Operation Of Gas Pipelines Research Articles

Quantitative research on stress failure risk assessment for girth welds with unequal wall thickness of the X80 pipeline under lateral load

The cumulative length of the X80 steel pipeline extends to 17,000 km, with a predominant portion traversing mountainous terrains characterized by intricate geological formations. Recurrent geological hazards significantly impede the safe operation of oil and gas pipelines. Landslides can induce substantial axial forces on steel pipelines, significantly increasing the risk of pipeline failure. Moreover, as a result of sudden changes in mechanical structure, the pipeline's unequal wall thickness leads to local stress concentration, making it more vulnerable to external loads than the steel pipeline itself. Therefore, to analyze the mechanical response of steel pipelines under different working conditions, we establish a smooth particle hydrodynamics, finite element transverse landslide pipeline model for girth welds with unequal wall thickness and investigate a tearing accident caused by a lateral landslide in a section of the large-diameter natural gas pipeline. The landslide volume is found to be the main controlling factor for the failure of pipeline circumferential welds. According to the genetic algorithm backpropagation neural network, the von Mises stress of the most dangerous section of the pipeline is calculated based on pipeline and landslide parameters, and the error is 11.67 %. According to the API RP 581–2016 Risk-Based Inspection Methodology, a failure risk assessment matrix is established using the pipeline statute as an evaluation indicator to evaluate the landslide risk to pipelines in different regions. A variable-wall-thickness girth weld on the ZG pipeline was selected for application. This method has good applicability for evaluating the failure risk of circumferential welds with wall thicknesses of 12.8/15.3 mm under the action of small landslides.

Modeling Pipe to Soil Potentials From Geomagnetic Storms in Gas Pipelines in New Zealand

AbstractGas pipelines can experience elevated pipe to soil potentials (PSPs) during geomagnetic disturbances due to the induced geoelectric field. Gas pipeline operators use cathodic protection to keep PSPs between −0.85 and −1.2 V to prevent corrosion of the steel pipes and disbondment of the protective coating from the pipes. We have developed a model of the gas pipelines in the North Island of New Zealand to identify whether a hazard exists to these pipelines and how big this hazard is. We used a transmission line representation to model the pipelines and a nodal admittance matrix method to calculate the PSPs at nodes up to 5 km apart along the pipelines. We used this model to calculate PSPs resulting from an idealized 100 mVkm−1 electric field, initially to the north and east. The calculated PSPs are highest are at the ends of the pipelines in the direction of the applied electric field vector. The calculated PSP follows a characteristic curve along the length of the pipelines that matches theory, with deviations due to branchlines and changes in pipeline direction. The modeling shows that the PSP magnitudes are sensitive to the branchline coating conductance with higher coating conductances decreasing the PSPs at most locations. Enhanced PSPs produce the highest risk of disbondment and corrosion occurring, and hence this modeling provides insights into the network locations most at risk.

Comprehensive analysis of the performance of welding joints of gas pipelines with different viscosities

Full-scale tests of gas pipelines with different viscosities were carried out in landfill conditions, which are as close as possible to the natural conditions of operation of gas pipelines. The kinetics of crack propagation along welded joints - their trajectory, the transition from the weld seam to the base metal of the pipe and vice versa, the speed of movement of cracks in viscous and brittle metal and defined zones of plastic deformation - were experimentally investigated. It is known that tests on Menaget, Charpy and other samples, which have thicknesses that do not correspond to the thickness of the pipe walls, do not reflect the real picture of visco-plastic and brittle fractures, which does not allow to develop a methodology or model for predicting the final resource (non-accident) of long-term gas pipelines period of operation. At the same time, theoretical and laboratory researches do not always adequately answer the questions directly related to ensuring the durability and trouble-free operation of pipelines. It is likely that in the laboratory conditions of enterprises or scientific institutions it is difficult to reproduce and take into account all the factors that characterize the growth and spread of destruction in a real operating gas pipeline. Therefore, the data of laboratory studies must be checked and necessarily clarified according to the results of pneumatic tests of long pipe sections, i.e., at present, the need to combine laboratory and field tests of pipes of the gas pipeline network is urgently needed. Such tests are not massive, but as a result of their performance, important information is obtained regarding the behavior and properties of the metal in the conditions of loading and operation, which are closest to operational conditions. In field tests, pipes with a diameter of 1000x18 mm were used, which underwent controlled rolling (steel class X70 - grade 06G2BA) at a working pressure of RR = 9.7 MPa (in the northern - low-temperature version). Tensile tests, studies of impact toughness, strength and plasticity of the weld metal were carried out according to standard methods described in works [2-5]. During the experiments, a large number of sensors of temperature, pressure, strain, stress, crack propagation speed, etc. were used. The obtained results regarding the kinetics of the destruction of natural pipes in landfill conditions lay the groundwork for the development of a mathematical model of the engineering forecast of the residual (non-accident) resource of pipelines operating in oil and gas fields.

