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56th U.S. rock Mechanics/Geomechanics Symposium

作者： Li, Xingbao Ban, Fansheng Zhu, Yujie Luo, Jiangwei Chen, Shaoyun Jin, Sheng Che, Zhenhua dong, Jingnan The Second Gas Production Plant of Petro China Changqing Oilfield Company Yulin China CNPC Engineering Technology R&D Company Limited Beijing China China University of Petroleum Beijing China Drilling Engineering Technology Research Institute Daqing Drilling and Exploration Engineering Company Daqing China Petroleum Engineering Research Institute of Dagang Oilfield Tianjin China Sinopec Zhongyuan Oilfield Engineering Service Management Center Henan China

ISBN: (纸本)9780979497575

drilling mud loss is of crucial importance in drilling. Lost circulation will extend the well construction period, cause investment losses, and even cause serious downhole accidents. In the Mizhi block of Changqing Oilfield targeted by this research, serious leakage occurred in many wellbore drilling processes, which has seriously affected the development of the block and caused economic losses. This paper focuses the mud loss during the drilling process of more than 200 wells in the Mizhi block, and counts the key loss data such as the lost horizons, the amount of lost drilling fluid, the average leak rate, and the density of the drilling fluid, and fully analyzes the possible reasons of the lost circulation. Collecting logging data, modeling geomechanics of some key wells and formations and taking cores. Finally, the geomechanical model is established. Analyzing the logging data and the specific leakage situation, the leakage mainly comes from fracture, and the leakage horizons mainly locate at the bottom of the Liujiagou Formation, the entire interval of the Shiqianfeng Formation and the top of the Shihezi Formation. Most of the mud loss sections are sand-mudstone interbeds. Geomechanical analysis shows that the rock mechanical strength of the entire interval is difficult to support the stability of the wellbore under the drilling fluid density of 1.1 grams per cubic meter, but the block loss pressure is generally between 1.1-1.2 grams per cubic meter. Collapse and leakage coexist in the wellbore. This study gives the method of drilling fluid optimization, and gives the possible reasons for the leakage from the perspective of geomechanics, which has important guiding significance for the further development of the Mizhi block. © 2022 ArMA, American rock Mechanics Association.

关键词： drilling fluids

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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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Experimental Investigation on the Crystallization Mechanism and Mitigation Strategies for Gas Injection and Brine discharge Pipelines in Salt Caverns

SSRN

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SSrN 2024年

作者： Liu, Wei Li, Qihang Wang, Yifan Ban, Fansheng Fu, Pan Li, depeng Jiang, deyi State Key Laboratory of Coal Mine Disaster Dynamics and Control Chongqing University Chongqing400044 China CNPC Engineering Technology R&D Company Limited Beijing102206 China

The present research aimed to investigate the crystallization mechanism and propose preventive measures by designing and establishing a physical simulation platform for gas injection and brine discharge. Herein, firstly, the mechanism of brine crystallization was analyzed, and the experimental parameters were determined based on similarity theory. Moreover, the impact of gas/water injection temperature, brine temperature in salt caverns, flow rate, and pipe wall roughness on the crystallizat- ion of brine was studied. Finally, measures for the prevention of crystallization and unblocking were proposed. The physical experimental results demonstrated that with every 10 °C increase in gas/water injection temperature, the crystallization rate exhibited an average reduction of 26.56%, whereas it displayed a remarkable increment of 186.16% for the brine temperature. Accordingly, by heating the injected gas/water and selecting a shallow stratum for constructing salt cavern gas storage (SCGS), crystallization can be alleviated. Besides, the crystallization rate initially increases and then decreases with flow rate, thus we recommend that the flow rate should preferably exceed 96 m3/h due to high flow rate being unfavorable for crystal adhesion and enhancing the scouring effect. On the other hand, the crystallization in the middle of brine discharge pipeline is particularly serious and requires special attention. reducing pipe wall roughness can remarkably reduce crystallization, and the development of erosion-resistive coatings is crucial. To solve these challenges, a small U-shaped pipe backflushing method for unblocking is proposed, and preliminary application suggestions are provided. Therefore, the findings of this study can offer valuable technical guidance and theoretical support for addressing the challenge of column crystallization during gas injection and brine discharge processes in practical engineering. © 2024, The Authors. All rights reserved.

关键词： Gases

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Implementing managed pressure drilling technique in drilling an offshore exploration well

Implementing managed pressure drilling technique in drilling...

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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

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

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

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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

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research on engineering technologies to develop China's complex reservoirs and their feasibility in development of marginal oilfields in South America

Research on engineering technologies to develop China's comp...

