检索结果-内蒙古大学图书馆

Optimization design of gas injection and brine discharge process parameters in salt cavern gas storage

International Journal of Thermofluids 2025年 27卷

作者： Kang, Yi Yuan, Guangjie Guan, Yueyang Fu, Pan Yuan, Yuan Tian, Shouceng CNPC Engineering Technology R&D Company Limited Beijing China College of Petroleum Engineering China University of Petroleum Beijing China China State Key Laboratory of Oil and Gas Resources and Exploration Beijing China SouthWest Petroleum University Sichuan China

The gas injection and brine discharge technology, as a key technique in salt cavern construction, is crucial for effectively removing brine from the cavern to optimize storage capacity. However, during the later stage of gas injection and brine discharge, the presence of insoluble particles in the salt rock formation poses a risk of clogging the brine discharge pipe as the pipe extends deeper into the cavern to maximize brine removal. To address this, numerical simulations using Fluent software were conducted, employing the enhanced realizable k-epsilon turbulent model and Eulerian multiphase flow model to analyze the transport behavior of gas, liquid, and solid phases in the salt cavern, as well as the gas injection and brine discharge strategies. By integrating numerical simulations with orthogonal experimental methods, the influence of gas injection pressure and brine discharge pipe diameter on the gas injection and brine discharge process was investigated. The results indicate that, under higher gas injection pressures, particularly at 14 MPa, the risk of brine discharge pipe clogging due to sediment deposition at the pipe inlet is reduced, with lower sediment mound heights observed. Additionally, smaller brine discharge pipe diameters, such as 114.3 mm, result in decreased sediment mound heights and reduced risk of pipe clogging. These findings provide theoretical insights and technical guidance for practical applications and construction practices in the field. © 2025

关键词： Caves

来源：评论

学校读者我要写书评

暂无评论

Integrated Well Network design Mode for CO2 EOr and Storage and its Application in L reservoir

Integrated Well Network Design Mode for CO2 EOR and Storage ...

引用

2025 International Petroleum technology Conference, IPTC 2025

作者： Wu, Zangyuan Tang, Yongliang Lian, Liming Zhou, daiyu Zhao, Haitao Shao, Guangqiang Feng, Qihong Zhou, Wei Li, Hong Bian, Wanjiang Zhang, Liang du, Hongbao Luo, Min Huang, Xingning Tarim Oilfield Company PetroChina Xinjiang Korla China R&D Center for Ultra-Deep Complex Reservoir Exploration and Development CNPC Xinjiang Korla China School of Petroleum Engineering China University of Petroleum East China Qingdao China Research Institute of Petroleum E&D Petrochina CNPC Beijing China Chengdu CK Energy Technology Co. Ltd. Sichuan Chengdu China

ISBN: (纸本)9781959025436

This paper addresses the challenge of difficulty in adjusting late-stage production in water-flooded reservoirs and proposes an integrated well network design mode for CO2 enhanced oil recovery (EOr) and storage. The well network is designed according to the full life cycle of carbon capture, utilization, and storage (CCUS), meeting the requirements of both CO2 EOr and storage phases. It extends the implementation time of CO2 EOr schemes to enhance oil recovery while ensuring effective CO2 storage, aligning with the overall strategy of global green and low-carbon development. The overall approach involves the use of a three-dimensional CO2 flooding injection and recovery well network, with progressive development in the vertical stratigraphic layers to maximize the utilization of existing old wells. The stratigraphic reconstruction involves the CO2 flooding injection and recovery well network, ensuring that new gas injection wells meet the requirements for CO2 injection processes and production rates, while also serving as replacements for gas injection in other stratigraphic layers. Production wells make use of the original old wells, and well completion methods are adjusted to achieve the development of replacement layers. The "top injection, middle production, bottom support" three-stage development method is designed to fully utilize the high points of reservoir microstructures and bottom water energy. Finally, well network optimization is achieved through streamline tracking simulation methods. The proposed technology has been applied in the CO2 enhanced oil recovery plan for the L reservoir. Initially focusing on CO2 flooding for oil recovery and shifting to CO2 storage later, it is projected to achieve a cumulative CO2 injection of tens of millions of tons over 46 years (including 40% recycled injection), with a displacement factor reaching 1.57PV. After deducting the recycled carbon amount, the cumulative carbon storage exceeds 6 million tons, affecting a vo

关键词： Crude oil

来源：评论

学校读者我要写书评

暂无评论

A novel characterization and evaluation method of flow field and its application

A novel characterization and evaluation method of flow field...