Technological Aspects of Methane–Hydrogen Mixture Transportation through Operating Gas Pipelines Considering Industrial and Fire Safety

Pipeline transportation is widely regarded as the most cost-effective method for conveying substantial volumes of hydrogen across extensive distances. However, before hydrogen can be widely used, a new pipeline network must be built to reliably supply industrial users. An alternative way to rather expensive investments in new infrastructure could be to use the existing pipeline network to add pure hydrogen to natural gas and further transport the gas mixture in an industrially safe way. The new solution necessities will be examined for compression, transportation, and fire hazard accidents, which have not been scrutinized by other scholars. This study presents the results of a comprehensive analysis of the methane–hydrogen mixture compression process and a mathematical description of the main pipeline operation during gas mixture transportation, considering industrial fire safety issues. By examining a case study involving a main gas pipeline and its associated mathematical model for hydrogen transportation, it becomes feasible to assess the potential hazards associated with various leakage areas and the subsequent occurrence of fires. The findings of this investigation demonstrate that the spontaneous combustion of hydrogen due to leakage from a natural gas pipeline is directly influenced by the proportion of hydrogen present in the gas mixture. If the hydrogen percentage reaches a balanced ratio of 50–50%, it is plausible that the equipment at the compressor station could be subject to detrimental consequences, potentially leading to accidents and fires. Furthermore, the obtained results from modeling in ANSYS Fluent software propose two practical scenarios, which demonstrate that despite the limited research conducted on the safety aspects and the occurrence of fires during the operation of hydrogen gas pipelines, industrial and fire safety necessitate the inclusion of hydrogen transport infrastructure as a pivotal element within the broader framework of hydrogen infrastructure development.

Experimental study and chemical affinity model on the inhibition of CO2 gas hydrate formation

Natural gas and water can form complex cage crystals in oil and gas pipelines under certain conditions. The natural gas hydrate formed after crystal clustering can block the pipeline and affect the operation efficiency of the pipeline, and even cause equipment damage, bringing economic and security problems to enterprises. In the present study, we experimentally investigated the inhibition of CO2 formation hydrate using attapulgite (ATP) and glucose (GLC). The kinetic influence on the formation of CO2 hydrate by the complex pairing of kinetic inhibitor ATP is conducted under the working conditions of 277.15 K and 3.5 MPa. The effect of compound inhibitors on the temperature and pressure conditions, growth process and gas consumption of hydrate formation are revealed. The chemical affinity model of CO2 hydrate formation under a compound inhibitor system is derived and established based on experimental studies. The results show that the combination of GLC and ATP can inhibit the formation of CO2 hydrate to varying degrees, prolong the induction time of hydrate, and reduce the consumption of CO2. The optimized experimental studies demonstrate that the best inhibitory compound system is 15 mg/mL GLC + 1.00 mg/mL ATP. Compared with the pure water system and single 15 mg/mL GLC system, the induction time is extended by 122.61% and 122.23%, while the gas consumption is reduced by 23.72% and 3.41%. The results provide new ideas and methods for the prediction of hydrate formation in the compound inhibitor system for the safe operation of oil and gas pipelines.

Experimental study on the mechanical behavior of buried steel pipeline subjected to the local subsidence

Localized subsidence of soil layer is a typical geological disaster for buried long-distance oil and gas pipelines, which seriously threatens the safe operation of oil and gas pipelines. Therefore, a series of large-scale model tests are performed to investigate the mechanical response of the buried pipe induced by surrounding soil when the localized soil layer sinks. Results indicate that the subsidence height has a relatively greater impact on pipe strain and soil pressure than the subsidence range. Moreover, the distribution of the pipeline strain presents obvious regional characteristics and is divided into subsidence regions, non-subsidence affected regions, and non-subsidence unaffected regions. With the increasing moisture content of the backfill, the strain of the pipeline and the earth pressure around the pipe was reduced. In addition, the modified Marston earth pressure formula is proposed to estimate the vertical earth pressure on the top of the pipeline. The vertical earth pressure calculated using the proposed method fits well with the test results.

