Gas Sales Research Articles

State of Disaster: A Historical Geography of Louisiana’s Land Loss Crisis by Craig E. Colten

<i>State of Disaster: A Historical Geography of Louisiana’s Land Loss Crisis</i> by Craig E. Colten

Risk Assessment of Delay for CEMS and WHRU Installation Project on Plant Shutdown at Central Processing Gas Gundih

This paper addresses a risk assessment of delay for installation of Continuous Emission Monitoring System and Waste Heat Recovery Unit as an effort to fulfil compliance with the Regulation of the State Minister of the Environment Number 13 of 2009 concerning Quality Standards for Emissions from Immovable Sources for Oil and Gas Businesses and Activities. The installation of the unit consists of three steps, pre-shutdown, window shutdown and post shutdown. In accordance with Gas Sale Agreement, that the entire period of normal maintenance work that causes gas to not flow, should not be more than 15 (fifteen) days every year. The planning and implementation of maintenance is very important by utilizing the condition of the window shutdown to avoid material and non-material losses. Reviewing the vulnerability of this project, it is necessary to conduct research that assesses the level of risk of project delays using the ISO 31000:2018 risk management concept approach, through identification of risk variables from several literature studies, risk analysis through Group Discussion Forums, and risk management efforts to reduce risk of delays in the installation project. From the risk identification, 30 risk variables that affect project delays consist of 2 High categories, 3 Medium to High categories, 15 Medium categories, 6 Low to Medium categories and 4 Low categories. The Risk Treatment carried out in the high and Medium to high categories resulted in 9 mandatory RCOs to reduce delays and 1 RCO to speed up the implementation schedule from 19 days to 13 days and earn a profit of $615,000 because the process of selling gas to consumers can be accelerated by 2 days.

Process simulation and optimisation for acid gas removal system in natural gas processing

Acid gases such as hydrogen sulphide (H2S) and carbon dioxide (CO2) are abundant in natural gas, which affect the economics of plant operations and the environment. Chemical absorption is one of the most established technologies for acid gas removal. However, it suffers with a major drawback, i.e. high energy consumption. In this work, an integrated simulation-optimisation approach was employed to minimise energy consumption and hence operating cost in an acid gas removal (AGR) system for natural gas processing. The integrated approach made use of commercial simulation software Aspen HYSYS and optimisation software LINGO to establish a surrogate model that has the best operating conditions while satisfying sales gas requirements. Operational parameters such as alkanolamine flowrates, absorber pressure, and alkanolamine temperature were taken into account. Moreover, Pareto analysis is carried out for multi-objective optimisation in maximising profit and minimising CO2 content. The integrated approach was demonstrated on a case study involving an AGR system in a natural gas processing plant. Results showed that with the optimal operating conditions, profit of the plant is predicted to increase by 9.15% for the same CO2 basis (i.e. 0.77 mol%); the profit is expected to increase by 23.3% at higher CO2 content (i.e. 1 mol%). It was observed that the maximum profit and minimum CO2 content is achieved at amine recirculation rate of 1914.49 m3/h, pressure of 54 kg/cm2, and temperature of 49.54 °C. Furthermore, sensitivity analysis illustrated that profit is proportional to the sweet gas price whereas electricity cost is the most vital parameter in reducing the overall profitability.

Study on The Design of Solar-Wind Energy System to Reduce The Use of Gas Fuel in The Southeast Sumatra Block

The Southeast Sumatra block produces oil and gas. Natural gas production of 15,300 MSCF is used as fuel for turbine generators to generate 38 MW of electrical energy, while the rest is used as business products. The application of the solar-wind system can reduce the load on the turbine generator so that gas fuel consumption is also reduced. Five platforms have areas that can be utilized for a solar-wind system. This study aims to determine the amount of gas fuel consumption that can be reduced by the solar-wind system application. The method is simulation using the HOMER software to determine the amount of electrical energy that can be supplied and the costs required by the solar-wind system. The components used are found in the HOMER software and on the market. The simulation results show that the off-grid solar-wind system can provide electricity supply of 50,235 kWh per year and reduce gas fuel consumption by 20,094 MSCF per year. The on-grid solar-wind system can provide electricity supply of up to 81,230 kWh per year and reducing the use of gas fuel by 32,492 MSCF per year. The off-grid solar-wind system will increase gas sales by $132,620 per year with NPV&gt;0 and ROI 21%, while the on-grid system will increase gas sales by $214,447 per year with NPV&gt;0 and ROI 57%. Both models of solar-wind systems have positive economic values ​​so that they are feasible to implement