引用

Abu dhabi International Petroleum Exhibition and Conference 2020, AdIP 2020

作者： Qiao, Yan Yang, Xiangtong Zhang, Yang Wang, Yonghong Hou, Tengfei Huang, Bo Shang, Litao Li, Huili CNPC Engineering Technology R&D Company Limited

ISBN: (纸本)9781613997345

At present, most of the oil fields in eastern China have entered the stage of high water cut development, with a comprehensive water cut of over 90% and an oil recovery of less than 30%. To improve oil recovery, the flow field must be described qualitatively and quantitatively, so as to provide a basis for the formulation of measures. This paper proposes two categories of indicators: one is a guideline for developing measures, including streamline bundle properties, and the other is an indicator for evaluating the effects of measures, remaining oil dispersion (rOd) and dynamic heterogeneity included. Through numerical simulation methods, the regularity research and adaptive evaluation of each flow field characterization indicator are carried out. Finally, according to the streamline bundle properties of block E, the liquid rate of injection and production wells were optimized, and the effectiveness of the optimization was evaluated. The study found that under the condition of fixed well pattern, the streamline bundle flow (SF) between wells is relatively stable, and the change in streamline bundle potential (SP) and streamline bundle oil cut (SOC) tends to decrease with time. The typical curve of rOd generally includes four stages, and the effectiveness of measures is judged by the trend of rOd. For dynamic heterogeneity, the change curve generally includes unstable stage and stable stage. The value of the stable stage value can reflect the heterogeneity of the flow field. The larger the value, the stronger the heterogeneity of the flow field. According to the streamline bundle properties, three liquid rate optimization strategies, which are streamline bundle flow method (SFM), streamline bundle potential method (SPM), and streamline bundle oil cut method (SOM), are proposed, and the effectiveness of the measures is evaluated using rOd and dynamic heterogeneity. After liquid rate optimization, the rOd of the reservoir in Block E increased and decreased later, the Lo

关键词： Flow fields

来源：评论

学校读者我要写书评

暂无评论

Implementing managed pressure drilling technique in drilling an offshore exploration well

Implementing managed pressure drilling technique in drilling...

引用

Offshore technology Conference Asia 2020, OTCA 2020

作者： Cai, Xiao Guo, Qingfeng Zhao, Qing CNPC Engineering Technology R&D Company Limited

ISBN: (纸本)9781613996812

The managed pressure drilling technique has been widely applied in land to solve different technical and well control issues as well as ensuring the safety of field personnel. Offshore exploration drilling is one of the most challenging operations due to its nature of drilling hazards and facing environment. There is a great need of applying managed pressure technique in offshore drilling. A new MPd equipment is developed, which is named as pressure control drilling system (PCdS), and performs its first application in offshore drilling to reach its further potential. The PCdS is applied in an exploration well located in the gulf of Bohai to perform a near-balanced drilling operation for the purpose of reducing the density of drilling fluid. It utilizes the microflux control technique to precisely monitor the wellbore condition and detect the overflow and loss of circulation in time. The technique of constant bottom hole pressure is used by the PCdS to maintain the bottom hole pressure constant and minimize the fluctuations of bottom hole pressure during making connections and round trip, enhancing the drilling performance. The equivalent circulating density of 1.08-1.09 g/cm3 is obtained by the proposed PCdS using the solid-free drilling fluid with a density of 1.03g/cm3. While nearby wells use the drilling fluid with the density of 1.15-1.20 g/cm3 at the same Stratum. Cooperated with the drilling fluid of lower density, utilization of the proposed pressure control drilling system significantly avoids the formation damage. The chip hold-down effect is minimized by the proposed PCdS to increase the rOP. The average rOP of nearby wells is 4.02 m/h. While the average rOP of the well using the proposed PCdS is 7.23 m/h, indicating the increase of 80 percent. With the assistance of the proposed PCdS, the drilling team set a single bit footage record of 312.88 m and daily footage record of 163 m, which demonstrates a great improvement of operation efficiency. No drilling