CFD-DPM modelling of solid particle erosion on weld reinforcement height in liquid-solid high shear flows

Liquid-solid two-phase flow erosion can lead to great economic losses and safety concerns in the oil & gas storage and transportation industry. The solid particle erosion on weld reinforcement height (WRH) in liquid-solid high shear flows were systematically investigated by coupling the computational fluid dynamics (CFD) and the discrete phase model (DPM) method. The effects of liquid velocity, WRH height, particle flow rate, and particle size on the particle erosion in the WRH region were analyzed. Increasing erosion rate was observed with increasing liquid velocity. The erosion rate first increased and then decreased with increasing WRH height. The increasing erosion rate was observed with both increasing particle flow rates and particle sizes. The existence of defects on the WRH surface significantly increased the maximum erosion rates. This work can provide scientific guidelines for the corrosion protection and safe operation of long-distance oil & gas pipelines.

Study on prediction model of liquid holdup based on back propagation neural network optimized by tuna swarm algorithm

ABSTRACT It is unavoidable that there will be liquid accumulation in the low-lying areas of the pipelines during the operation of wet gas pipelines. The existence of liquid accumulation can generate a variety of safety issues and, in extreme circumstances, accidents. The accurate calculation of liquid holdup in gas-liquid two-phase flow is of great significance for the study of flow pattern identification, pressure drop calculation, pigging cycle determination, hydrate prediction, wax deposition prediction, pipeline corrosion evaluation and prediction, and transportation efficiency calculation of gas pipelines. Therefore, it is crucial to predict the liquid holdup of wet gas pipelines. 2141 independent experimental data samples were collected and screened out from literatures. Based on the gray theory, gray relation analysis was carried out on the influencing factors of liquid holdup, and the factors with greater influence were selected as the influencing variables; the liquid holdup prediction model based on tuna swarm algorithm optimized BP neural network was established, with pipe diameter, inclination angle, apparent gas velocity, apparent liquid velocity, average temperature, average pressure, and liquid viscosity as input parameters, and liquid holdup as output parameter. Liquid holdup was predicted for upward inclined, downward inclined, and horizontal pipelines respectively. The results show that the prediction model of liquid holdup established in this paper has high accuracy, with the MAPE value of 5.3223%, RMSE value of 0.0213, and R 2 value of 0.9924 for upward inclined pipelines; the MAPE value of 10.1859%, RMSE value of 0.0174, and R 2 value of 0.9922 for downward inclined pipelines; the MAPE value of 4.8037%, RMSE value of 0.0113, and R 2 value of 0.9974 for horizontal pipelines. The predicted results are generally stable and have a wider scope of application, providing a new idea and approach for predicting the liquid holdup of wet gas pipelines.

Правовые аспекты обеспечения прав титульного владельца газопровода при выполнении работ на чужих земельных участках

This article is dedicated to a complex study of the issues of protection of rights of title gas pipeline holders (gas pipeline owners and gas pipeline operating companies) in performance of engineering works on gas transmission network sections located within the boundaries of land plots owned by others. Considering the special nature of a gas transmission network as a source of increased danger and a hazardous industrial facility, the author believes that one of the priority areas of gas pipeline operation is regular diagnostics and maintenance as well as in-process current (emergency) repair performed to avoid any breakdowns of the normal operation mode of the gas transmission network and causing of damage to lives, health and property of third parties. Taking into account these circumstances and the specifics of legal regulation of gas pipeline operation, the author of the article singles out the legal problem that lies in the ambiguity of approaches to the solution of the issue of provision of the title gas pipeline holder with access to the operated section of the gas transmission network if such facility is located within the boundaries of a land plot not owned by the gas pipeline holder. In order to solve this problem, the author performs a systemic analysis of the applicable laws of the Russian Federation and the legislative practice of some foreign countries and singles out three key concepts of provision of access to a gas pipeline located at a land plot owned by another person; such concepts include an opportunity to establish private or public easement and imperative proclamation of the unconditional right of the gas pipeline holder to unrestricted access to any section of the operated gas transmission network irrespective of the ownership of land plots such sites are located at. The author gives a systemic evaluation of each of the mentioned conceptual approaches; based on such evaluation, the author brings forward recommendations for improvement of the applicable laws to comply with the proclaimed principle of ensuring energy security of the Russian Federation.

