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A micro-crosslinked amphoteric hydrophobic association copolymer as high temperature-and salt-resistance fluid loss reducer for water-based drilling fluids

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Petroleum Science 2024年第3期21卷 1980-1991页

作者： Jian Li Yu-Xi Ji Xiao-Xiao Ni Kai-He Lv Xian-Bin Huang Jin-Sheng Sun School of Petroleum Engineering China University of Petroleum(East China)Qingdao266580ShandongChina Key Laboratory of Unconventional Oil&Gas Development China University of Petroleum(East China)Qingdao26650ShandongChina Inspection and Testing Center of Huabei Oil Field Company PetroChinaRenqiu062552HebeiChina Drilling Fluid Research Institute CNPC Engineering Technology R&D Company LimitedBeijing102206China

during ultradeep oil and gas drilling,fluid loss reducers are highly important for water-based drilling fluids,while preparing high temperature-and salt-resistance fluid loss reducers with excellent rheology and filtration performance remains a ***,a micro-crosslinked amphoteric hydrophobic association copolymer(i.e.,dAdC)was synthesized using N,N-dimethyl acrylamide,diallyl dimethyl ammonium chloride,2-acrylamido-2-methylpropane sulfonic acid,hydrophobic monomer,and pentaerythritol triallyl ether *** to the synergistic effects of hydrogen bonds,electrostatic interaction,hydrophobic association,and micro-crosslinking,the dAdC copolymer exhibited outstanding temperature-and *** rheological experiments have shown that the dAdC copolymer had excellent shear dilution performance and a certain degree of salt-responsive viscosity-increasing *** dAdC copolymer could effectively adsorb on the surface of bentonite particles through electrostatic interaction and hydrogen bonds,which bring more negative charge to the bentonite,thus improving the hydration and dispersion of bentonite particles as well as the colloidal stability of the drilling ***,the drilling fluids constructed based on the dAdC copolymer exhibited satisfactory rheological and filtration properties(FLHTHP=12 m L)after aging at high temperatures(up to200℃)and high salinity(saturated salt)***,this work provided new insights into designing and fabricating high-performance drilling fluid treatment agents,demonstrating good potential applications in deep and ultradeep drilling engineering.

关键词： Fluid loss reducer Temperature-and salt-resistance Hydrophobic association Amphoteric Micro-crosslinking

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A Chemical Method of Achieving Uniform Stimulation Intensity Along Long Laterals in Horizontal Wells

A Chemical Method of Achieving Uniform Stimulation Intensity...

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2024 SPE Conference at Oman Petroleum and Energy Show, OPES 2024

作者： Yuan, Zebo Liu, Huifeng Xu, Ning Jin, Song Shi, Ying Chen, Zhangxin PetroChina Tarim Oilfield Company Xinjiang Korla China CNPC R&D DIFC Company Limited Dubai United Arab Emirates CNPC Oman Company Muscat Oman Department of Chemical and Petroleum Engineering University of Calgary CalgaryAB Canada

ISBN: (纸本)9781959025252

To exploit a reservoir more efficiently, horizontal wells with long laterals are being drilled in many oilfields in the world. Uniform acidizing by bullheading is a challenge in these wells because the volume of acid that enters each segment tends to be different: larger at the heel while smaller at the toe. This further causes a non-uniform production profile which advances breakthrough of water. In this paper, a method of using a temperature-sensitive viscous acid to achieve uniform stimulation profile is introduced. The acid is delicately designed so that the viscosity of it changes with temperature and the changing rate can be quantitatively controlled. As the acid flows in wellbore, the diffusion coefficient of H+ and therefore the acid-rock reaction rate gradually increases while it is being warmed by wellbore. A model describing the change of viscosity and H+ mass transfer coefficient is established and coupled with a wellbore heat transfer model. The basic of this acid is hydrochloric acid but it is mixed with a special gelatinizer. The initial viscosity of the acid ranges from 60 to 1400 mPa.s at surface, depending on the concentration of gelatinizer. Its viscosity gradually decreases to 200 mPa.s with temperature increasing to 100 ℃.The leaking off velocity decreases from 2.0×10−6 m/s to 2.0×10−7 m/s accordingly, depending on the injecting time. And the acid concentration at the wall of wellbore increase by three times when the injecting rate doubles, also depending on the wellbore temperature and pressure. The acid-rock reaction rate is faster at toe than at heel, which just compensates the differences of acid volume allocation between toe and heel due to wellbore flow friction. A model describing the correlations between the acid viscosity, diffusion coefficient of H+, the concentrations of HCl, the injection rate and the temperature is generated. This model is coupled with an acid flow and reaction model and a wellbore heat transfer model and in the end

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AdLM-LWd: Adaptive deep Learning Model for Lithology Identification from Logging- While-drilling data with Online Learning Mechanism

ADLM-LWD: Adaptive Deep Learning Model for Lithology Identif...

