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10 March 2026, Volume 22 Issue 1

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EXPERT VIEWPOINT

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A Nanogel Viscosifier and Plugging Agent for Deep Complex Formations：Performance Evaluation

LUO Pingya, HE Jianing, DUAN Yongqiang, ZHANG Yong, YOU Ziwei, LIU Pingjiang, CHEN Li, BAI Yang, WANG Ren, BAI Yingrui

2026, 22(1):  1-8.  DOI: 10.12388/j.issn.1673-2677.2026.01.001

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To address the common challenges of rheological deterioration，excessive fluid loss，and wellbore instability for drilling fluids under high temperature，high salinity，and high stress conditions in ultra-deep wells，a cationic nanogel viscosifier and plugging agent，P（AM-DMC），was designed and synthesized from acrylamide （AM） and methacryloxyethyltrimethylammonium chloride （DMC） via inverse suspension polymerization. This material combines the viscosity-enhancing property of flexible polymer chains with the high interfacial activity and size effects of nano-particles. Scanning electron microscopy （SEM） showed the material has an irregular polyhedral morphology and a particle size distribution of 200-500 nm. The performance of the developed material was systematically evaluated in a low solid water based drilling fluid，including rheology，filtration control，and salinity tolerance，while the contact angle and Zeta potential measurements were used to reveal the micro-interfacial properties. The material exhibited high hydrophilicity （a contact angle of 13°） and excellent dispersion stability，facilitated by its strong positive surface charge （Zeta potential of +59.1 mV），which forms the basis of the synergistic viscosity-enhancing and plugging mechanism. Results demonstrated that P（AM-DMC） significantly improves the structural viscosity and shear resistance capacity of the drilling fluid through strong electrostatic adsorption between its cationic chains and clay particles，along with the formation of a three-dimensional network of the materials. Increasing the dosage of P（AM-DMC） markedly enhanced the apparent viscosity and yield point while significantly reducing both API and HTHP fluid loss. The system maintained excellent rheological stability and low fluid loss after aging at 170°C，confirming its outstanding thermal stability. It is indicated that P（AM-DMC） nanogel is a novel additive for high-performance drilling fluids in deep complex formations，offering efficient viscosity enhancement，fine plugging，and superior temperature resistance and thus holding significant engineering value for the safe and efficient drilling of ultra-deep wells.

OIL AND GAS EXPLORATION

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Research Progress on High Temperature Fluid Loss Control Mechanisms and Materials for Water Based Drilling Fluids

YANG Jie, WANG Ren, LUO Yufeng, LIANG Hao , JING Yujuan, ZHOU Chuxiang

2026, 22(1):  9-25.  DOI: 10.12388/j.issn.1673-2677.2026.01.002

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In the process of high temperature deep well drilling，water based drilling fluid is prone to problems such as sharp increase in fluid loss and deterioration of performance，which seriously affects wellbore stability and drilling safety. Therefore，the research on high temperature fluid loss control mechanism and materials has become a critical issue in current oil and gas drilling engineering. This review summarizes the influencing factors and mechanism of high temperature fluid loss of water based drilling fluids，analyzes the synergistic effects of temperature，pressure，and formation conditions on leak off performance，and reveals the underlying mechanisms of clay particle aggregation，polymer molecular chain degradation，and mud cake structure disruption under high temperature conditions. On this basis，the research progress of high temperature fluid loss control materials in recent years is discussed，including the functional design，synthesis methods and performance optimization strategies of modified natural polymers，high temperature polymers，sulfonated materials，and nanocomposite materials. The high temperature stability and fluid loss control effect of four kinds of fluid loss reducer are compared. The problems of ultra-high temperature adaptability，environmental protection and economy are summarized，and the future development directions of extreme environment resistance，green sustainability and intelligent design synergy are prospected. This review provides theoretical insights and technical support for the development and application of fluid loss control materials for high temperature drilling fluids.