MAGNETIC-PULSED TREATMENT TO IMPROVE THE STRENGTH PROPERTIES OF DEFECTIVE SECTIONS OF OIL AND GAS PIPELINES

Link for citation: Schipachev A.M., Mohammed Aljadly. Magnetic-pulse treatment to improve the strength properties of defective sections of oil and gas pipelines. Bulletin of the Tomsk Polytechnic University. Geo Аssets Engineering, 2023, vol. 334, no. 5, рр.7-16.In Rus. The relevance. During the operation of oil and gas pipelines, continuity defects (including point and linear defects such as delamination, cracks of various nature, etc.) occur in their structure. The peculiarity of material continuity defects is caused by the fact that in the process of loading the defects cause stress concentration near their tops, which leads to a rapid increase in their number and geometric dimensions, followed by the merging of the latter and the formation of large discontinuities, and as a consequence, the strength properties of pipelines decrease. Consequently, early detection of metal continuity defects and their elimination before they reach a critical size are urgent tasks. The solution of which will significantly improve the operational and strength properties of the working elements of pipelines and extend their lifespan. The main aim of the research is to study the effectiveness of magnetic-pulse treatment to improve the strength properties of used oil and gas pipelines by reducing the defects size. Objects: defective sections of main oil and gas pipelines. Methods: magnetic pulse treatment of samples on a magnetic-pulse unit MPU-10-SSAU 10, determination of temperature changes caused by magnetic-pulse treatment, testing samples for impact strength on a pendulum-testing machine, comparison of the obtained results for treated and untreated samples, determination of the effect of magnetic-pulse treatment on the strength properties of gas pipeline metal, study of the fracture surface of samples after impact tests. Results. It was established experimentally that the impact strength of the treated samples increased by 14 % compared to the untreated samples. Snapshots of the temperature distribution during the magnetic-pulse treatment showed a significant increase in temperature near the crack tips. It was found that destruction of the metal subjected to magnetic-pulse action acquired more viscous character.

Deeppipe: Theory-guided prediction method based automatic machine learning for maximum pitting corrosion depth of oil and gas pipeline

Accurate monitoring of pipeline corrosion is important and necessary not only for the normal operation of oil and gas pipelines but also for the reliable and stable supply of energy. To avoid failures of buried steel pipelines, the precise prediction of maximum pitting corrosion depth should be conducted to prevent accidents. In this paper, an automatic machine learning (AML) based approach is developed to automate the construction of corrosion depth prediction model. The engineering theory and domain knowledge are integrated into feature engineering, which is an important part of the machine learning (ML) modeling process, to overcome the drawback of the conventional modeling method of ML. Subsequently, a novel prediction method, so-called theory-guided AML (Tg-AML) is proposed for the maximum depth prediction of pitting corrosion pipeline. Firstly, several new feature variables are constructed based on the corrosion mechanism (empirical model and interaction between input variables). Then, seven different feature subsets are developed based on correlation analysis. To select the suitable feature subset and verify the superiority of Tg-AML, a real-world pitting corrosion dataset is utilized for performance comparison based on evaluation metrics. After acquiring the suitable feature subset, the maximum pitting corrosion depth prediction model that fits the data and is guided by both engineering theory and domain knowledge is established. The results indicate that the proposed model achieves better accuracy and efficiency than other models, such as neural network, and decision tree, with root mean square error (RMSE) being 0.288, mean absolute error (MAE) being 0.174, confidence index (Cl) being 0.933.