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New Trends in Computational Intelligence (NTCI), International Conference on

作者： Ziyun Zhao Wang Lin Lingzhi Jing Yumeng Tian Weihong Guo CNPC Engineering and Technology R&D Company Limited Beijing China

ISBN: (数字)9798331517021

ISBN: (纸本)9798331517038

Accurate lithology identification from Logging-While-drilling (LWd) data is crucial for optimizing drilling operations and enhancing reservoir characterization in the oil and gas industry. However, the lack of standardized datasets and the need for real-time adaptability in varying geological environments pose significant challenges. This study addresses these issues through three key contributions. First, a comprehensive dataset for lithology identification is constructed, combining LWd features with corresponding lithology labels, providing a valuable resource for deep learning applications in this field. Second, a novel deep learning model is proposed, integrating 2d convolution and bidirectional LSTM to effectively capture both spatial and temporal features of LWd data. The model demonstrates high stability and performance across various metrics in extensive cross-validation tests. Lastly, an Adaptive Incremental Learning Algorithm (AILA) is introduced, incorporating online learning mechanisms and dynamic adaptation strategies to enhance the model's real-time adaptability. These advancements contribute to more accurate and adaptive lithology identification systems, which potentially improve real-time decision-making in drilling operations and lead to more efficient and cost-effective exploration and production processes.

关键词： deep learning Learning systems drilling Adaptation models Accuracy Incremental learning Heuristic algorithms Geology real-time systems data models

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Study on Multi-string Wellhead Growth Prediction in High Temperature Wells and Analysis of On-Site Example 30th

Study on Multi-string Wellhead Growth Prediction in High Tem...

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30th International Conference on Computational and Experimental engineering and Sciences, ICCES 2024

作者： Wang, Hao Li, Mu Hao, Wei-Wei Zhang, Hui CNPC Engineering Technology R&D Company Limited Beijing102206 China National Engineering Research Center of Oil & Gas Drilling and Completion Technology Beijing102206 China China University of Petroleum Beijing102249 China

ISBN: (纸本)9783031687747

In high temperature wells such as thermal recovery wells or ultra-deep wells, it is prone to experiencing wellhead growth during the production process. Most current research focuses on the free extension of single casing in the uncemented section of the wellbore, but the most of their results significantly diverges from actual observations. Therefore, it is necessary to establish a method for predicting wellhead growth height considering the length of casing-cement sheath debonding and multi-string effect. In this study, the thermal debonding mechanism of casing-cement sheath was theoretically analyzed, and a calculation model for the debonding length of casing-cement sheath was obtained. Then, based on the frictional resistance of the cement sheath and the coupling effect of multiple layers of casing, a method for predicting wellhead growth height was further established. Finally, the sensitivity analysis of influencing factors of wellhead growth was carried out and a case study was conducted on an offshore well in the South China Sea. The results showed that: (1) The predicted wellhead growth height is in good agreement with the measured results, with a maximum relative error of only −5.63%, validating the effectiveness and accuracy of the wellhead growth height prediction model for on-site application. (2) The wellhead growth height is positively correlated with production speed, production time and thermal conductivity of tubing, and negatively correlated with the casing-cement bonding load. (3) The influence of production speed should be considered when installing wellheads, and cementing quality should be improved for preventing wellhead growth in actual field operations. This study can provide reference and significant implications for preventing and reducing wellhead growth issues in high temperature wells. © The Author(s), under exclusive license to Springer Nature Switzerland AG 2024.

关键词： Casing-cement debonding High temperature wells On-site example Wellbore integrity Wellhead growth

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Quantitative evaluation of controlling factors of nonuniform production in deep shale gas based on optic fiber logging technology 58

Quantitative evaluation of controlling factors of nonuniform...

