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    10 October 2025, Volume 47 Issue 5
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    ACADEMICIAN THOUGHTS
    Preparation and Performance Evaluation of High Temperature Degradable Pullulan Microsphere Hydrogel Plugging Agent
    LUO Pingya, DAI Feng, XIANG Xinrong, LIN Zhengwen, LIU Yingmin, BAI Yang
    2025, 47(5):  1-12.  DOI: 10.11885/j.issn.1674-5086.2025.01.11.02
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    Wellbore instability poses a significant challenge encountered during drilling operations, impacting the efficiency of drilling processes, escalating operational expenses, and jeopardizing drilling safety. Nanomaterials play a pivotal role in sealing microcracks within the formation and stabilizing the wellbore. In this investigation, a pullulan microsphere (PM) was produced through reverse microemulsion polymerization. Subsequently, N, N-dimethylacrylamide (DMAA), 2-acrylamido-2-methylpropanesulfonic acid (AMPS), and dimethyldiallylammonium chloride (DMDAAC) were grafted onto PM to create a pullulan microsphere plugging agent (PM-DAD). Experimental findings demonstrate that PM-DAD disintegrates into nanoparticles of varying sizes under different high temperatures, effectively sealing microcracks of diverse dimensions. PM-DAD exhibits remarkable efficacy in reducing filtration losses, with the filtration loss of freshwater-based slurry measuring 4.7 mL after aging at 200 ℃, while maintaining a salt resistance of 15%. Notably, PM-DAD demonstrates prolonged and efficient plugging capabilities, reducing the artificial mud cake permeability by 65.2% and limiting sand bed invasion depth by 9.2 cm after being subjected to 200 ℃ aging. The mechanism elucidates that PM-DAD accomplishes nanopore sealing through a synergistic approach involving pore penetration and rock surface adsorption, highlighting its potential application in shale gas extraction.
    GEOLOGY EXPLORATION
    Application of 3D Far-field Sonic Service in the Identification of Carbonate Reservoir Borehole-side Reflector
    ZHAO Ailin, CHENG Lu, TANG Yulin, WU Yuyu, HUANG Hong
    2025, 47(5):  13-23.  DOI: 10.11885/j.issn.1674-5086.2024.05.22.01
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    The carbonate reservoir of Permian Maokou Formation in the Sichuan Basin has strong heterogeneity, and its reservoir space is mainly cracks and holes. It is difficult to evaluate the fractures and caves near the borehole by conventional logging methods due to the limitation of detection depth. The conventional dipole acoustic reflection imaging can evaluate the fractures and caves in the range of several meters to tens of meters around the borehole to a certain extent, but it has the disadvantages of low resolution and 180° ambiguity in azimuth measurement. The 3D Far-field sonic service based on Sonic Scanner can simultaneously record multi-azimuth monopole and dipole wave field data. By combining the processing results of monopole and dipole data, the high-resolution detection results of the borehole-side structure can be obtained and the remote detection depth can be realized at the same time. The true azimuth and dip of the well-side structure can be obtained by using ray tracing and 3D STC technology, which overcomes the limitations of traditional acoustic remote detection technology. This paper introduces the 3D Far-field sonic service technology and the field application case of a horizontal well in Maokou Formation in central Sichuan Basin. The field application results show that the technology can effectively evaluate the fractures and formation interfaces within 60 m near the borehole in the carbonate reservoir of Maokou Formation in central Sichuan Basin, which provides a strong technical guarantee for the increase of reserves and production in Maokou Formation.