Leak Detection in Natural Gas Pipelines Based on Unsupervised Reconstruction of Healthy Flow Data

Summary Timely detection of leak accidents plays an essential role in the safe operation and risk assessment of natural gas pipelines. However, the scarce leak data and complex operating conditions lead to small samples, data imbalance, and problems with confusing operating conditions. The reliance on leak data limits the recognition performance of the artificial intelligence classification method for leakage operating conditions. A leak detection method based on the unsupervised reconstruction of healthy flow data is established to address these problems. First, an unsupervised neural network is established to reconstruct healthy flow data from real natural gas pipelines. And a model update strategy based on active learning is designed to improve the model’s adaptability for time-varying pipelines. Next, a dynamic alarm threshold strategy that accounts for the knowledge of the experience and statistical characteristics of the data segments is suggested to prevent false alarms caused by ambiguous operating conditions. Finally, unlike most recent work that only considers simulated data or laboratory data, this paper conducts a leak case study on an actual natural gas pipeline in service to improve the robustness of the proposed method in the actual operating environment. The findings of this paper can be used as a reference to analyze pipeline behavior analysis based on pipeline flow trend characteristics and early alarm management.

BI-IEnKF coupling model for effective source term estimation of natural gas leakage in urban utility tunnels

As an effective way to facilitate the increasing demand for reliable infrastructure, energy supply and sustainable urban development, underground utility tunnels have been developed rapidly in recent years. Due to the widespread distribution of utility tunnels, the safe operation of natural gas pipelines accommodated in utility tunnels has caused great concern considering fire, explosion, and other coupling consequences induced by the gas pipeline leakage. However, the limited information on leakage source terms in accidental leakage scenarios could preclude timely consequence assessment and effective emergency response. In this study, a BI-IEnKF coupling source term estimation (STE) model is developed, with the combination of gas dispersion model, Bayesian inference (BI) and iterative ensemble Kalman filter (IEnKF) method, to achieve the effective source term estimation (including leakage location and leakage rate) and gas concentration distribution prediction. The newly developed model is first evaluated by the twin experiment with good reliability and accuracy. Furthermore, three contributing factors affecting the performance of the developed BI-IEnKF coupling STE model were investigated to assist parameter selection for practical use. Additionally, the novel application of mobile sensors serving as an alternative for fixed sensors is explored, and an application framework is sequentially given to guide the deployment of the developed coupling model in utility tunnels. The results show that the developed model has great performance in accuracy, efficiency and robustness, as well as the potential to be applied in actual utility tunnel scenarios. This study can provide technical supports for safety control and emergency response in the case of natural gas pipeline leakage accidents in utility tunnels. Also, it could be helpful to reasonable references for gas lekage monitoring system design.

Phase transformations in pipeline gas transportation and methods to prevent emerging complications

The current methods for prevention of problems in gas gathering, field preparation and transportation systems, as a rule, do not consider the joint effect of such processes as gas flow in the pipeline in case of phase transitions, accumulation of liquid in the pipeline cavity, heat exchange of the pipeline with the surrounding environment. The studies assessed the barodynamic factors and the component composition of gas, affecting hydrate formation, taking into account the complex effect of the processes involved in the operation of gas pipelines. The technological solution for gas pipeline cleaning by specially developed polymeric gel composition is proposed.

Risk assessment of oil and gas pipelines hot work based on AHP-FCE

A new quantitative risk assessment method for hot work is proposed based on the Analytic Hierarchy Process (AHP) and Fuzzy Comprehensive Evaluation (FCE). It can help pipeline companies realize the risk management of hot work and further ensure the safe operation of oil and gas pipelines. Taking one natural gas pipeline in China as an example, this paper evaluates the risk of a single hot work in the spring of one natural gas pipeline in a high consequence region. First of all, the risk factors are determined with reference to the job safety analysis (JSA), and then experts were invited to fill out a questionnaire to collect their opinions. According to the results of the questionnaire, AHP is used to calculate the weight coefficients of the evaluation indicators, and FCE is used to evaluate the risk level of hot work. After calculation, the comprehensive risk score of hot work is 40.888. It belongs to a "General risk". This method can not only quantitatively evaluate the risk levels of hot work, but also reasonably sort the importance of various risk factors. It is helpful for the effective management of hot work and provides suggestions for implementing control measures.

Constrained exact boundary controllability of a semilinear model for pipeline gas flow

AbstractWhile the quasilinear isothermal Euler equations are an excellent model for gas pipeline flow, the operation of the pipeline flow with high pressure and small Mach numbers allows us to obtain approximate solutions by a simpler semilinear model. We provide a derivation of the semilinear model that shows that the semilinear model is valid for sufficiently low Mach numbers and sufficiently high pressures. We prove an existence result for continuous solutions of the semilinear model that takes into account lower and upper bounds for the pressure and an upper bound for the magnitude of the Mach number of the gas flow. These state constraints are important both in the operation of gas pipelines and to guarantee that the solution remains in the set where the model is physically valid. We show the constrained exact boundary controllability of the system with the same pressure and Mach number constraints.