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58th US rock Mechanics / Geomechanics Symposium 2024, ArMA 2024

作者： Shao, S.r. Hu, H. Yang, Z.X. Tan, P. Shale Gas Research Institute Southwest Oil & Gas Field Company Chengdu China Chongqing Gas District Southwest Oil & Gas Field Company Chongqing China CNPC Engineering Technology R&D Company Limited Beijing China

ISBN: (纸本)9798331305086

The performance of deep shale gas reservoirs is controlled by several factors, and there is a difference in gas production between fracturing stages. Thus, clarification and quantification of main controlling factors of production is indispensable. In this paper, based on the distributed optic fiber logging data of a deep shale gas well in southern Sichuan, the hierarchical fuzzy comprehensive evaluation method and analytic hierarchy process were used to determine major controlling factors, and a performance evaluation model was established. The results show that the gas production of fracturing stages calculated by above model is highly consistent with measured results. reservoir physical properties are major factors affecting gas production. The production potential of a stage with high geological quality can be improved by increasing clusters, average pumping rate, proppant injection intensity to achieve complicated fracture networks and increasing the proportion of ceramic proppant to ensure effective conductivity. Given that the contribution of stage lengths to gas production is low, for an interval with poor geological quality, stage lengths can be increased appropriately to reach a balance point of cost-effectiveness and stimulation effect. This study provides a basis for shale gas fracturing optimization and production improvement. Copyright 2024 ArMA, American rock Mechanics Association.

关键词： Quality control

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Calibration technology and Application of Mud Logging Sensors Based on Artificial Intelligence 13th

Calibration Technology and Application of Mud Logging Sensor...

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13th International Field Exploration and development Conference, IFEdC 2023

作者： Wu, Chang-Liang Zhou, Zhi-Xiong ding, Tie-Heng Xiong, Jian-Guo Gao, Yong-Liang Li, Yang Luo, Xue-Li KEMBL Petroleum Technology Co. Ltd. Beijing China CNPC Engineering Technology R&D Company Ltd. Beijing China National Engineering Research Center of Oil and Gas Drilling and Completion Technology Beijing China

ISBN: (纸本)9789819702718

Mud logging serves as the "eyes" of exploration and development, acting as a counselor for drilling safety, the center of information transmission, and holding the first-hand data on oil and gas exploration and development. With the rapid development of informatization, digitization, intelligence, and remote support systems, the demand for high-quality mud logging data has continuously risen, where sensor calibration and calibration technology serve as the foundation for ensuring accuracy and reliability. This paper proposes an artificial intelligence-based comprehensive mud logging instrument sensor calibration and calibration technology, targeting the issues of prolonged service life, low precision, and low inspection rate of traditional mud logging instruments. The technology primarily involves collecting and pre-processing sensor output data such as filtering, sampling to eliminate noise, and improve the dataset's quality. Mathematical models of sensors were constructed using machine learning or deep learning algorithms to analyze the relationship between sensor outputs and actual values, which could also compute sensor errors and uncertainties. Algorithm optimization methods such as wavelet transform and adaptive filtering were used to process and analyze sensor data for different types of sensors and environmental conditions. The adaptive control algorithm was then utilized based on the predicted model results and actual measurement results to calibrate the sensor, ultimately helping to avoid errors and uncertainty in the traditional manual calibration process. Experimental results show that this technology has higher accuracy and reliability than traditional calibration techniques while maintaining simple operation, fast speed, and cost-effectiveness. This technology improves the level of detection and evaluation technology of comprehensive mud logging instruments, Standardizes mud logging equipment management, and plays an essential role in timely discoverin

关键词： Uncertainty analysis

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Mesoporous SiO_(2)nanoparticles with low surface energy and multi-level roughness as shale wellbore stabilizers in oil-based drilling fluid

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Petroleum Science 2025年第1期22卷 384-397页

作者： Hong-Yan du Kai-He Lv Jin-Sheng Sun Mei-Chun Li Yuan Geng Xian-Bin Huang Hao-Kun Shen Muhammad Arqam Khan School of Petroleum Engineering China University of PetroleumEast ChinaQingdao266580ShandongChina Key Laboratory of Unconventional Oil&Gas Development Ministry of EducationQingdao266580ShandongChina CNPC Engineering Technology R&D Company Ltd. Beijing102206China Co-Innovation Center of Efficient Processing and Utilization of Forest Resources College of Materials Science and EngineeringNanjing Forestry UniversityNanjing210000JiangsuChina Department of Petroleum Engineering NED University of Engineering&Technology395007Pakistan