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Unsupervised Diagnosis and Response Recommendation System for Stuck Pipe Risks

LV Zehao, LI Zhen, WEI Fengqi, JI Guodong, LI Lingdong, CHEN Weifeng

2026, 22(1):  26-32.  DOI: 10.12388/j.issn.1673-2677.2026.01.003

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Stuck pipe，a common risk during drilling operations，severely restricts safe and efficient drilling. Traditional methods for diagnosing and handling stuck pipe incidents mostly rely on expert experience，mechanistic models，or supervised machine learning algorithms and suffer from issues such as diagnostic lag，high false alarms due to overfitting，strong subjectivity，and low adaptability. This paper proposes a method for diagnosing stuck pipe risks and recommending cases of countermeasures based on unsupervised learning and K-Nearest Neighbors （KNN），which has been implemented as a software system. The system comprises two core modules：stuck pipe risk diagnosis and stuck pipe incident handling. The stuck pipe risk diagnosis module employs the Isolation Forest algorithm to monitor and diagnose abnormal trends in key real-time downhole engineering parameters. The stuck pipe incident handling module utilizes a Case-Based Reasoning （CBR） algorithm based on KD-Tree and KNN to retrieve cases from a stuck pipe decision case library，returning the data of three most similar cases to the client-side to assist engineers in handling stuck pipe incidents. Based on the aforementioned，an intelligent downhole sticking diagnosis system based on case-based reasoning was designed and implemented. Tests show that the system successfully issues warnings approximately 5 minutes before an incident occurs，quickly retrieves three most similar historical handling cases，and pushes them to the interface. This developed system provides direct decision support for engineers.

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Research Status and Technical Progress of Wellbore Integrity

LI Xiao, ZHAO Yuhang, ZHANG Hui, WU Yongchuan, ZHENG Ting, ZHANG Yi, ZHENG Fangjian, CHEN Qi

2026, 22(1):  33-39.  DOI: 10.12388/j.issn.1673-2677.2026.01.004

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Wellbore integrity is a key factor to ensuring the safe and sustainable operation of oil and gas wells throughout the life cycle. As the global energy exploitation expands to regions with deep formations，deep seas and complex geological conditions，the wellbore barrier system is facing unprecedented challenges due to extreme conditions such as high temperature and high pressure （HTHP），high stresses and corrosive media. Over recent years，great progress has been made in research on wellbore integrity thanks to the development of new materials，applications of intelligent monitoring techniques and innovation of risk assessment models. This paper summarizes the research status of multiple aspects of wellbore integrity，such as HTHP-tolerant materials，composite materials resistant to hydrogen penetration，smart sensors and data-driven prediction models，and multi-factor risk assessment methods. Moreover，it reviews the current challenges in long-term durability validation of materials，reliability of intelligent monitoring systems and applicability of multi-scale models as well as special requirements of emerging application scenarios for Carbon Neutrality. This paper provides references for safe development of oil and gas and integrity management of subsurface storage and transportation facilities for energy transformation.

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Numerical Simulation on the Damage Evolution Law of Casing-Cement Interface During Perforating

DING Jianxin, SUN Wenyue, YANG Zhiguo, WANG Jianhua, WANG Haitao, XI Yan

2026, 22(1):  40-48.  DOI: 10.12388/j.issn.1673-2677.2026.01.005

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During perforating，the high velocity jet penetrates the casing-cement-formation assembly. This not only causes damage to the cement sheath but also leads to bonding damage at the casing-cement interface. Such degradation tends to cause cross-flow of wellbore fluids along channels in the casing-cement interface，ultimately severely shortening the lifespan of oil and gas wells. Given this，a numerical model of high velocity jet penetration into the casing-cement-formation after perforating charge explosion is established using the fluid solid coupling method. The dynamic damage evolution law of the casing-cement bonding interface in the process of penetration is analyzed，and the effects of the cement sheath material parameter （shear modulus），cohesive unit parameter （fracture energy） and casing types on the damage area and maximum damage radius of the bonding interface are investigated. The results show that with the penetrating of jet，damage appears at the casing-cement sheath bonding interface，and the damage zone continuously expands. When the jet penetrates into the formation，the damage area reaches the maximum. With the increasing of shear modulus or fracture energy of cement sheath，the damage degree of the bonding interface decreases. Increasing borehole cleaning or using fiber containing cement slurry can reduce the damage of jet penetration to the bonding interface. When aluminum alloy，titanium alloy，nickel base alloy and other highly resistant casings are used，the damage area and maximum damage radius of the casing-cement bonding interface increase significantly during perforation penetration. The findings of this research provide theoretical support for wellbore integrity protection and engineering parameters optimization during perforating.