Финансово-экономическое обоснование проекта по строительству малотоннажного комплекса сжижения природного газа

In modern economic conditions, the increased demand for liquefied natural gas necessitates the engineering design of technological solutions for the production of liquefied natural gas and its financial and economic justification. The scientific article is devoted to the development of a financial and economic model and the evaluation of the effectiveness of the project for the construction of a small-scale natural gas liquefaction complex and the analysis of project risks. The proposed format of the financial and economic model is based on the calculation of key indicators of the project's operating and investment activities, including OPEX and CAPEX, as well as on the formation of financial plans that reflect the net profit and net cash flow. The presented financial models are used in calculating the performance indicators of the design solution and are the information basis for the analisis influence risk factors for net monetary income. The article examined the impact of macroeconomic drivers and deflator indices — liquefied natural gas prices, the dollar exchange rate against the ruble on the change in income from gas sales and on the formation of key project indicators. The authors of the article substantiate the expediency of applying the financial and economic model in practice for further use in project documentation as an economic part of the feasibility study.

Concurrent 14. Presentation for: The transformation of Australia’s first commercial CSG field into a major gas project: how innovation and subsurface understanding has driven its success

Presented on Wednesday 18 May: Session 14 Mount Isa Mines Limited discovered coal seam gas (CSG) in the ‘Dawson Valley’ in 1991. It was the first commercial coal seam gas field in Australia, with production and sales of gas commencing circa 1994, then operated by Conoco and known as Meridian SeamGas. In 2010, Westside Corporation acquired a 51% operating interest in Meridian SeamGas from Anglo American (Anglo) and Mitsui Moura Investment Pty Ltd (MMI). Over the last 10 years, Westside has increased sales by 466% from 9 terajoules per day (TJ/d) to 42 TJ/d with gas being sold to both domestic and export markets. Further acreage acquisition to the north and south increased the asset area by 264%; now known as the Greater Meridian Fields (GMF). The steep rise in gas demand, complex market dynamics, regulatory environment, and competition from large global oil and gas operators makes it a challenging environment for smaller gas producers in Australia. Remaining agile and employing innovative approaches to optimise field development are key factors for Westside’s growth. In particular, the pad-based drilling of up dip multi-lateral wells has reduced cost and surface footprint, while enabling more efficient gas drainage. To support this field development, a more robust subsurface framework was required. Adequate knowledge of the distribution and variability of coal thickness, gas content/composition, structure, and geohazards forms the basis of the static model. It is used for resource definition and for the optimal planning and execution of multi-lateral wells, reducing drilling risks. To access the presentation click the link on the right. To read the full paper click here

The transformation of Australia’s first commercial CSG field into a major gas project: how innovation and subsurface understanding has driven its success

Mount Isa Mines Limited discovered coal seam gas (CSG) in the ‘Dawson Valley’ in 1991. It was the first commercial coal seam gas field in Australia, with production and sales of gas commencing circa 1994, then operated by Conoco and known as Meridian SeamGas. In 2010, Westside Corporation acquired a 51% operating interest in Meridian SeamGas from Anglo American (Anglo) and Mitsui Moura Investment Pty Ltd (MMI). Over the last 10 years, Westside has increased sales by 466% from 9 terajoules per day (TJ/d) to 42 TJ/d with gas being sold to both domestic and export markets. Further acreage acquisition to the north and south increased the asset area by 264%; now known as the Greater Meridian Fields (GMF). The steep rise in gas demand, complex market dynamics, regulatory environment, and competition from large global oil and gas operators makes it a challenging environment for smaller gas producers in Australia. Remaining agile and employing innovative approaches to optimise field development are key factors for Westside’s growth. In particular, the pad-based drilling of up dip multi-lateral wells has reduced cost and surface footprint, while enabling more efficient gas drainage. To support this field development, a more robust subsurface framework was required. Adequate knowledge of the distribution and variability of coal thickness, gas content/composition, structure, and geohazards forms the basis of the static model. It is used for resource definition and for the optimal planning and execution of multi-lateral wells, reducing drilling risks.