关键词： drilling fluids

来源：评论

学校读者我要写书评

暂无评论

Copolymer intercalated hydrotalcite sustained release-type fluid loss additive for water-based drilling fluid: Synthesis, characterization, and performance evaluation

引用

Colloids and Surfaces A: Physicochemical and engineering Aspects 2023年第1期669卷

作者： Li, Pengpeng Liu, Ming Feng, Jie Hui, Baotong Hu, Miaomiao Guo, Jintang School of Chemical Engineering and Technology Tianjin University Tianjin300350 China CNPC Engineering Technology R&D Company Limited Beijing102206 China Zhejiang Shaoxing Institute Tianjin University Zhejiang312300 China

The polyanionic copolymer fluid loss additive (PSAdM) intercalated hydrotalcite sustained release-type fluid loss additive (PSAdM–LdH) was fabricated through in situ intercalation polymerization to alleviate the deterioration of filtration and rheological properties of water-based drilling fluid (WBdF) under extreme geological conditions (e.g., high-temperature and alt-gypsum formations). The PSAdM between layers of LdH can be slowly exchanged by anions in WBdF to give full play to its original efficiency. results of FT–Ir, TG and Xrd demonstrate that the PSAdM successfully intercalated the layers of LdH, and the intercalation rate was approximately 14 wt%. In addition, results of filtration measurements of WBdF demonstrate that the PSAdM–LdH significantly decreased the filtration volume, even though after thermal rolling at 200 °C the filtration volume of brine drilling fluids contained 2 wt% PSAdM–LdH was reduced by approximately 50% compared with PSAdM. Moreover, the introduction of PSAdM–LdH enhanced the thixotropy of WBdF because of forming a dynamic reversible gel structure by copolymer and charged clay colloidal particles (LdH and bentonite), which is conducive to giving full play to the water power of the bit, and carrying and suspending the drill cutting well in the annulus. Therefore, PSAdM–LdH has broad application prospects for exploring and developing super-deep reservoirs. © 2023 Elsevier B.V.

关键词： drilling fluids

来源：评论

学校读者我要写书评

暂无评论

research on radial drilling technology of high efficient rock breaking under high temperature deep well conditions

Research on radial drilling technology of high efficient roc...

引用

Abu dhabi International Petroleum Exhibition and Conference 2020, AdIP 2020

作者： Chen, Zhi Zhu, Feng Hu, Qiangfa Zhang, Youjun Lv, Weiping CNPC Engineering Technology R&D Company Limited

ISBN: (纸本)9781613997345

The current radial well operation technology can not adapt to high temperature, and the long tripping period and low drilling efficiency in deep well *** to the characteristics of abrasive jet, a new radial drilling method is proposed in this paper, in which the abrasive jet is conveyed to the underground by CT (coiled tubing), the casing is sidetracked first, and then the formation is drilled. The working procedure is that using the CT to run the positioning and guiding tool in hole first, and then using the CT to run a steel tube in hole. When the steel tube reaches the deflector, it makes a radial turn, and the ground equipment transfers the abrasive drilling fluid to down hole through the CT. during the operation, the casing sidetracking is completed with drilling fluid with high abrasive concentration, then the abrasive concentration is reduced, and the steel tube enters the formation to complete the radial drilling. Practice has proved that when the well temperature exceeds 100°C the jet hose is easy to be damaged under high temperature and high pressure environment, resulting in leakage of drilling fluid and unable to complete the operation normally. It is necessary to select a suitable temperature-resistant jet hose. Practice has proved that when the well depth is more than 4000 meters, the pressure loss along the system increases and the jet water power from the nozzle decreases. For hard formation, the water jet is not enough for rock breaking drilling in the formation. The results show that under the same water power condition, abrasive jet has stronger ability to break rock and penetrate hard stratum than water jet because it contains solid particles with higher hardness and density. At the same time, the abrasive water jet with suitable abrasive concentration and water power can be used for casing sidetracking. The casing sidetracking and formation drilling are combined to simplify the process. Experiments show that the types of abrasiv