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Study on Seal Failure of Rubber Cylinder of Ultra-Deep Well Packers Based on Thermal-Mechanical Coupling

LIAN Wei, LIU Xianbo

2026, 22(1):  49-57.  DOI: 10.12388/j.issn.1673-2677.2026.01.006

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With the oil and gas exploration and development shifting toward deep and ultra-deep formations，the temperature and pressure conditions of the wellbore are becoming more and more complicated，and the problem of seal failure of packer rubber cylinders attracts increasing attention. Based on the principle of thermal-mechanical coupling，a numerical calculation model of the rubber cylinder of packers in ultra-deep wells was established according to the temperature distribution characteristics of the wellbore of ultra-deep wells，which revealed the influence of the wellbore temperature in ultra-deep wells on the sealing ability and safety of the rubber cylinder. It is shown that with the increasing wellbore temperature，the axial compressive deformation and radial expansion deformation of the cylinder both grow，and the sealing performance of the cylinder climbs up. However，the safety of the cylinder after setting is degraded. Based on the dynamic load distribution characteristics of the wellbore during perforation completion of an ultra-deep well in Sichuan Basin，the limit distance between the packer and the perforation section is calculated to be 220 m. Therefore，it is recommended that the packer be designed to be set at a position 90 m further down from 6 810 m toward the well bottom to improve the sealing performance of the rubber cylinder after setting. The research provides technical references for the optimization of packer setting positions in ultra-deep well completion.

OIL AND GAS DEVELOPMENT

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A New Method for Simulating Fractures and Evaluating Drilling Plugging Effectiveness Based on 3D Printing

YANG Liuqing, WANG Haibo, LIU Zhimin, ZENG Xin, LIU Ming

2026, 22(1):  58-67.  DOI: 10.12388/j.issn.1673-2677.2026.01.007

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Lost circulation is a critical technical challenge in drilling engineering. Current laboratory simulations of fracture-induced lost circulation primarily rely on traditional methods such as steel plate fractures，metal sheets，and sand beds，which fail to adequately replicate complex characteristics of actual thief zones，including the fracture orientation，tortuosity，and surface roughness. As a result，the field application success rate of plugging materials under complex geological conditions is still generally low. This paper proposes an innovative method that integrates realistic fracture simulation of thief zones with 3D printing technology through 3D imaging reconstruction. Actual rock samples of thief zones are scanned to establish digital core models，and 3D printing is applied to creating simulated cores，which significantly improves the fidelity and compatibility to real fracture structures. On this basis，a customized high temperature high pressure dynamic circulation plugging apparatus is used to conduct systematic pressure bearing experiments of multi-scale composite fractures. The sealing performance of various plugging formulations are compared and analyzed between 3D printed cores and traditional steel plate fractures，and a new methodology applicable to realistic fracture simulation and plugging evaluation is constructed. Field testing has validated that the optimized plugging formulation presents a one-time success rate of 83%，significantly enhancing the operational feasibility and economic viability of plugging operations. This method provides effective technical support for the efficient and precise sealing of complex formation fractures and contributes substantially to improved drilling efficiency and security of oil and gas resource recovery.

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Mechanism of Borehole Instability in Mudstone of Shihezi Formation in Sulige Block and Corresponding Drilling Fluid Technical Countermeasures