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Offshore technology Conference Brasil 2019, OTCB 2019

作者： Fu, Jin Wang, Xi Zhang, Shunyuan Liu, Bingshan Chen, Chen Yang, Guobin CNPC Engineering Technology R&D Company Ltd

ISBN: (纸本)9781613996713

Marginal Oilfields are refered to as those oilfields that are hardly developed efficiently with current technical and ecomonical conditions, characterized as high costs of development and low profit margins. However, under certain economical and technical circumstances, marginal oilfields may be transferred to be conventional ones. Since Petrobras developed the first ever offshore deep reservoir (Lula) by scale in 2006, Brazil has been conducting a progressive campaign targeting hydrocarbons buried under deep water, which contributes to discovery of Lula, Carioca, Jupiter, Buzios, Libra and other giant presalt reservoirs in Santos Basin. cnpc signed a cooperation contract with Petrobras in 2013, taking 10% of the total shares. How to efficiently develop the oilfield has been a challenging issue. Technologies of smart water injection in Shengli Oilfield have been studied, while the field development and environment (deep water) of Libra Oilfield have been analyzed, in order that the smart water injection technologies may be modified to develop the marginal oilfield more efficiently. different from conventional zonal water injection technologies, the remote wireless control water injection technologies take advantages of packers that are connected with each other via preset cables, which achieves downhole testing and water injection simultaneously. Being run via tubing, the water injection string locates a nozzle for each reservoir that is isolated by a packer. All nozzles are connected with packers via the preset cables that work as power lines for the whole string, so that downhole data such as pressures, flows and temperatures are all transferred to the processing computer on the surface. The computer program is used to convert pressure and formation signals into curves that are transferred to company via WIFI or mobile 2G/3G/4G webs, in order that technicians there may understand and learn about downhole pressures, temperatures, flows and nozzle conditions in real

关键词： Offshore oil well production

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Technical and risk assessment of underground gas storage construction and operation in China and Caspian region

Technical and risk assessment of underground gas storage con...

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SPE russian Petroleum technology Conference 2019, rPTC 2019

作者： Fu, Jin Wang, Xi Chen, Chen Chen, Haowei Zhang, Shunyuan Liu, Bingshan CNPC Engineering Technology R&D Company Ltd

ISBN: (纸本)9781613996928

Since China proposed "Belt and road" initiative in 2013, Caspian countries have become a crucial region for oil and gas cooperation. However, it has been a common technical issue to develop presalt oil and gas resevoirs in the world. Caspian region is known for the wide-spread thick salt-gypsum formations. In China some old wells that were depleted due to engineering difficulties arising from presalt formations started to be developed as underground gas storages. The crude oil price has been keeping at a low level in recent years, which made China's government put more efforts in the development of underground oil storages in depleted salt caverns. As the largest project of underground gas storages, Jintan gas storage construction project successfully made best use of depleted salt caverns. A Sonar test was applied on 4 Jintan underground salt caverns that are 900m deep and 1000m away from the surface in order to reveal their shapes. Salt and muddy salt rocks were collected in Jintan as samples to be analyzed in 3-axis pressure tests. Numerical results with finite element method (FEM) code ABAQUS were studied to approach the creep behaviors of caverns and rock pillars. The pressure arch model and the most dangerous sliding surface model were both utilized to optimize geometric parameters of the upper and lower walls of dissolved cavities. Creep happens on salt rocks under deviator stress, which has non-linear relationship with time. In the simulated gas storage process the internal pressure went up to 14.0 MPa within 3 months but dropped to 7.0MPa in the following 3 months. The above condition may last for 9.5 years in real scenarios. Surrounding rocks of caverns deformed during construction but the most obvious creep was found at their tops and bottoms. Within 10 years salt pillars between caverns are under high deviator stress, thus their creep is the most serious. Surrounding rocks become unstable as the internal pressure of caverns decreases. The creep scope of

关键词： Caves

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Study of the Bonding Strength of the First Interface of Cement Sheath Using Fbg technology

SSRN

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SSrN 2024年

作者： Cheng, Y.Q. Gou, X.L. Liu, L.M. Zhao, C.J. Wang, r. Xia, X.r. Lin, Y. Liu, S.Q. SINOPEC Research Institute of Safety Engineering Co. Ltd China CNPC Engineering Technology R&D Co. Ltd China

An important parameter in predicting the failure of cement sheath interface sealing integrity is the bonding strength of cement sheath interface. With oil and gas exploration and development focusing on deep and ultra deep layers, traditional methods for testing bonding strength cannot meet the needs of cement sheath interface sealing. Based on FBG technology, this study developed an in-situ method to quantify interface bonding strength between cement sheath, and the accuracy of the method was verified through theoretical calculations. Under different curing conditions, experimental research was conducted using this new method to determine the mechanical properties of cement sheath interface bonding. It has been shown in the experimental results that the humidity change during quantification not only affects the initial stress state of the cement sheath interface, but also affects the bonding performance of the cement sheath interface by up to 17-100%. As a result, traditional measurement methods may misestimate the sealing ability of the cement sheath interface. Additionally, increasing the curing temperature and reducing the Young's modulus are more conducive to improving the bonding characteristics of the cement sheath interface than increasing the curing time. In the case of cement slurry systems used on-site, a 48-hour waiting period is sufficient to ensure good bonding of the cement sheath interface. As a result, developing a cement slurry system that is resistant to high temperatures, has high strength and low-carbon mechanical properties can improve the sealing integrity of underground cement sheath. © 2024, The Authors. All rights reserved.

关键词： Nondestructive examination

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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...

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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

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Production-induced Stress in Nonhomogeneous Shale Gas reservoirs 55

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

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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

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