Gas Gathering System Research Articles

The erosion rate prediction for the elbow in shale gas gathering and transportation system: RSM and GA-BP-ANN modeling

Elbow erosion caused by sand mixed in shale gas is a significant issue faced by shale gas gathering and transportation systems, posing a serious threat to the safe and stable production of shale gas. In this paper, the factors affecting elbow erosion in the shale gas gathering and transportation system are identified. The computational fluid dynamics (CFD) two-way coupling Euler-Lagrange method is used to investigate the single-action of various parameters on particle trajectory, erosion morphology, and maximum erosion rate, including pipe inner diameter, pipe R/D ratio, pipe bending angle, pipe bending orientation, solid particle velocity, solid particle size, and solid particle mass flow rate. Subsequently, the response surface methodology (RSM) is employed to quantitatively explore the synergistic interactions between these factors that affect the maximum erosion rate of the elbow, and a surrogate model for simple and rapid evaluation of the maximum erosion rate for elbows at the engineering level is proposed. Finally, the backpropagation artificial neural network (BP-ANN) optimized by genetic algorithm (GA) is used to train the samples obtained by Latin hypercube sampling (LHS) in the multi-factor range. By comparison, the RSM surrogate model and the GA-BP-ANN model reveal a favorable level of agreement with the experimental data, while considering various influential factors. It is important to note that each method possesses distinct advantages, limitations, and specific application environments. This research can provide quantitative references for preventing and controlling erosion within the shale gas gathering and transportation system.

A Multi-Period Model of Compressor Scheme Optimization for the Shale Gas Gathering and Transportation System

In the process of shale gas production, with the change in gas productive parameters, the pressurization demand for the shale gas gathering and transportation system (SGGTS) also changes, which affects the choice of pressurizing location and timing. Our purpose is to effectively respond to the impact of parameter changes during shale gas production and to better select the pressurization schemes. Therefore, we considered the modularization of the compressors and established a mixed-integer nonlinear programming (MINLP) model to minimize the total cost of the SGGTS. Taking an actual shale gas field as an example, by discretizing the time during a given production period to solve the model under multi-period and single-period conditions, the optimal pressurization scheme for the SGGTS in the specified production period is obtained. It indicates that the results obtained under a multi-period condition are more conducive to actual production. Compared with the results obtained under the single-period condition, the cumulative cost obtained in the multi-period condition is reduced by 17.19%. By deploying the MINLP model in the specified production period, the pressurization demand is met in each time period. This greatly improves the utilization rate of modular compressors, reduces the total cost, and improves the economic benefits of the SGGTS.

Application and prospects of multi-phase pipeline simulation technology in empowering the intelligent oil and gas fields

This paper reviews the application of multiphase flow simulation technology for constructing intelligent oil and gas fields. By utilizing the theoretical multiphase flow simulation model and solution algorithm, the practical engineering application of this technology in various oil and gas gathering and transportation system scenarios, including subsea production systems in offshore oil and gas fields, well site gathering and transportation production systems in onshore gas fields, and platform gathering and transportation production systems, was assessed and described. In addition, the role of multiphase flow simulation technology in intelligent oilfield surface production was discussed from the perspective of surface oil and gas pipeline networks and intelligent oilfield operations. Moreover, the future development prospects of multiphase pipeline transport simulation technology were proposed, providing a reference for improving related research and constructing intelligent oilfields.

Numerical simulation of solid particle erosion in the gas-liquid flow of key pipe fittings in shale gas fields

Erosion caused by solid particles is one of the important reasons for the failure of shale gas gathering pipelines. However, the erosion laws of right-angle pipe and blind tee were rarely compared in previous studies, and the parameter settings almost did not meet the actual requirements of shale gas exploitation. The aim of this paper is to study the erosion laws of 90° elbow, right-angle pipe and blind tee based on the production parameters of a gas field. CFD-DPM approach integrates the Mixture model, the Discrete Phase Model, and an erosion model is employed to predict solid particle erosion in gas-liquid two-phase flow in the shale gas field. The results show that the maximum erosion rate of pipe wall increases exponentially with the fluid velocity. With the development of mining, the lower the free water content, the more serious the pipe wall erosion. In addition, under the same working conditions, the blind tee is relatively erosion-resistant compared with 90° elbow and right-angle pipe. The shale gas gathering and transmission system can use blind tees to connect pipes and limit fluid velocity, so as to prolong service life and ensure flow safety.

