and wellhead pressure for compressed air energy storage in salt cavern, a coupled prediction model of injection and production gas flow rate and wellhead pressure based on gas pipe flow theory was established in this paper. And, a high-precision and high-speed iterative solution algorithm was proposed to achieve accurate and rapid prediction of injection and production gas flow rate, wellhead pressure, and total pressure loss. Furthermore, the influences of factors such as cavity connectivity, number of cavities, cavity pressure, depth of injection and production wells, number of injection and production columns, size of injection and production columns, and injection and production medium on injection and production gas flow rate, wellhead pressure, and total pressure loss were discussed. The research results indicate that: ① There are good stability, fast convergence speed, and good consistency between the predicted results and on-site measured data for the model. ② Under the condition that cavity is connected, the total injection production flow rate will be evenly distributed to each injection production well, and the wellhead pressure and total pressure loss of each injection production well are consistent. Under the condition that cavity is not connected, injection production wells with higher cavity pressure have greater injection production gas flow rate and total pressure loss. ③ With the increase in the number of chambers, the decrease in chamber pressure, the increase in injection production well depth, the increase in the number of injection production columns, and the decrease in the size of injection production columns, the single tube injection production gas flow rate decreases. However, the changes in wellhead pressure and total pressure loss are not only influenced by various factors, but also closely related to operating conditions. ④ When other conditions remain unchanged,

关键词： Compressed air

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Stability Analysis of Underground-gas-storage Salt Cavern Based on Similarity Criterion 55

Stability Analysis of Underground-gas-storage Salt Cavern Ba...

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

作者： dong, Jingnan Li, Guotao Liu, Tianen Li, Jingcui Zhang, Yingbin CNPC Engineering Technology R&D Company Limited Beijing China HydroChina-ITASCA R&D Center Hangzhou China

ISBN: (纸本)9781713839125

Underground gas storage using salt cavern is becoming popular due to the rising problem of the seasonal gas demand peaking. The salt cavern stability analysis is an indispensable part of the salt cavern design. The aim of the research is to study the stability of the two-well-horizontal caverns and establish the universal similarity criteria controlling the creep of the cavern. The WIPP-drucker model is investigated. The mechanical properties of the formation generally follow the geo data from Pingding Mountain. The creep simulation is performed over a period of 30 years under different and cycling cavern gas pressures simulating the gas demand peak over the whole year. The similarity criteria regarding salt cavern stability are established based on dimensional analysis. The dimensional relationships between surface subsidence, cavern volume reduction, in-situ stress, cavern gas pressure, steady-state creep rate, creep time and characteristic length of the cavern are founded. results show that the simulated cavern volume reduction due to creep corresponds to the measured real cavern volume change over years. The results also show that a total of 9 dimensional physical quantities control the whole creep system. There are 4 simple criteria and 2 composed criteria, which correspond to 6 scaling criterions. The numerical simulation results verify the accuracy of the scaling criterions. The study provides guidance to the salt cavern design and operation process in the term of the mechanical stability of the cavern. © 2021 ArMA, American rock Mechanics Association

关键词： Creep

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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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Sand Production Prediction of depleted-reservoir Underground Gas Storage - An experimental study 56

Sand Production Prediction of Depleted-reservoir Underground...

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56th U.S. rock Mechanics/Geomechanics Symposium

作者： Ma, Lijun dong, Jingnan Wang, Jinzhong Zhang, Yuda Li, Guotao Li, Jingcui Department of Well Engineering Supervise Changqing Oil Field Company Shaanxi China CNPC Engineering Technology R&D Company Limited Beijing China Jidong Oilfield Company PetroChina Hebei Tangshan China Research Institute of Petroleum Exploration & Development PetroChina Beijing China

ISBN: (纸本)9780979497575

depleted-reservoirs underground gas storage are playing an increasingly important role in seasonal demanding of natural gas, ensuring stable gas supply and strategic reserves. However, due to the physical properties of the reservoir, the problem of sand production in the wellbore cannot be ignored. This research is based on the high-pressure sand production experiment simulation device system. Using the in-situ core, through experiments to simulate the sand production of the high-pressure gas storage reservoir, the sand production is systematically and quantitatively studied. The experimental results show that there are two key pressures for sand production caused by the destruction of the inner wall of the wellbore, namely, the equivalent initial sand production pressure (critical confining pressure) and the strength of the thick-walled barrel (collapse pressure). After the confining pressure exceeds the equivalent initial sand production pressure, the core begins to produce sand, and the sand has a relatively smaller particle size. The sand production is found to increases linearly with the equivalent confining pressure. After the confining pressure exceeds the strength of the thick-walled barrel, the core body is damaged and a large amount of sand is produced. The sand body has a relatively large particle size. The particle size distribution indicates the increase of sand particle size during the sand production of the gas storage well. This experiment provides guidance for the operation and completion of gas storage in depleted oil reservoirs, and also provides a quantitatively experimental method for the study of wellbore sand production. © 2022 ArMA, American rock Mechanics Association.

关键词： Sand

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Study on the Fluid-Solid Coupling Seepage of the deep Tight reservoir Based on 3d digital Core Modeling

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Energy engineering 2025年第2期122卷 537-560页

作者： Haijun Yang Zhenzhong Cai Hui Zhang Chong Sun Jing Li Xiaoyu Meng Chen Liu Chengqiang Yang PetroChina Tarim Oilfield Company Korla841000China CNPC R&D Center for Ultra-Deep Complex Reservoir Exploration and Development Korla841000China National Key Laboratory of Deep Oil and Gas China University of Petroleum(East China)Qingdao266580China Structure and Shipping Department Offshore Oil Engineering(Qingdao)Co.Ltd.Qingdao266520China

deep tight reservoirs exhibit complex stress and seepage fields due to varying pore structures,thus the seepage characteristics are significant for enhancing oil *** study conducted triaxial compression and permeability tests to investigate the mechanical and seepage properties of tight sandstone.A digital core of tight sandstone was built using Computed Tomography(CT)scanning,which was divided into matrix and pore phases by a pore equivalent diameter threshold.A fluid-solid coupling model was established to investigate the seepage characteristics at *** results showed that increasing the confining pressure decreased porosity,permeability,and flow velocity,with the pore phase becoming the dominant seepage *** and large pores closed first under increasing pressure,resulted in a steep drop in ***,permeability slightly decreased under high confining pressure,which followed a first-order exponential *** velocity increased with seepage *** the damage mainly occurred in stress-concentration regions under low seepage *** behavior followed linear darcy flow,the damage emerged at seepage entrances under high pressure,which decreased rock elastic modulus and significantly increased permeability.

关键词： digital core fluid-solid coupling pore structure microscopic seepage

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A Conventional Neural Network Lithology Classification Method Based on Vibration data 56

A Conventional Neural Network Lithology Classification Metho...

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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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