关键词： rocks

来源：评论

学校读者我要写书评

暂无评论

Production-induced Stress in Nonhomogeneous Shale Gas reservoirs 55

Production-induced Stress in Nonhomogeneous Shale Gas Reserv...

引用

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

作者： dong, J.N. Jin, G.T. Liu, T.E. Qiu, K.X. Wei, S.M. CNPC Engineering Technology R&D Company Limited Beijing102206 China Peking University Beijing102249 China Beijing102249 China

ISBN: (纸本)9781713839125

The mechanical properties of shale are greatly influenced by the fraction of organic matter in the shale. However, the effects of organic matter distribution on stress interference have not been well considered. Since parent- wells target "sweet spots,"infill wells (child wells) generally target an area with a lower porosity and permeability, which correspond to a higher organic matter content. This study investigates the influence of organic matter distribution on changes in horizontal principal stress. For the scenario with nonuniformly distributed organic matter, the infill well region is set as the organic-rich region. A fully coupled numerical model considering the whole flow spectrum of shale gas and the shrinkage of organic matter is built. Some conclusions are drawn from the simulation results;for example, the shrinkage of organic matter enlarges the alteration angle of the maximum horizontal principal stress orientation and the magnitude of the minimum horizontal principal stress. However, the effect of organic matter on the alteration angle of the maximum horizontal principal stress is basically negligible after 3 years of production. The magnitude and orientation of the horizontal principal stresses experienced more modest changes in the infill well region with nonuniformly distributed organic matter than in that with uniformly distributed organic matter. Copyright © 2021 ArMA, American rock Mechanics Association.

关键词： Shale gas

来源：评论

学校读者我要写书评

暂无评论

Simulation Experiment of Sediment Sealing in Old Well of Underground Gas Storage (Ugs)

SSRN

引用

SSrN 2024年

作者： Zhang, Yuda dong, Jingnan Liu, Tianen Guan, Yueyang Ban, Fansheng Yuan, Guangjie Research Institute of Petroleum Exploration & Development PetroChina Beijing100083 China CNPC Engineering Technology R&D Company Limited Beijing102206 China National Engineering Laboratory of Petroleum Drilling Technology Beijing102206 China National Elite Institute of Engineering CNPC Beijing100096 China

UGS is the key place to ensure the stable supply of natural gas, and the plugging effect of old wells will be seriously affected due to its characteristics of strong and alternating injection and withdrawal. In order to study the plugging of old wells with fishing and buried by sediment, a full-scale wellbore sediment sealing simulation experiment and a small-scale core permeability experiment were designed. Considering the factors such as sediment composition, compaction degree and metal surface roughness, the compaction law of fillers and the change law of permeability with rock cuttings content under different top hydraulic conditions were analyzed. The experimental results show that there are two kinds of sealing failure in old wells. One is gas breakthrough, the breakthrough pressure difference is 1.3-2.7 MPa, the breakthrough time is about 30 s, and the dominant channel is the interface between sediment and casing and fishing. The other is gas leakage. The permeability range of the sediment is 0.0024-0.031 d, and the reservoir gas flows along the pore channel of the sediment. This study simulates the sediment plugging old wells in the range of gas storage site, and provides reference for the sealing failure process and mechanism of old wells. © 2024, The Authors. All rights reserved.