A Process Simulation Model of Oil and Gas Gathering System for Digital Requirements

A Process Simulation Model of Oil and Gas Gathering System for Digital Requirements

An optimization method for shale gas gathering system - Consideration of reliability enhancement under earthquake-related uncertainties

Shale gas gathering systems are of great importance in gas fields for the efficient and reliable transportation of gas. In traditional design methods, pipeline layouts are optimized only from an economic point of view, where reliability is evaluated after optimization. However, reliability can be enhanced by spare pipelines so that both economic and reliable aspects are evaluated simultaneously. Based on the idea of enhancing reliability, this research proposes a methodology for optimizing the pipeline layout problem including well clustering, stations site selecting, and piping. Different topology arrangements and spare pipelines are investigated to enhance the production efficiency and reliability of the pipeline network under earthquake-related uncertainties. Reliability evaluation is converted into an economic one so that the objective of this work is to minimize the total annual cost. To solve such a complex problem, genetic algorithm, K-means algorithm, GeoSteiner algorithm, Kruskal algorithm, linear programming and Monte Carlo simulations are combined. A real-world case study illustrates the effectiveness of the proposed methodology and shows a 36.53% reduction in the total annual cost compared with the initial scheme. • This work optimizes both network topology and the implementation of spare pipelines to enhance reliability. • A two-level pipeline network with four kinds of topologies is optimized. • The proposed model considers the hydraulic characteristics of pipeline networks under uncertainties. • Practical large-scale problem can be solved through the proposed methodology.

Experimental investigation of maldistribution characteristics of gas‐liquid two-phase flow in a horizontal pipeline

In the flow distribution of oil and gas gathering and transportation system, the flow pattern, inertia force, gravity, and other factors will lead to uneven flow distribution of each outlet pipe, which will seriously affect the economy and safety of the gathering and transportation system. Therefore, it is of great significance to analyze the characteristics of gas–liquid two-phase flow in horizontal pipelines. For this reason, an experimental device for maldistribution control of gas–liquid two-phase flow is developed in this article. In order to solve the problem of flow maldistribution in gas–liquid two-phase flow pipe, the test experiments of maldistribution control under the conditions of three flow patterns (stratified flow, slug flow, and annular flow) are carried out. Through experiments, we revealed the control law of flow pattern to liquid maldistribution and gas maldistribution with or without flute pipes and formed the maldistribution control scheme of gas–liquid two-phase flow in the horizontal pipeline. It is found that it is more beneficial to the control of average liquid maldistribution degree under the condition of slug flow pattern in horizontal manifold without flute pipe, and it is more beneficial to the control of average gas maldistribution degree under the condition of annular flow pattern without flute pipe. Without the function of the flute pipe and in the annular flow pattern, it is beneficial to the control of average maldistribution degree of gas–liquid two-phase flow. The findings of this research can be used as a reference for the field maldistribution control of oil and gas gathering and transportation systems.

Characteristics of liquid loading with surfactant injection in hilly terrain pipeline

Surfactant injection technology has recently been proposed as an alternative to mechanical pigging for liquid unloading from the wellhead to the surface gas gathering system. This study aimed to verify the effectiveness of the technology by experimentally evaluating the liquid loading characteristics of gas–liquid flow with a surfactant at the undeveloped and developed flow positions of the uphill test section (10°) of a hilly terrain pipeline. The inner diameter and length of the uphill test section were 50.0 mm and 16.0 m, respectively. The liquid and gas working fluids were deionized water or 250 ppm sodium dodecyl sulfate (SDS) surfactant solution and air with the superficial velocities of 0.001 to 0.010 m/s and 2.0 to 14.0 m/s. The liquid volume fraction and liquid holdup were measured using the image-quick closing valve method and wire mesh sensor method, respectively, and the liquid holdup data were visualized using the MATLAB program and Tecplot software. Owing to the effect of the surfactant, the flow range of low liquid loading increased significantly with the flow regime transition from intermittent flow to segregated flow. Because of the complex interaction between the morphology of the slug body and the foam formation, the fluctuation range and peak of liquid holdup and the liquid volume fraction decreased significantly in the intermittent flow. The liquid holdup fluctuation range and liquid volume fraction decreased to nearly zero, and a foam layer was formed and climbed up along the pipe wall in the segregated flow. The results and analyses are beneficial for improving the surfactant injection scheme and establishing a prediction model.