    Sedimentary Characteristics and Evolution Model of Lower Cambrian Canglangpu Formation in Central and Northern Sichuan Basin
    QU Haizhou, YANG Shiyuan, LI Juzheng, WEN Siying, ZHOU Linlang
    2025, 47(5):  24-38.  DOI: 10.11885/j.issn.1674-5086.2024.07.21.02
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    To deepen the understanding of the sedimentary facies of the Lower Cambrian Canglangpu Formation in the northern part of the Sichuan Basin and clarify the favorable areas for the distribution of carbonate beaches. Based on core, logging, seismic and field outcrop data, this paper studies the sedimentary characteristics and evolution model of the Lower Cambrian Canglangpu Formation. The results show that: 1) The sedimentary facies of Canglangpu Formation in the study area can be divided into four types: muddy water tidal flat facies, mixed platform facies, restricted platform facies and open platform facies. The muddy water tidal flat facies can be divided into two subfacies of intertidal zone and subtidal zone, and the lithology is mainly clastic rock. The mixed platform facies can be divided into two subfacies: platform flat and platform depression, which are dominated by mixed rock deposits. The restricted platform facies and the open platform facies are dominated by carbonate deposits. The former is dominated by dolomite, and the latter is dominated by limestone. 2) From west to east, muddy water tidal flat facies, mixed platform facies, restricted platform facies and open platform facies are successively developed in the first member of Canglangpu Formation under the influence of western terrigenous debris injection and Deyang-Anyue rift trough. 3) During the sedimentary period of the second member of Canglangpu Formation, the early rift trough was almost filled up, and the muddy water tidal flat facies was the main sedimentary facies. In summary, the favorable beach bodies in the study area are mainly developed in the restricted platform-open platform facies on the east side of the pre-rift trough. Affected by the rift trough and regression, the beach bodies gradually migrate eastward.
    Lithology Identification in Glutenite Reservoir Based on the XGBoost Algorithm
    WANG Yingwei, ZHAO Jun, QIN Jianhua, ZHANG Jing, WANG Junyu, FENG Yueli
    2025, 47(5):  39-48.  DOI: 10.11885/j.issn.1674-5086.2024.06.12.01
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    In glutenite reservoirs, the complexity of logging responses due to rock granularity poses challenges for traditional lithology identification methods. With technological advancements, combining logging data with computer technology for lithology research has become a new trend. The optimized version of the gradient boosting decision tree, the XGBoost algorithm, is widely applied in lithology identification for its efficient and accurate prediction capabilities and excellent generalization performance. This study uses the XGBoost algorithm to identify the lithology of glutenite reservoirs in the M block to improve identification accuracy. By analyzing the lithological characteristics and logging responses of the Baikouquan formation reservoirs, four logging curves (GR, AC, DEN, RT) were selected as feature variables. A total of 468 sample data sets were divided into training and testing sets in 4： 1 ratio, and the key parameters of XGBoost were optimized through cross-validation, determining the optimal values for iteration times, learning rate, and other model parameters. The experimental results show that the XGBoost algorithm performs well in lithology identification, achieving a final accuracy rate of 91.05%, an improvement in both accuracy and efficiency compared to the C4.5 decision tree algorithm. The study results demonstrate the effectiveness of the XGBoost algorithm in improving lithology identification accuracy, providing guidance for the exploration and development of glutenite reservoirs.
    Natural Gas Accumulation Mechanisms and Exploration Directions of Ancient Reservoirs in the Sichuan Basin Under Multi-Stage Tectonic Backgrounds
    TANG Yuxin, XIAO Di, ZHAO Like, LUO Bing, ZHOU Gang, HU Guang
    2025, 47(5):  49-61.  DOI: 10.11885/j.issn.1674-5086.2024.10.17.02
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    To deepen understanding of the Sinian-Cambrian gas enrichment in the Sichuan Basin and expand exploration fairways, this study of the Dengying Formation documents reservoir types and fluid properties under multiple tectonic episodes and quantifies their regional variability. Recurrent deformation generated structural, lithologic and stratigraphic-lithologic composite traps. Extensional intracratonic sags evolved into hydrocarbon kitchens that contain thicker, higher-quality source rocks. The basin interior retains a closed formation-water system, excellent preservation and high gas saturation, whereas the marginal zones retains open meteoric flux, weaker preservation and low saturation. Four accumulation styles are recognized: primary accumulation in Anyue where a paleo-oil pool cracked in situ; residual accumulation in Ziyang where cracked hydrocarbons migrated and were partly stranded; adjusted accumulation in Weiyuan where remigration led to entrapment elsewhere; and destroyed accumulation in Sangmuchang where the paleo-pool was breached and dispersed. Primary accumulations exhibit the most favourable formation and preservation conditions, followed by adjusted ones. Tectonic stability is the key control on gas retention in these ancient strata; the northern and southern slopes of the central Sichuan paleo-uplift are the premier fairways for primary and adjusted pools and constitute the focus of future exploration.