SUN Minghao, LI Yaoxuan, WANG Ju, GENG Yuan, MENG Sicong, WANG Lihui

2026, 22(1):  68-77.  DOI: 10.12388/j.issn.1673-2677.2026.01.008

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Drilling the mudstone of the Shihezi Formation in the Sulige Block is prone to complex issues such as lost circulation，frequent sticking and jamming during tripping，and wellbore collapse，which severely restrains the operation efficiency of drilling. To tackle the technical challenge of wellbore instability in drilling the Shihezi Formation mudstone，the mechanisms behind wellbore instability of this block were investigated by collecting samples of the Shihezi Formation mudstone and researching the microscopic fabrics and physical and chemical properties of rocks as well as the law governing the effect of hydration on rock mechanics parameters. Meanwhile，the variations of samples in the microscopic morphology，mechanical property and dispersion capability were observed after they are treated by aqueous solutions of different inhibitors and different drilling fluid systems. It was found that，on the basis of a composite salt system，the combined use of organic and inorganic inhibitors to suppress shale hydration achieved the best performance in improving wellbore stability of the Shihezi Formation mudstone. Correspondingly，countermeasures to enhance wellbore stability were proposed. The findings of this research provide theoretical support for techniques improving wellbore stability in the Sulige Block and assist in the safe，steady，and efficient development of the Sulige self-operated block.

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Main Control Factors and Laws of Perforation Erosion in Volume Fracturing

WANG Bo, LI Huan, YAN Tingwei, ZHOU Lintai, SHENG Shaopeng, ZHOU Fujian

2026, 22(1):  78-87.  DOI: 10.12388/j.issn.1673-2677.2026.01.009

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Volume fracturing is one of the key technologies for the efficient development of unconventional oil and gas resources. At present，volume fracturing has entered the stage with the core characteristics of multi-cluster，small cluster spacing，limited entry perforating，temporary plugging diversion，high injection rates and high-intensity proppant injection. Perforation erosion is serious in cases of high injection pressure，high injection rates and high sand concentrations. This leads to high likelihood of failure of temporary plugging and limited entry and consequently high difficulties in delivering spontaneous initiation and uniform propagation of fractures due to competitive fluid attraction among perforation clusters within one fracturing stage，which is practically restraining the safe and high-efficiency development of unconventional oil and gas. A global literature review of the studies on perforation erosion in both China and other countries is performed. The theoretical models of perforation erosion are summarized，and the research status of perforation erosion is analyzed. The causes of perforation erosion during large-scale propped fracturing are discussed，the factors affecting perforation erosion are identified，and the countermeasure strategies are proposed. Clarifying the main factors controlling perforation erosion and the corresponding laws and developing protective measures are of great engineering significance for the efficient development of unconventional hydrocarbon resources.

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Analysis of Factors Affecting Pressure Prediction Accuracy and Model Selection for HPHT Condensate Gas Wells

HAN Guoqing, HE Tian, GUO Ling, LAI Siy, LIU Tong

2026, 22(1):  88-96.  DOI: 10.12388/j.issn.1673-2677.2026.01.010

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Most of the deep condensate gas fields under development in China are characterized by high temperature，high pressure，and complex phase behaviors. Due to the constraints of testing cost and safety，direct measurement of downhole pressure is not feasible，and therefore，multiphase pipe flow models suited to high pressure and high temperature （HPHT） condensate gas wells are required to predict bottomhole pressure according to wellhead data. To clarify the applicability differences of multiphase wellbore flow models for pressure prediction in HPHT condensate gas wells and establish a rational basis for model selection，this study analyzes the phase behavior evolution across the dew point and the flow pattern transitions under high pressure conditions，compares the applicability of black-oil and compositional models，and evaluates four mechanistic models and five empirical models through case studies. The results indicate that for the seven case wells，the average error of mechanistic models is only 1.76% in deep wells，lower than that of empirical models；in conventional wells，the average errors of both model types exceed 10%. The multi-fluid mechanistic model corrected by high pressure flow experiments and field test data，combined with compositional models accounting for the effect of polar water，can better capture condensate dropout，liquid holdup variation，and are thus more suitable for HPHT condensate gas well pressure prediction. This study provides important references for improving and applying prediction methods of wellbore pressure profiles and bottomhole pressure in HPHT condensate gas wells.