A MINLP model for combination pressurization optimization of shale gas gathering system

The combination pressurization of the shale gas gathering system is one of the most common pressurization methods in the current engineering site, but it is mostly set by manual experience or simulation analysis, and thus the optimal pressurization scheme cannot be obtained. In order to optimize the pressurization mode of the shale gas gathering and transportation system, a mixed integer nonlinear programming model (MINLP) is established based on the existing pressurization mode of the shale gas field. The model takes the minimum total cost of the compressor unit as the objective function. Various constraints are also taken into account, such as pipe pressure, flowrate, compressor related, well and platform throttling, uniqueness for well and platform pressurization. Solving this optimization model can figure out the appropriate pressurization position, operating power, and compressor unit cost. An actual case for a shale gas block is applied to determine the combined pressurization scheme suitable for this production condition. The results show that the combination of more pressurization methods can meet the pressurization requirements under different production conditions. When both well and platform pressurization are considered, the optimized pressurization position is more concentrated, the number of compressors is reduced by two sets, and the total compressor cost is reduced by 99.28 × 104 Yuan, which reflects the advantages of combined pressurization in the pressurization of shale gas gathering and transportation systems.

Integral Layout Optimization of Subsea Production Control System Considering Three-Dimensional Space Constraint

The subsea production control system, characterized by a complex and diverse structure and high cost, is one of the essential parts of a subsea production system. The rational layout of the subsea production control system is essential to reduce development costs and ensure safe production in offshore fields. Most previous studies on layout design in offshore fields have focused on the oil- and gas-gathering system. However, the layout of the subsea production control system has not thoroughly been researched to date and the seabed terrain and integral optimization have rarely been discussed. This paper focuses on the multi-layer star structure and multi-layer star-tree structure, two common layout structures of subsea production control systems, and establishes the corresponding model with obstacle and seabed terrain conditions. Obtaining the lowest possible total cost was the aim of the model. A hybrid algorithm combining the adaptive mutation particle swarm algorithm and the A-star algorithm was applied to integrally optimize the subsea distribution unit and umbilical touch down point positions, the pipe connection topology and pipe routes. The practicality of this approach is demonstrated by designing a layout with one FPSO and 22 subsea control modules. The results indicate that the multi-layer star-tree layout structure has a lower total cost compared to that of the multi-layer star layout structure. In addition, the results were compared with a case that ignores the seabed terrain, indicating differences in the total construction cost. This method provides engineers with quantitative references and reliable cost estimates to make decisions regarding the layout of the subsea production control system.

Pyrolysis behavior of coal in a moving bed with baffled internals under different residence times

In view of the problems faced by a conventional moving bed coal pyrolysis process, such as the inability to deal with pulverized coal, low light tar yield, poor tar quality, etc., a moving bed pyrolysis process with baffled internals was developed to control heat and mass transfer of the gas-solid two-phase and the pyrolysis reaction process. The multi-stage gas gathering system can collect the oil and gas products released in different pyrolysis stages of coal in time. The pyrolysis behavior and product quality of Naomaohu coal at different temperatures and residence times were investigated. The results show that the baffle internals enhance heat and volatile matter transfer among particles, enabling it to process 0.4–6.0 mm pulverized coal. When pyrolysis temperature is 550°C and residence time is 3.0h, the pyrolysis tar yield reaches the highest 11.38%, which is 86.87% of the Gray-King assay yield, and the mass fraction of light components below 360°C in the tar fraction is 85.0%. With the extension of the residence time, the H2 volume fraction in the pyrolysis gas increases from 22.1% to 35.1%, and the CO volume fraction increases from 8.0% to 9.5%. Tar yield in the first and second layer reactors increases with increasing residence time, and the tar yield in the third and fourth layer reactors isobtained when the residence time is 2.0 h. As the number of beds increases, content of light components in the tar simulated distillation fraction increases; content of tar aliphatic hydrocarbon compounds decreases, and that of monocyclic aromatic hydrocarbons and bicyclic aromatic hydrocarbons gradually increases. Based on the above results, it provides technical support for large-scale industrial processing of small particle size pulverized coal, and preparation of higher yield and quality tar.