    Geology Sweet Spot of Shale Gas Optimization Evaluation Based on Analytic Hierarchy Process
    LENG Yijiang, TANG Hongming, WANG Ying, SHI Xuewen, LIU Jia
    2025, 47(5):  62-74.  DOI: 10.11885/j.issn.1674-5086.2024.12.27.03
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    Shale gas geological sweet spot evaluation is a comprehensive problem involving multiple parameters, and its prediction methods are diverse and the definition of the threshold of each index parameter is difficult to be unified. Based on clarifying the petrophysical properties of shale formations and integrating core experimental analysis results, this study systematically conducted optimization of geological sweet spot parameters for shale gas reservoirs. The prediction models of TOC content, porosity, gas saturation and gas content were established. And the weight coefficients of each key reservoir parameter were determined by analytic hierarchy process. Finally, the quantitative evaluation model of geological sweet spot index was established. The application results in Luzhou deep shale reservoir and Changning middle deep shale reservoir show that the correlation coefficients between the predicted values and the measured values of the four parameters are all above 0.85, which effectively improves the prediction accuracy of key parameters of shale gas reservoir. Both regions show higher geological sweet spot parameters at the bottom of Longmaxi Formation, which is highly consistent with the actual production situation. This study not only solves the contradiction of multi-parameter difficult to quantify in the evaluation process of geological sweet spot, provides a new comprehensive quantitative evaluation model of shale gas geological sweet spot, but also deepens the understanding and understanding of the complex mechanism of geological sweet spot, and provides scientific basis and theoretical support for the formulation of future shale gas exploration and development strategies.
    OIL AND GAS ENGINEERING
    Evaluation of Production Performance in Horizontal Shale Gas Wells Based on Flow Array Sensing Tool Monitoring
    CHEN Meng, LAI Qiang, DONG Guomin, LIU Heng, LIU Xiangjun, LI Zhenglan
    2025, 47(5):  75-84.  DOI: 10.11885/j.issn.1674-5086.2024.11.28.31
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    Production profile logging in horizontal wells is a key technique means to evaluate the development and production performance for unconventional gas reservoirs, and accurate quantification of gas and water production in each production layer is the key basis for guiding the optimization and adjustment of gas reservoir development. A new logging system, flow array sensing tool(FAST), which is different from the existing production logging tools such as MAPS and FSI, was introduced for research. By analyzing the response characteristics of array turbine flow, ultrasonic flow, array conductivity and optical fiber holdup curves, a comprehensive quantitative calculation method for fluid velocity based on array turbine flow rate and ultrasonic flow rate and gas and water holdup based on array conductivity and optical fiber holdup data were established. Case study has been carried out based on the measured curves under 2 working systems for fracturing shale gas horizontal Well QH1 from Sichuan basin. Comprehensive comparison shows that the gas and water production of each production layer calculated based on the proposed method is more matched with the actual reservoir characteristics, and the relative errors between the gas and water production of the full flow layer and wellhead is less than 6.5%, which shows that this new method can better meet the requirements for production performance evaluation and fracturing effect evaluation of horizontal wells in unconventional gas reservoirs.
    Fixed-point Diversion Acid Fracturing Technology and Its Application in Long Horizontal Wells in Western Sichuan Gas Field
    WANG Junfeng, WANG Xingwen, REN Jichuan, HE Songgen, GUAN Chencheng
    2025, 47(5):  85-98.  DOI: 10.11885/j.issn.1674-5086.2023.12.26.31
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    The Leikoupo Formation gas reservoir in the western Sichuan gas field is mainly developed with the “ultra-long openhole + liner completion + fixed-point diversion acid fracturing” method. The correct of the acid fracturing control range within the high-quality reservoir in the planar direction and the effective control of sweet spot reservoirs are key factors in enhancing the stimulation effectiveness of the ultra-long open-hole sections. To address these issues, the study optimizes the fracture control range for different reservoir types through production simulations and identifies the impact of reservoir heterogeneity on the fracture control range. A numerical simulation model is established, which couples acid fluid flow-reaction, pressure changes, wormhole growth, and hydraulic fracture propagation. This model is used to optimize the acid injection location, injection parameters, and timing of temporary plugging. The research findings indicate that the optimal fracture spacing within the high-quality reservoir should be 6180 m, and a thickness of the tight band >40 m affects the fracture control range. The maximum effective stimulation range within the wellbore is determined to be 264.6 m, and temporary plugging methods need to be employed to regulate acid absorption profiles during sweet spot dispersion. The study recommends using half of the acid volume for the initial stage of temporary plugging, and for the subsequent stage, it suggests post-plugging after the first stage or temporary plugging within the segment when injecting 50～100 m3 of acid. Based on these research results, a long horizontal well fixed-point diversion acid fracturing technique is developed and applied to five long horizontal wells, resulting in an average unobstructed flow rate of 235×104 m3/d, which represents a 63.2% increase compared to the previous period.