Study of static charge accumulation in HDPE gas pipelines

The accumulation of static charge in polyethylene pipes of gas network systems is a familiar process, which is paid attention to mainly to prevent accidents on pipelines. incidents related to static electricity can occur both during assembly works (coil tapping) and during the operation of gas pipelines (gas venting, etc.). Despite the fact that repeated attempts to study this process have been made by major operating organizations, today we can state that these regularities have not been studied in full. In this work we have made an attempt to describe theoretically the process of static charge accumulation on a pipe body, as well as to evaluate experimentally the adequacy of the proposed models.

Calculation of gas supply pressure using plastic pipes for preventing accidental emissions

Technological (production, operational and repair) risks come to the fore, minimizing which requires optimization of the work of structural units responsible for a reasonable assessment of the technical condition, maintenance and repair of facilities, timely renewal of production facilities with minimization of wear and tear of equipment, which is a risk factor in the failure of the gas transmission system. In addition, based on the noted features of gas transportation enterprises, in the risk management block, logistics risks, safety risks, environmental, social and (in a certain aspect) financial risks should play a significant role. Objectively, in order to establish an acceptable range of risks, it is necessary to collect statistical data on the occurrence of risk factors for the foreseeable period in order to leave for constant monitoring those risk factors that appear regularly in the gas transmission system. The construction and operation of gas pipelines play an important role in the reasonable and technical transportation of gaseous substances. Noteworthy, algorithm for calculating the proposed medium pressure gas pipeline was developed, accordingly, in this research, the gas flow area was determined. The results showed that based on the calculations of underground average pressure of polyethylene pipes, the average gas pressure was 5,733 Pa, withstands pressure was up to 8009.7 Pa, withstands stress on the pipe wall was up to 0.024 MPa, and emission loss was 3964.4 m3 when there was an accident.

Failure analysis and control of natural gas pipelines under excavation impact based on machine learning scheme

Third-party excavation operations pose a serious threat to the safe operation of natural gas pipelines, and quantifying the failure conditions of pipelines can effectively identify the hazards of excavation operations. Considering the current lack of test data on the full-size critical conditions of pipelines under different failure modes, to make the research results have better field application, this study aims to develop a failure prediction model, which is adopted for predicting the failure modes of the pipeline under different excavation conditions in order to propose control strategies. In this work, finite element analysis is combined with machine learning algorithms. The finite element analysis process derives the critical loads for different failure modes of the pipe and establishes the failure condition data set. Correlation analysis and sensitivity analysis were employed to investigate the influence pattern of the features. The prediction performance of different machine learning combination algorithms was tested, and a hybrid data-driven prediction model was established and combined with the excavation equipment parameters to determine the risk level of the excavation equipment and the risk area of the operation. The results demonstrate that the critical load value for failure grows when the strength of the pipe increases. The four features of yield strength, strength limit, pipe diameter, and wall thickness exhibit the highest importance scores. The bucket tooth wedge angle only influences the magnitude of the puncture critical load, with correlation and sensitivity coefficients being 0.315 and 0.116, respectively. In the test of the combined algorithm, the RFECV-CSVR-NSGAIII algorithm built in this study has the highest generalization performance, the mean absolute error percentage (MAPE) is lower than 0.0476, the coefficient of determination R2 reaches over 0.9960, and the prediction model has excellent accuracy. The prediction model was subjected to case studies to obtain rapid identification of risk levels and operational risk areas of excavation equipment.

Legal regulation of the operation of oil and gas pipelines

The relevance of the chosen topic of the article is due to the lack of scientific research in the field of legal regulation of the operation of oil and gas pipelines. The article states that the legislation of the Russian Federation does not provide the concept of oil and gas pipelines. In the course of the study, the features of pipelines were identified and analyzed, which made it possible to give an appropriate legal definition of oil and gas pipelines. Also, the classification of pipelines was carried out in order to determine the place of oil and gas pipelines in the system of legal regulation. Taking into account the above pipelines classifications, an analysis of regulatory sources containing norms governing the operation of oil and gas fields was carried out, as a result of which their imperfection and insufficiency in relation to field and on-site pipelines was ascertained.