Oil-based drilling fluids possess excellent properties such as shale inhibition, cuttings suspension, and superior lubrication, making them essential in the development of unconventional oil and gas ***, wellbore instability, caused by the invasion of drilling fluids into shale formations, remains a significant challenge for the safe and efficient extraction of shale oil and gas. This work reports the preparation of mesoporous SiO2nanoparticles with low surface energy, utilized as multifunctional agents to enhance the performance of oil-based drilling fluids aimed at improving wellbore stability. The results indicate that the coating prepared from these nanoparticles exhibit excellent hydrophobicity and antifouling properties, increasing the water contact angle from 32°to 146°and oil contact angle from 24°to134.8°. Additionally, these nanoparticles exhibit exceptional chemical stability and thermal *** these nanoparticles into oil-based drilling fluids reduced the surface energy of the mud cake from 34.99 to 8.17 m J·m-2and increased the roughness of shale from 0.26 to 2.39 μm. These modifications rendered the mud cake and shale surfaces amphiphobic, effectively mitigating capillary infiltration and delaying the long-term strength degradation of shale in oil-based drilling fluids. After 28days of immersion in oil-based drilling fluid, shale cores treated with MF-SiO2exhibited a 30.5% increase in compressive strength compared to untreated cores. Additionally, these nanoparticles demonstrated the ability to penetrate and seal rock pores, reducing the API filtration volume of the drilling fluid from11.2 to 7.6 m L. This study introduces a novel approach to enhance the development of shale gas and oil resources, offering a promising strategy for wellbore stabilization in oil-based drilling fluid systems.

关键词： Fluorosilane Wettability Wellbore stability drilling engineering Self-cleaning Antifouling

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The Successful Application of MPd technology in drilling Ultra deep and Ultra-high Pressure Saltwater Formation to Mitigate drilling Hazards: A Case Study in Tarim Basin 29th

The Successful Application of MPD Technology in Drilling Ult...

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29th International Conference on Computational and Experimental engineering and Sciences, ICCES 2023

作者： Liu, dezhi Jia, Hongjun Lei, Ming Feng, Weixiong Feng, Hui Jiang, Jiwei CNPC Engineering Technology R&D Company Limited Beijing102206 China PetroChina Tarim Oilfield Company Limited Korla841000 China China Petroleum Technical Service Corporation Limited Beijing100010 China

ISBN: (纸本)9783031449468

The ultra-high pressure saltwater formation coupled with high permeability sand intercalation makes the ultra-deep salt and gypsum formation (6670–7700 m TVd) drilling of the 9–1/2ʺ hole section particularly challenging in the piedmont area in Tarim Basin. drilling strategy is usually oriented to the use of high density OBM with densities normally ranging between 2.32 and 2.60 g/cm3. High density mud causes losses and sticking events. To overcome the challenges mentioned, the application of MPd technology with the constant liquid volume during the drilling of the 9–1/2ʺ hole section enables utilizing the balance between formation pressure and downhole pressure. The technology involves keeping constant circulation fluid volume during drilling, and pipe connection under shut-in, shut-in during trip and keeping fluid in wellbore constant by squeezing in and releasing liquid, so as to keep pressure in wellbore balanced. This paper summarizes the key points of field implementation and related calculation method of the constant liquid volume MPd technology. Comparing with conventional drilling methods, the constant liquid volume MPd technology can enhance drilling efficiency and mitigate drilling hazards such as losses and differential sticking. As a result 325 m of salt and gypsum formation were drilled in only 29 days while field average is around 97 days. The successful application of MPd technology will provide a new approach for safe drilling of ultra-high pressure saltwater and narrow density window formation. © The Author(s), under exclusive license to Springer Nature Switzerland AG 2024.

关键词： Infill drilling

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Feasibility Study of Low-Tension-Gas Flooding Application in High Temperature High Salinity Sandstone reservoirs

Feasibility Study of Low-Tension-Gas Flooding Application in...