    Numerical Simulation of Uniform Propagation of Multiple Fracture Promotion though Non-uniform Perforation and Temporary Plugging
    HE Yunbin, REN Jichuan, CHEN Ming, GUO Tiankui, WANG Yunpeng
    2025, 47(5):  99-111.  DOI: 10.11885/j.issn.1674-5086.2023.05.10.01
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    Multi-cluster fracturing of horizontal wells is a key technique for unconventional oil and gas development, in which uneven propagation of multiple fractures is a critical factor limiting production increases. Based on a planar three-dimensional model of multi-fracture propagation, taking into account the heterogeneity of in-situ stress, non-uniform perforation, and temporary plugging within the fracturing stage, a multi-cluster fracturing model for horizontal wells was established and a program was developed to simulate the dynamic propagation of unevenly expanding fractures with consideration of in-situ stress heterogeneity. The study found that the heterogeneity of in-situ stress within the fracturing stage had a significant impact on the competitive expansion of multiple fractures. Adding 2～4 perforation holes in high-stress clusters could balance stress heterogeneity to a certain degree, but there is an efficiency limit when the in-situ stress heterogeneity is strong. Regarding the temporary plugging process within the fracturing stage, the timing of temporary plugging had almost no effect on the increase in bottom hole pressure, and early temporary plugging was beneficial for the balanced distribution of liquid between clusters. The number of temporary plugging operations had a significant impact on the increase in bottomhole pressure, and three temporary plugging operations could increase bottom hole pressure by about 10 MPa. Two to three temporary plugging operations could achieve a relatively balanced liquid injection, but the effect of promoting balanced injection becomes less clear when the number of temporary plugging operations exceeds two.
    Fluid Representativeness Evaluation and Fluid Distribution Characteristics of Fuman Oilfield
    ZHANG Jie, LIU Zhiliang, WANG Peng, ZHAO Longfei, TU Hanmin
    2025, 47(5):  112-120.  DOI: 10.11885/j.issn.1674-5086.2023.10.16.01
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    The reservoir in the Fuman Oilfield is buried at a depth of more than 7 000 m, with high temperature, high pressure, various types of formation fluids, and complex distribution patterns. A significant amount of sampling work was carried out in the early stages of exploring the Fuman Oilfield. It was discovered that in some samples, the dissolved gas oil ratio in the PVT experiment did not match the production gas oil ratio, failing to reflect the properties of the formation fluid accurately. Consequently, an evaluation method for the representativeness of fluid samples from the ultra-deep, high-temperature, and ultrahigh-pressure Fuman reservoirs has been established based on relevant standards and considering whether the dissolved gas to oil ratio aligns with production performance. The representativeness of samples from 58 wells was evaluated, and the factors affecting sample representativeness were analyzed. The research shows that the main reasons for poor sample representativeness include unstable production conditions in the sampling wells prior to sampling, shallow sampling depth for downhole samples, and the imbalance in oil-gas separation during separator sampling. Among all representative samples, the sample collected by separator sampling accounts for 67.74%, and it is recommended that separator sampling be the primary method for Fuman Oilfield in the future. Based on the representative samples obtained, the overall fluids in the Fuman Oilfield showed a trend of lighter fluids from west to east and from north to south.
    Prediction of Penetration Rate Method for Ultra-deep Well Based on Multi-dimensional Time Series LSTM
    LIU Yang, CHEN Sitong, XIANG Xingyun, SHEN Minghua, MA Tianshou
    2025, 47(5):  121-133.  DOI: 10.11885/j.issn.1674-5086.2024.01.08.01
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    In order to solve the problems of multiple factors, complex mechanism, nonlinear, strong coupling and other characteristics of rate of penetration in the process of complex deep drilling, this paper proposes a method of ROP prediction based on multi-dimensional time series long short-term memory neural network. Based on the actual logging data of Well X-1 in Xinjiang, this paper selects engineering parameters, hydraulics parameters, lithology parameters and other parameters as model inputs through the feature correlation analysis and the physical meaning of traditional ROP equation, and analyzes the ROP prediction effect of multi-dimensional features under different parameter combination modes. The results show that ROP is positively correlated with rotational speed, torque and riser pressure, but negatively correlated with vertical depth, hook load, specific weight on bit, drilling fluid conductivity, outlet drilling fluid temperature, outlet displacement and PDC drill ability, while weakly correlated with pump stroke and drilling fluid density; different characteristic parameter combinations have different prediction accuracy on ROP, among which the optimal parameter combinations are specific weight on bit, rotational speed, torque, hook load, riser pressure, drilling fluid conductivity, outlet drilling fluid temperature, outlet displacement, vertical depth and PDC drillability extreme value. MAE of ROP prediction is 0.30 m/h, MAPE is 11.35% and R2 is 0.93; The optimal hyperparameter combination scheme of the model was determined by orthogonal experiment. The R2 was increased by 0.06.