Instantaneous gas flow rate estimation in the gas-gathering system flowline by indirect measurement method

Implementation of modern automation systems on the northern gas fields located at the final stage of operation, is unprofitable economically and is not always possible technically. At the same time, the competent operation of such deposits requires constant monitoring for the state of gas wells and the shelves of the gas transmission network. In particular, the pressure and temperature is obligatory at the mouth of the well and at the end of the shelf. Also an important parameter from the point of view of regulating the modes of the wells is the instantaneous flow rate of the shelf, which is currently not measured at the old deposits. The article proposes to assess the Instantaneous consumption by an indirect method, according to the values of pressure and temperature. The algorithm for calculating the consumption is proposed, the testing of which at the Urengoy gas condensate field confirmed its adequacy. The monitoring system of technological parameters is built into gas fishery ACS. The algorithm visualization is implemented in the SCADA HMI / Cimplicity software package.

Application of Computer Energy Optimization Method in Oil and Gas Gathering and Transportation System

With the continuous development of society and economy, human demand for petrochemical-related products and derivatives is becoming more and more vigorous. However, the increase in oilfield development time and the expansion of scale easily make it difficult to control energy consumption. In response to this bottleneck problem, this paper relies on computer technology to explore the development of energy optimization software for oil and gas gathering and transportation systems, which provides convenience for grassroots technical managers by realizing control of the operating parameters of the oil gathering system, realizing process management and fine management., Changed the traditional oilfield management model. At the same time, taking the water-mixing oil collection process as an example, explore the application process and effect of the software in the oil field.

Corrosion behavior of L360 N and L415 N mild steel in a shale gas gathering environment – Laboratory and on-site studies

Hydraulic fracturing combined with horizontal drilling has resulted in the rapid development of unconventional shale gas production during the last couple of decades. These shale gas fields have faced challenges in terms of bacterial control and pitting corrosion attacks. In the present work, laboratory and on-site corrosion tests were performed to investigate the corrosion behavior of two gathering pipelines in a shale gas field. General and pitting corrosion rates were determined via gravimetric analysis and surface profilometry, respectively. The surface morphologies of coupons and compositions of surface films were analyzed by scanning electron microscopy (SEM) and energy dispersive spectrometer (EDS). The results indicate an abundance of sulfate-reducing bacteria (SRB), with a concentration of over 104 cells/mL, was detected in the produced water collected from two gathering pipelines. Both laboratory and on-site corrosion tests revealed that the general corrosion rate was relatively low over a long testing period and decreased with the exposure time. A quantitative analysis of the general corrosion rate as a function of operating time for both pipelines was carried out based on the experimental and on-site corrosion tests. Pitting corrosion was a fundamental consideration and could pose a threat to the integrity of mild steel pipelines in a shale gas gathering system. Medium-to-serious pitting corrosion, with rates from 0.13 mm/y to 0.45 mm/y, was measured from 97 to 653 day's on-site samples. It is proposed that microbiologically influenced corrosion (MIC) associated with under-deposit corrosion was the predominant cause of pitting corrosion. In addition, chloride in the produced water promoted the pitting corrosion.

The Ensign Field, Blocks 48/14a, 48/15a and 48/15b, UK North Sea

Abstract The Ensign Field is located in UK offshore licence Blocks 48/14a, 48/15a and 48/15b. The field is located 100 km east of the Humberside coast within the Sole Pit area of the Southern North Sea. The reservoir consists of sandstones of the Permian Rotliegend Group (Leman Sandstone Formation). Reservoir quality has been impacted by diagenesis during deep burial, whereby illitization has reduced permeability to sub-millidarcy scale. The field has been developed with two horizontal production wells, both completed with five hydraulic fracture stages. First gas from the field was achieved in 2012 via the Ensign normally unmanned installation and exported through the Lincolnshire Offshore Gas Gathering System. The field is compartmentalized by multiple regional-scale De Keyser fault zones. A heterogeneous natural fracture network exists with only a limited contribution to flow. Well performance and ultimate gas recovery have been lower than originally anticipated due to sub-optimal completions and a higher degree of compartmentalization than originally expected. The volume of gas that is connected to the wells is limited by low-offset faults, which have been identified by integrating long-term production data, and core, log and reprocessed seismic data. Production ceased in 2018 when the original export route was decommissioned.