Sustainable design and analysis for helium extraction from sale gas in liquefied natural gas production

Currently, natural gas (NG) is an economically proven source of helium with up to 8 mol% concentration. Helium extraction at earlier stages in the natural gas liquefaction plant shows a motivating initiative to improve the economics and environmental aspects. Cryogenic fractionation is the most industrially used technology to recover helium from natural gas compared to other available technologies such as adsorption and membrane. In this work, three cryogenic-based fractionation processes, namely cold box, single column, and double columns, are assessed from technical, economic, and environmental perspectives. Aspen HYSYS simulation package is utilized to develop 1400 MMSCFD NG liquefaction capacity models for different helium concentrations. Cold box technology indicates the highest net profit per kg of helium recovery approximated at $260 for the case of a 10% ratio of sales gas vs. 90% LNG with a 1% initial helium concentration scenario. However, single column and double column technologies report the highest reduction in energy and emissions when integrating helium recovery and NG liquefaction with a 86% reduction for the same scenario.

Kebijakan Qatar Dalam Krisis Diplomatik Tahun 2017

This thesis departs from the Diplomatic Crisis between Saudi Arabia and Qatar in 2017. In relation to the diplomatic crisis, it was explained that Qatar issued a Policy in the Diplomatic Crisis, and refused to fulfill the 13 demands given by Saudi Arabia and its allies. However, the policy issued by Qatar is inseparable from the encouraging factors. For this reason, this Thesis Writing aims to find out the Factors that encourage Qatar's Policy in the Diplomatic Crisis in 2017. By using KJ Holsti's Foreign Political Study and Literature Study Research Methods, this thesis discovers the Driving Variables namely Oil and Gas Sales Guarantee nature to other countries, Diversification of Economic Sources from the Non-Oil and Gas Sector, Resilience of the Transportation Sector to the Diplomatic Crisis, Alternative Flight Lines, Guaranteed Food Supply from the Outside, Endurance of the Trade Sector against the Diplomatic Crisis and Donald Trump's Defense against Saudi Arabia.

FORMATION OF NEW LOGISTIC NODES OF GAS TRADE IN THE COUNTRIES OF SOUTH-EASTERN EUROPE

The countries of South-Eastern Europe had close economic ties with Russia and were guided by the purchase of Russian natural gas. In the recent years, both geopolitically and the market events, as well as the energy security concerns, have transformed the region of South-Eastern Europe into a significant element of the energy strategy of the European Union. The emergence of new gas suppliers in this region is due to both the requirements of the European Union for the diversification of energy supply sources and the active formation of new gas corridors in Eastern Europe, in particular, the launch of a large gas terminal in Poland. The creation of a new gas infrastructure exacerbates competition between suppliers and requires market participants to develop optimal gas supply options for consumers adapted to new conditions. The article examines the features of the formation of promising gas hubs in the countries of South-Eastern Europe. The specifics of the development of the gas market in Bulgaria and Greece are shown. Attention is focused on strengthening Turkey's position as an important gas corridor. The results of the study allow us to conclude that the energy infrastructure in this region is still underdeveloped. The region does not offer an efficient market mechanism for the sale and purchase of natural gas, as well as a spot pricing mechanism. At the same time, amid heightened competition on the European gas market, South-Eastern Europe is beginning to play an increasingly significant role in maintaining Russia's position as the largest gas supplier.