    Evaluation of Cementing Flushing Efficiency Based on the Same Wall Shear Rate
    FENG Yingtao, CUI Ce, WANG Youwei, HUANG Feng, YUAN Bin
    2025, 47(5):  134-142.  DOI: 10.11885/j.issn.1674-5086.2023.03.14.02
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    The flushing efficiency is a key index to evaluate the performance of flushing fluid, which directly affects the optimization, dosage, and then the cementing quality. However, the current evaluation methods for flushing efficiency are either at room temperature and pressure represented by the rotational viscometer method, and there is no process of water loss to form a mud cake, or there is little connection between the flushing speed of the device and the annulus displacement. To solve this problem, based on the principle of equal wall shear rate, the rotating speed model of the flushing efficiency evaluation device was established during mud cake formation and flushing, and the evaluation method of mud cake flushing efficiency under high temperature and high pressure was proposed. The method combines the flow of drilling fluid and flushing fluid in the well with the flow in the flushing efficiency evaluation device. The applicability analysis of high temperature and high pressure flushing efficiency evaluation method shows that the high temperature and high pressure flushing efficiency evaluation method has good repeatability, and the experimental results have high comparison, which can provide a basis for the optimization of flushing performance evaluation and application process parameters optimization. In addition, it is found that the flushing efficiency decreases with the increase of the formation time of mud cake water loss and the pressure difference, and increases quickly at first and then slowly with the increase of the flushing time and displacement.
    A Research on Internal Pressure Strength Calculation of Shut-in Casing for Overflow in High Pressure Gas Wells
    LI Yatian, LI Wenzhe, WANG Liuyang, WEN Chunyu, LI Runze
    2025, 47(5):  143-150.  DOI: 10.11885/j.issn.1674-5086.2023.02.01.03
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    During overflow shutdown in high-pressure gas wells, the rapid pressure changes within the wellbore cause an imbalance in casing stress distribution, significantly reducing its internal pressure resistance and increasing the risk of failure. To address the insufficient accuracy of existing methods in calculating the internal pressure resistance of shut-in casings, this paper proposes a toughness burst model for open-ended casings. The model was used to calculate the internal pressure resistance of a BG110SS grade casing with dimensions of 244.5 mm×13.8 mm. Concurrently, a finite element model of a casing-cement ring system incorporating cement ring constraints was established using 3D software to simulate the mechanical response of the casing under shut-in internal pressure loads. Comparison between the finite element simulation results and the calculations from the toughness burst model demonstrates that the proposed model achieves high computational accuracy and more realistically reflects the casing's internal pressure resistance. This provides a new scientific reference basis for determining the internal pressure resistance of casings under overflow shutdown conditions in high-pressure gas wells.
    An Experimental Study of Shear at the Bedrock-cover Contact Surface of a Clastic Accumulation
    QIU Enxi, ZHAO Jianjie, WAN Xusheng, WANG Zhishen, LIU Jun
    2025, 47(5):  151-165.  DOI: 10.11885/j.issn.1674-5086.2023.06.13.02
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    In the southeast Tibetan region, the stratigraphic lithology is complex, the clastic accumulation is widely distributed, and the base cover interface is mostly the potential slip surface of the slope of such accumulation, whose shear mechanical properties are the key factor to control the stability of the slope. To investigate the mechanical properties of the base cover interface of the accumulation, a 3-level indoor orthogonal direct shear experiment with 4 factors (rock content, joint roughness coefficient (JRC), water content, and bedrock softness) was conducted. The results show that the shear stress-shear displacement curve pattern of the soil-stone mixture-bedrock interface is dominated by plastic strain, but there is strain softening in the test curve with a JRC value of 18.7 at high vertical pressure, and the length of the strain softening phase is positively correlated with the size of the rock content. In addition, the shear stress-shear displacement curve is prone to the phenomenon of“stress jump”, which is mainly related to the block and bedrock embedded occlusion, block and bedrock fragmentation, block in the bedrock surface position adjustment; for the shear strength of soil-stone mixture-bedrock interface, the degree of bedrock softness and water content have the most significant degree of influence. The key factors affecting cohesion and internal friction angle are the degree of bedrock softness and water content, while the key factors affecting shear expansion are JRC and bedrock softness and hardness, and the key factors affecting shear contraction are rock content and water content.