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Research on Construction and Properties of a Foaming Complex Containing Sodium Cocoyl Glycinate for Gas Well Drainage

DONG Sanbao, YAN Yao, LI Jinhua, MA Chao, CHEN Jiakui, REN Zhenyu, HAN Weiwei

2026, 22(1):  97-106.  DOI: 10.12388/j.issn.1673-2677.2026.01.011

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For liquid-loading gas wells，applications of high-performance foaming complexes are key to successful foam-assisted removal of water accumulating in gas wells. Therefore，in this paper，we developed a gemini cationic surfactant （CAGB） and combined it with sodium cocoyl glycinate （SCG） and a short-chain fluorocarbon surfactant FS-50 to form an excellent ternary foam drainage formulation tolerant of salts and gas condensate. Experimental results showed that with the CAGB/SCG/FS-50 molar ratio of 4∶16∶5 and a total concentration of 25 mmol/L，the foam volume and half-life time were optimized up to 455 mL and 20.45 min，respectively. After adding rhamnose，the foam volume and half-life were 405 mL and 74.09 min，respectively. The liquid carrying tests showed that a certain amount of condensate and methanol can enhance the liquid carrying performance of the foaming formulation. The liquid-carrying rate reached 45.94% in the case of the condensate content of 50%，and the foam formulation could withstand up to 60% condensate. Methanol also promoted the liquid-carrying performance. When the methanol content was 20%，the liquid-carrying rate could be increased to 44.69% and it remained high even at the methanol content of 60%. The addition of rhamnose allowed the ternary foaming formulation to maintain stable liquid-carrying capability at a salinity of 410 g/L，with a liquid-carrying rate of 32.35%. Elevated temperature is in favor of improving the liquid-carrying capability of the ternary foaming formulation，and the liquid-carry rate was high up to 69.11% at 90 ºC. Finally，surface tension tests and foam morphological observations also confirmed the synergistic effect of the components of the foaming formulation.

NEW ENERGY

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Techno-Economic Analysis of Desert-Gobi-Wasteland Large Scale New Energy Base in Xinjiang with Gas-Fired Power Support

LI Yunlong, LIU Yi, GU Jiawei, MA Mingwei, CHENG Long

2026, 22(1):  107-113.  DOI: 10.12388/j.issn.1673-2677.2026.01.012

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Under the "dual carbon" goals，gas-fired power，with its high efficiency，flexibility and cleanness，has become a crucial backbone power source for building a new-type power system. Focusing on the construction needs of large scale new energy bases in desert-gobi-wasteland regions of Xinjiang，this research considers the natural gas abundance of Xinjiang and systematically analyzes the regulation flexibility of gas-fired power，compared to coal-fired power，from a techno-economic perspective. Typical operational scenarios for desert-gobi-wasteland large scale new energy bases are designed，and shares of green electricity and carbon emission intensity are calculated in cases of different power source configurations. Moreover，this research quantifies the economic indicators and environmental benefits of gas-fired power and demonstrates the feasibility of gas-fired power as a superior backbone power source for such bases. The results show that introducing gas power into the base can significantly increase shares of green electricity by approximately 14% and reduce carbon emission intensity by about 75%，compared to the case of coal power. It is confirmed that gas-fired power offers notable advantages in enhancing new energy integration of the base，ensuring system security，and increasing proportions of clean electricity for transmission. The findings of this research provide a reference case balancing economic viability with ecological value for solutions to constructing clean energy bases in desert-gobi-wasteland regions.

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An Optimization Method for CO₂ Water-Alternating-Gas （WAG） Development Strategy Driven by Machine Learning

SU Bin, LI Junchao, ZHU Chen, LI Jixin

2026, 22(1):  114-124.  DOI: 10.12388/j.issn.1673-2677.2026.01.013

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Although numerical simulation exhibits high predictive accuracy in optimizing development strategies for CO₂ water-alternating-gas （CO₂-WAG） flooding，its limited efficiency cannot facilitate high-efficiency optimization of development plans for complex reservoirs due to the enormous computational burden involved in multi-parameter combinational and global optimization. To address this issue，a surrogate modeling approach based on the random forest algorithm is proposed and integrated with a global optimization framework to greatly enhance computational efficiency and predictive accuracy. By employing an improved K-Fold cross-validation method for hyperparameter optimization，a surrogate model capable of accurately capturing the complex nonlinear relationships between input parameters and development outcomes is constructed. The reliability of the model is validated using the test set of goodness of fit（R²） and root mean square error （RMSE），and its feasibility and precision are further demonstrated through comparisons with numerical simulation results. During the optimization process，an iterative traversal method is employed to explore the trade-off between incremental oil recovery and CO₂ storage efficiency，leading to the proposal of an optimal injection-production strategy meeting multiple objectives. The optimization results reveal that compared with conventional development schemes，the random forest algorithm optimized strategy significantly increases cumulative oil production，enhances CO₂ storage efficiency，and delays gas breakthrough. For a real tight reservoir model，the optimized scheme delivers an increase of 8.6% in cumulative oil production，an improvement of 14.5% in CO₂ storage，and a six-year delay in gas breakthrough，demonstrating significant enhancements in displacement performance and development benefits.