关键词： Sediments

来源：评论

学校读者我要写书评

暂无评论

Simulation Experiment of Sediment Sealing in Old Well of Underground Gas Storage (Ugs)

SSRN

引用

SSrN 2024年

作者： Zhang, Yuda Yuan, Guangjie dong, Jingnan Liu, Tianen Guan, Yueyang Ban, Fansheng Research Institute of Petroleum Exploration & Development PetroChina Beijing100083 China CNPC Engineering Technology R&D Company Limited Beijing102206 China National Engineering Laboratory of Petroleum Drilling Technology Beijing102206 China National Elite Institute of Engineering CNPC Beijing100096 China

关键词： Sediments

来源：评论

学校读者我要写书评

暂无评论

Flow numerical simulation of tubing or casing leakage in gas well

Flow numerical simulation of tubing or casing leakage in gas...

引用

Abu dhabi International Petroleum Exhibition and Conference 2020, AdIP 2020

作者： Zhang, Hong Yuan, Guangjie Li, Guotao Li, Jingcui Wan, Jifang Fu, Pan CNPC Engineering Technology R&D Company Limited Research Institute of Petroleum Exploration and Development CNPC Engineering Technology R&D Company Limited

ISBN: (纸本)9781613997345

Tubing or casing leakage of HTHP gas wells and underground gas storage wells affects wellbore integrity adversely. The wellbore micro-leakage detection technology can detect tiny fluid leakage in time and is of great significance to avoid malignant gas leakage accident. The theoretical basis of wellbore microleakage detection technology is characterizing the leakage flow field. To reveal the flow characteristics of gas leakage due to tubing and casing cracks and perforations, a CFd model of gas aperture leak has been established and flow field numerical simulation of high-speed and high-pressure gas outflow through aperture was conducted. The standard k-e turbulence model was used to calculate and analyze the pressure and velocity distribution of the steady flow field. In addition, a time step was set on the steady-state model and the Scale-Adaptive Simulation (SAS) model was adopted to simulate the transient flow field with the initial conditions of the steady-state simulation results. The effects of the shape and size of the leakage hole, the pressure inside the pipe, and the medium in the outer annular space on the flow field were analyzed. The results show that obvious turbulence disturbance appears near the inlet of the leakage hole and supersonic under-expansion jet forms near the outlet of the leakage hole under the gas well working conditions, creating the expansion wave and shock wave. The flow velocity of gas leakage through the circular hole is the highest, while that of the slot hole is the lowest under the same conditions. The larger the leakage aperture is, the greater the pressure difference between inside and outside of the pipe is, and the more drastic variation of gas velocity in the leakage hole. The method and results provide theoretical guidance for the microleakage detection technology of gas well wellbore. © 2020, Society of Petroleum Engineers

关键词： Flow fields

来源：评论

学校读者我要写书评

暂无评论

建议与咨询留下您的常用邮箱和电话号码，以便我们向您反馈解决方案和替代方法

时间限定

文献类型

馆藏选择

核心期刊

语言

文献类型

帮助

文字说明：

检索规则说明：

检索范例：

分类表

所选分类

限定检索结果

文献类型

馆藏范围

日期分布

学科分类号

主题

机构

作者

语言

请选择保存的检索档案：

请选择收藏分类：

通借通还

建议与咨询 留下您的常用邮箱和电话号码，以便我们向您反馈解决方案和替代方法

时间限定

文献类型

馆藏选择

核心期刊

语言

文献类型

帮助

文字说明：

检索规则说明：

检索范例：

分类表

所选分类

限定检索结果

文献类型

馆藏范围

日期分布

学科分类号

主题

机构

作者

语言

请选择保存的检索档案： 新增检索档案 确定 取消

请选择收藏分类： 新增自定义分类 确定 取消

通借通还

建议与咨询留下您的常用邮箱和电话号码，以便我们向您反馈解决方案和替代方法

请选择保存的检索档案：

请选择收藏分类：