    PETROLEUM MACHINERY AND OILFIELD CHEMISTRY
    An Experimental and Simulation Study on Material Erosion of Orifice Manifold at High Speed
    ZENG Jing, DENG Kuanhai, ZHOU Junping, LIU Bing, LIN Yuanhua
    2025, 47(5):  166-180.  DOI: 10.11885/j.issn.1674-5086.2023.09.18.02
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    High pressure difference, high flow rate and high sand content in throttling manifold of high pressure and high production gas wells make the problems of high speed gas-solid erosion wear especially prominent, and the failure of throttling manifold is frequent, which is easy to induce overflow, kick and blowout accidents, aggravating well control risks and bringing safety risks. Therefore, according to ASTM G76—2013, this paper adopts gas-solid nozzle erosion test method and air jet erosion test rig. The high speed (107 to 149 m/s) gas-solid nozzle erosion test of 30CrMo alloy steel was carried out under different inlet pressure (0.06 to 0.15 MPa) and impact angle (15° to 90°), and the erosion rate of 30CrMo alloy steel under different experimental conditions was obtained. The erosion rate equation of 30CrMo alloy steel suitable for high speed solid particle impact is established. Based on the results of erosion experiments, the optimal particle motion model for high speed compressible flow is constructed. Combined with discrete phase model and gas-solid two-phase coupling calculation method, a three-dimensional CFD erosion model of “reduced-tuber-nozzle-erosion cavity” was established. The erosion simulation of gas-solid nozzle of 30CrMo alloy steel, a throttling manifold material, was carried out at different impact angles and inlet pressure, and the distribution characteristics of flow field, particle movement trajectory, impact velocity distribution and slip characteristics were revealed. The accuracy and reliability of the simulation results are verified by the experimental results.
    Simulation of Corrosion in Sulfur-containing Venting Pipelines Considering Wall Liquid Phase Distribution
    PENG Xingyu, LIAO Yihong, XU Yibin, GONG Jianhua, SHEN Jun
    2025, 47(5):  181-194.  DOI: 10.11885/j.issn.1674-5086.2023.10.07.01
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    In order to carry out more accurately inspection of the venting pipeline of high sulfur natural gas field station, we use the CFD method to simulate the low-pressure venting pipeline with the combination of numerical simulation and on-site method, to deeply analyze the flow field distribution law, the liquid phase distribution law, and the distribution law of hydrogen sulfide in the different cross sections in the low-pressure venting pipeline, so as to predict the area of the low-pressure venting pipeline sensitive to internal corrosion, and to discuss the effect of changes of the distribution of the liquid phase at the wall surface on the internal corrosion of the high sulfur natural gas field station. The influence of liquid phase distribution changes on the wall surface on the internal corrosion of low-pressure vent pipelines in high sulfur natural gas stations was investigated. The results show that: the distribution of liquid phase in the venting pipeline of high sulfur natural gas station is the key factor leading to internal corrosion, and the 3～12～9 o'clock+6 o'clock directions of the 45° and 90° section of the second consecutive elbow at the entrance of the pipeline, as well as the 6～9 o'clock directions of the branch mouth at the tee, tend to be the most serious corrosion locations of the whole pipeline; when inspecting on-site, priority will be given to elbows and tees, and the wall thicknesses of the elbow and tee will be changed within the range of mild corrosion. If the wall thickness of these two places is within the range of mild corrosion, the detection of straight pipe section can be omitted. If the wall thickness at the tee varies beyond mild corrosion, the straight section should be tested primarily in the 6 o'clock direction. The results of the study effectively solved the problem of difficult to locate the internal corrosion position of the venting pipeline in high sulfur natural gas field station.