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Construction and Performance Evaluation of CO₂ Responsive Thickening System

ZHENG Cunchuan, SONG Yi, CHEN Shengen, PANG Zhequn, ZHOU Bidong, JING Qianlong

2026, 22(1):  125-132.  DOI: 10.12388/j.issn.1673-2677.2026.01.014

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To address the issue of reduced oil recovery caused by CO₂ channeling during CO₂ flooding in low permeability reservoirs，a salt-tolerant and temperature-resistant plugging system with low initial viscosity and high CO₂ responsiveness was developed using erucamidopropyl dimethylamine （PKO‑E） and a counterion salt. The basic properties of the system，along with its injectivity and plugging performance under simulated low permeability reservoir conditions，were systematically investigated. Experimental results showed that at 70 ℃ and a salinity of 9 824.97 mg/L，the CO₂-responsive thickening system exhibited an initial viscosity below 4.7 mPa·s，which increased to above 600 mPa·s after CO₂ introduction，confirming its low initial viscosity and strong CO₂-induced thickening characteristics. The system also demonstrated high salt resistance and thermal stability-maintaining viscosities of 453.97 mPa·s at 70 ℃ with a salinity of 2.5×10⁴ mg/L and 512.26 mPa·s at 90 ℃ with a salinity of 9 824.97 mg/L. In plugging tests using low permeability cores，the injection pressure remained below 0.3 MPa，the plugging efficiency exceeded 96%，the gas reduction rate was above 96%，and the breakthrough pressure reached over 2.31 MPa，which proved the high efficiency sealing capability of the system for CO₂ channeling pathways in low permeability formations. This study provides a useful reference for enhancing oil recovery in such reservoirs.

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Experimental Study and Model Optimization of Carbon Dioxide Dissolved Gas Crude Oil

HE Yanan, XIONG Xiaoqin, HUANG Delin, WANG Peiyao, MA Qizhao, LIAO Tao

2026, 22(1):  133-142.  DOI: 10.12388/j.issn.1673-2677.2026.01.015

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With the technical progress in carbon dioxide （CO₂） flooding for enhanced oil recovery （CO₂-EOR），it is of great significance to study the influence mechanism of CO₂ injection on the viscosity of crude oil. This study systematically investigated the synergistic effects of temperature （20-40 ℃），pressure （0.5-3.5 MPa），and water content （0%-60%） on the viscosity of saturated CO₂  dissolved gas crude oil through laboratory experiments. The results showed that under constant pressure，for every 5℃ increase in temperature，the viscosity decreases by approximately 60%-80%. At a constant temperature，for every 0.5 MPa increase in pressure，the viscosity decreases by approximately 1%-5%. In terms of water content，a 10% increase in water content leads to a rise in viscosity by 15%-50% before the inverted point （water content < 40%）. After the inverted point （water content>40%），for every 10% increase in water content，the viscosity decreases by 50%-80%. Based on the experimental data，the prediction performance of three classic models，namely Standing，Glaso and Vazquez & Beggs （V&B），was evaluated. It was found that the V&B model had the best robustness. The XGBoost algorithm combined with Bayesian optimization was used to dynamically correct the V&B model，and a multi-parameter mapping relationship of temperature，pressure and water content was established. The average relative error of the model was reduced from 20.1% to 6.9%，and the average absolute error was decreased by approximately 66%. This study provides a theoretical basis and intelligent prediction tool for the process design and dynamic optimization of oil and gas gathering and transportation systems under CO₂ flooding conditions.