КОМПЛЕКСНЫЕ РЕШЕНИЯ ПО ПОВЫШЕНИЮ ЭФФЕКТИВНОСТИ РАЗРАБОТКИ МНОГОПЛАСТОВЫХ ГАЗОВЫХ И ГАЗОКОНДЕНСАТНЫХ МЕСТОРОЖДЕНИЙ

Актуальность. С целью снижения капитальных затрат и сокращения времени выработки запасов газа и конденсата многопластового газоконденсатного месторождения актуальной задачей является обоснование технологии одновременной разработки различных по ресурсно-энергетическому потенциалу и/или фильтрационно-емкостным свойствам эксплуатационных объектов с подачей газа в одну газосборную сеть. Решение этой задачи актуально как на стадии проектирования, так и в зрелой стадии разработки месторождения на режиме истощения пластовой энергии. В условиях резкого различия ресурсно-энергетического потенциала и фильтрационно-емкостных свойств разрабатываемых объектов низконапорные скважины при определенном противодавлении в системе сбора газа прекращают фонтанирование и переводятся в бездействующий фонд до снижения линейного давления к необходимому уровню. Цель: обоснование комплексных технологических решений, направленных на повышение эффективности разработки многопластовых газовых и газоконденсатных месторождений с единой газосборной сетью. Объекты: многопластовые газовые и газоконденсатные месторождения, содержащие в геологическом разрезе разобщенные и различные по ресурсно-энергетическому потенциалу и фильтрационно-емкостным свойствам выделенные эксплуатационные объекты. Методы: анализ текущего состояния разработки газовых эксплуатационных объектов Губкинского месторождения, аналитические расчеты технологических режимов работы низконапорных скважин, проведение опытно-промышленных испытаний на газовых скважинах Губкинского месторождения, технико-экономический анализ результатов применения предложенных технологий. Результаты. Произведен анализ текущего состояния Губкинского месторождения, характеризуемого высокой дифференциацией текущих пластовых давлений по продуктивным пластам. Предложены комплексные решения по обеспечению совместной разработки эксплуатационных объектов с подачей газа в общую газосборную сеть, обеспечивающие устойчивые режимы работы скважин и основанные на регулировании устьевого давления различными техническими устройствами. Произведена технико-экономическая оценка влияния представленных комплексных технологических решений на эффективность разработки нижнемеловых пластов Губкинского месторождения.

Layout optimization of large-scale oil–gas gathering system based on combined optimization strategy

Layout optimization of large-scale oil–gas gathering system is a kind of NP-hard problem in the field of system optimization. It involves a large number of network nodes, coupled optimization variables, complex network structures and hydraulic constraints, which cause the great difficulty in constructing optimization models and solution methods. In this paper, a high-dimensional mixed integer nonlinear layout optimization mathematical model involving the pipeline network structure parameters and pipeline design parameters is established, which can be applied to large-scale oil gathering system and gas gathering system universally. A modified particle swarm optimization (MPSO) algorithm with global search ability is proposed. The convergence theorem of the stochastic optimization algorithm is established based on the Poincare cycle theory. Global convergence of MPSO algorithm is proved, and the performance of MPSO algorithm is analyzed by numerical experiments. Based on dimension reduction planning and modularization thought, the grid dissection set partition method is proposed, and the theoretical foundation and complexity of the grid dissection method are discussed. In order to reduce the dimension of the layout optimization problem, the concept of the fuzzy set of adjacent position, and a novel approach for the well-station connection mode optimization are put forward. Based on the MPSO algorithm, grid dissection set partition method and solution method by fuzzy set of adjacent position, a combined optimization strategy for layout optimization model is proposed. The reliability and practicality of the proposed layout optimization model and combined optimization strategy are verified by the successful application of a real-world large-scale oil field with 661 wells.

EFFICIENCY EVALUATION OF IMPLEMENTATION OF OPTIMIZATION METHODS OF OPERATION MODES OF THE "PLAST - GAS PIPELINE" SYSTEM BY THE METHODS OF MATHEMATICAL MODELING