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2023 Abu dhabi International Petroleum Exhibition and Conference, AdIP 2023

作者： Zhou, Nancy C. Niu, Fangya Panthi, Krishna K. Abdullah, Mohammad B. Lu, Meng Vaughan, Steven Zhang, danhua Leslie Mohanty, Kishore K. Mojdeh, delshad Li, Jianshen Liu, Fuchen Yang, Zhenzhou CNPC USA Corp. KatyTX United States The University of Texas at Austin AustinTX United States CNPC Engineering Technology R&D Company Limited Beijing China

ISBN: (纸本)9781959025078

Low-tension-gas (LTG) flooding has been demonstrated in the laboratory to improve oil recovery for tight formations with sub-20-md permeability. High temperature and high salinity (HTHS) reservoir conditions still pose significant challenges for this hybrid surfactant and gas enhance oil recovery (EOr) method. This paper presents a systematic study that includes developing low interfacial tension (IFT) surfactant formulation, investigating LTG flooding, and lab-scale reservoir simulations to evaluate the feasibility of LTG for field application in harsh reservoir conditions. The brine and crude oil analysis showed that the formation water and injection water from the interested field have total dissolved solids (TdS) up to 70,000 ppm and divalent cations, such as calcium (Ca2+) and magnesium (Mg2+) over 2,000 ppm, and the crude oil contains over 5% asphaltene and has total acid number of > 0.5 mg KOH/g. A novel synergistic blend of two commercially available long-alkyl-chain surfactants with a co-solvent was developed with ultralow IFT and acceptable foamability at 92°C. The foam injectivity core flood showed that a foam quality of 50-80% demonstrated a stable foam. The surfactant polymer (SP) core flood test using outcrop cores demonstrated the efficiency of the developed ultra-low IFT surfactant formulation. LTG core flood experiments using reservoir core plugs were performed by injecting the same low tension surfactant formulation along with gas at 50% quality followed by foam drive with the mobility control foam at 80% quality. The residual oil saturation was reduced to less than 5% by LTG flooding. The lab observed recovery was accurately modeled using UTCHEM, a chemical flooding simulator. Our experimental work demonstrates the effectiveness of LTG flooding in high temperature sandstone reservoirs with high divalent cations in high salinity formation brine. Our mechanistic models and numerical simulations for this complex surfactant and gas EOr method matched

关键词： Gases

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An Integrated Governance technology Based on Magnetic Steering System for Cementing Plug in Open-Hole Section of Underground Gas Storage: Theoretical Analysis and Field Test

An Integrated Governance Technology Based on Magnetic Steeri...

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2024 SPE Conference at Oman Petroleum and Energy Show, OPES 2024

作者： Che, Yang Yuan, Guang Jie He, Ai Guo Qiao, Lei Liu, Tian En Fang, Ming Xing CNPC Engineering Technology R&D Company Limited Institute of Unconventional Oil and Gas Engineering Beijing China National Engineering Research Center for Oil & Gas Drilling and Completion Technology Beijing China China University of Petroleum Beijing China

ISBN: (纸本)9781959025252

The paper describes a comprehensive control technology based on a magnetic steering system for plugging the cementing plug in open holes without clear beacons in underground gas storage (UGS). Utilizing depleted oil and gas reservoirs for natural gas storage is an important approach towards achieving carbon neutrality. Plugging old wellbores that affect sealing performance is prioritized according to relevant standards. The challenge with open holes with cement plugs is that there are no clear beacons in the wellbore, and the extent of compaction is unknown. Accurate positioning of the cement plug is crucial and the current technical methods, such as electromagnetic and acoustic waves, have limitations. Magnetic steering technology, which is mature and widely used in drilling complex structure wells, requires beacons like pipes and metal pipe strings. On the other hand, acoustic positioning technology is still experimental and suffers from large distance and azimuth errors due to the attenuation characteristics of acoustic waves in heterogeneous formations. These existing technologies are unable to directly position open holes with cement plugs. The paper proposes a comprehensive control technology based on the magnetic steering system. It starts by measuring the positional relationship between the drilling wellbore and a magnetic reference wellbore using the magnetic steering system. The skew data is then used with the ISCWSA model to determine the location of the plugged wellbore and the magnetic reference wellbore. By calculating the relative positional relationship between the drilling wellbore and the plugged wellbore, the cement plug reentry can be achieved within the error ellipse range below the sidetracking point. After reentry, specific work such as crushing, element logging, caliper logging, and full hydrocarbon gas detection is performed to verify if the wellbore is still in the original position and if the caprock is properly squeezed and plugged. The c

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