To date, Ukraine's mature gas fields, which are being developed in the gas regime, are at the final stage of development, which is characterized by a significant depletion of reservoir energy. The final stage of development requires solving complex problems related to watering wells, destruction of the reservoir, removal of formation water and mechanical impurities, increasing back pressure in the system, as well as the moral and physical wear and tear of industrial equipment. In the conditions of falling gas production, a significant part of the operating well stock is unstable, in the mode of unauthorized stops due to the accumulation of liquid at the bottom and insufficient gas velocities for removal to the surface, and also the accumulation of the liquid phase in the lowered places of the gas gathering system. Within the framework of the conducted studies, the gas dynamic models of the operation of the gas collection system of 3 oil/gas-condensate fields (OGCF) are created. A single model of the gas production system "reservoir - well - gas gathering system - inter-field gas pipeline - main facilities" is built. The current efficiency of the gas production, collection and transportation system is assessed. On the basis of model calculations, the current production capabilities of the wells are defined, as well as the "narrow" places of the system. It is established that the introduction of modern technologies for the operation of watered wells without optimizing the operation of the entire gas production system is irrational, since the liquid that is carried out from the wellbore will accumulate in the plumes and increase the back pressure level in the ground part. In conditions of increasing gas sampling, liquid flowlines can be taken out of the loops and deactivated the separation equipment. The feasibility of introducing methods for optimizing the operation modes of the gas production - gathering and transportation system is estimated, which allows choosing the optimal method for increasing the efficiency and reliability of its operation. For the first time in the Ukrainian gas industry, an integrated model of the field is created as a single chain of extraction, collection, preparation and transportation of natural gas, which can be adapted for the development and arrangement of both new and mature deposits. The main advantage of the application for the hydrocarbon production sector is the simulation of the processes, which makes it possible to evaluate the operating mode of the well in the safe zone while reducing the working pressure and introducing various intensification methods, and also to estimate the increase in hydrocarbon production. For the equipment of the ground infrastructure – "midstream" – the main advantage is a reduction in the time required to perform design calculations for gas pipelines, trains and pipelines for transporting multiphase media using public models. The creation and use of integrated models of gas fields gives an understanding of the integral picture of available resources and ensures an increase in the efficiency of field development management. The results of the calculation are clearly correlated with the actual data, which makes it possible to use the models constructed to obtain numerical results.

FEATURES OF GAS-COLLECTION SYSTEM OPERATION UNDER LIQUID ACCUMULATION

Any gas condensate field has an extensive gas gathering system (GGS), through which gas is delivered from the wells to the complex gas treatment plant. The movement of the gas is due to reservoir’ own energy. At the final stage of the field development the operating conditions of the GGS change due, firstly, to a decrease in the temperature of the transported gas, and secondly, to an increase in the water content of well products. Simultaneous action of these factors, especially in winter, leads to the ice and hydrate plugs emergence that violate the normal operation of the GGS. In order for the flowlines to operate in the mode of fluid removal, the gas flow velocity must exceed the so-called critical velocity. Its value is determined by the diameter of the pipeline, the ratio of gas and liquid densities, thermobaric conditions, the slope of the plume and other factors. It’s often not possible to ensure this speed at the final stage of operation, so the complete removal of the liquid is difficult and the danger of ice formation persists. The article proposes an innovative technology, which allows to pre-rotate ice formation in the flowline. The gas-liquid mixture in the GGS receives additional heat from the heat exchanger located inside the GGS. The coiled tubing is used as a heat exchanger. It is filled with constantly circulating coolant liquid, which is heated by passing through the heat exchanger by the discharge heat from the air cooling apparatus (ACA). Water methanol solution is used as coolant liquid. The coolant flow rate changing is carried out by means of variable-frequency drive pump. The control is based on the results of temperature measurement in the loop. The use of the proposed method allows to provide trouble-free operation of the GSS and to dispose of the waste heat from the ACA.

Development of cleaning methods complex of industrial gas pipelines based on the analysis of their hydraulic efficiency

The majority of gas and gas condensate fields of Ukraine are developed by pressure depletion, which makes it possible to stabilize production only in conditions of low working pressures at the wellhead. In turn, the working pressure values significantly depend on the pressure at the inlet to the gas gathering stations and pressure loss in the gas gathering and transportation process. Consequently, their reduction will lead to an increase in natural gas production from depleted fields. The main idea of the work is to offer continuous monitoring of the gas gathering system in order to detect changes in the thermobaric operation mode. Such changes can signal the high probability of liquid accumulation, which will produce additional friction. The results of monitoring changes in pressure, temperature, dew points and natural gas composition allow carrying out their complex analysis and evaluating the possibility of liquid mass formation in certain areas of the gas pipeline system with an acceptable accuracy, which at once excludes a more detailed recording of their presence by means of instrument equipment and human resources, as well as reduces the time of non-response to a problem. The works may be fully executed by the operations technician or the dispatch service. After detecting potentially hazardous places, they are analyzed for confirmation of the presence of liquid and the decision to clean them with one of the proposed methods is made. This approach will be very interesting to large international companies, since natural gas reserves are constantly exhausted, and withdrawal of the remaining gas from depleted fields is an attractive target for producing companies. In addition, the use of simple pigging methods based on the analysis of the hydraulic efficiency of pipelines can significantly reduce both time and material resources.