NATURAL GAS AS A SUBJECT OF GEOPOLITICAL INTERESTS OF STATES

In the last decade, the subject of sale, purchase or transit of natural gas between the countries in Europe has gained, in addition to the economic dimension, a much broader, and for some countries even more significant, geopolitical dimension. This is most evident based on the attitude of the United States and some European countries towards the projects for the construction of the Nord Stream 2, Turkish Stream and South Stream gas pipelines. By displaying a negative attitude towards these gas pipelines, the United States (with the support of some European countries) has formally emerged as a “protector of the energy interests of European countries” from Russian influence, i.e. Russian gas. Essentially, the United States is trying to slow down, reduce and suspend gas supplies from the Russian Federation (RF) to European countries, especially the most powerful ones (Germany, for example), and disguised by the need to “diversify gas supplies to European countries”, thus reduce Russia’s presence in Europe and quality of interstate relations. At the same time, the United States is trying to offer and sell its liquefied natural gas to European countries as an alternative to Russian gas, and to “fill in” the empty geopolitical space. The Russian Federation, on its behalf, instructed by the experiences from several “gas crises” with Ukraine, but also in accordance with its geopolitical interests, seeks (and has almost succeeded in doing so) to ensure the transport and sale of its gas by building new gas pipelines to Europe and improve relations with European countries. Other European countries, which need Russian gas, are trying to ensure energy security by participating in the construction of the gas pipeline, or by supporting the realization of that project. The fate of the gas pipeline and thus the possibility of gas distribution to individual states becomes a subject of interest (and conflict) of the great powers and their geopolitical interests.

PENGELOLAAN BADAN USAHA MILIK DESA (BUM DESA) DI MASA PANDEMI COVID-19

Coronavirus disease 2019 (COVID-19) pandemic period is a good momentum for Village Owned Enterprises(BUM Desa) to reorganize their orientation. Not only as a business unit that only pursues economic benefits,but also carries out social functions by playing a more role in social safety nets for the community. In addition,this period is also an important momentum to improve themselves in order to be able to face the complexproblems faced by BUM Desa due to the COVID-19 pandemic. The economic problems faced by both BUMDesa and the community are increasingly complex due to the COVID-19 pandemic. These problems includethe decline in the village economy due to the difficulties experienced by farmers to market their products,the decline in MSMEs, a decrease in people’s purchasing power, and an increase in the economic burdenof the village due to the large number of homecomers returning to the village with problems due to workin the city. This study uses qualitative research conducted through librarians to compare the managementof BUM Desa in various regions. Results of research and management of BUM Desa Overall from variousregions in Indonesia that managing BUM Desa starts with planning, to monitoring the BUM Desa sothat they continue to run as regulated in the regulations and based on the articles of association that havebeen set. And there are also ways to open businesses such as Livestock, LPG gas sales and granulatedsugar distributors and the management of BUM Desa can be done by implementing digitalization so thatmanagement can run more optimally

Racjonalne sposoby działania podziemnych magazynów gazu z uwzględnieniem zużycia nośnika energii

The fuel and energy complex of Ukraine, like most developed countries of the world, is a complex system of material production incorporating a set of many subsystems that cover the extraction, conversion, distribution, storage and consumption of energy. Ukraine's gas transportation system has an extremely complex system, which consists of gas pipelines of various purposes and capacities, compressor stations, compressor shops, gas distribution stations and underground gas storage facilities. Compressor stations, allied with underground storage, ensure full pipeline use, reliability of work, modes of regulation of transit flows and maintenance of uninterrupted supply. Their co-employment is considered one of the most effective methods of increasing reserves for reliable gas supply and efficiency of gas sales in the country and abroad. The use of storage reduces the unevenness of seasonal consumption and enables timely delivery. This is justified by the fact that during the year, gas production is uneven, as is consumption. In winter, the amount of gas extracted does not provide the amount of gas consumed. Therefore, underground storage facilities are an integral part of the gas transmission system, which must function efficiently. The Ukrainian gas transportation system is part of the European energy system, despite the fact that the country itself is not yet a member of the EU. To research the issues of improving the efficiency of the system and underground storage facilities, it is necessary to analyse the parameters of their work and study the problems of reducing costs during storage and transportation. In the work on the basis of the analysis of the cyclic operation of the Dashavsky underground storage, the energy approach to an estimation of losses of gas at storage is offered. This will streamline and specify the general ideas and the level of irreversible losses of natural gas as an energy source and will increase the efficiency of operation of the underground gas storage as a whole. At the same time, taking into account the energy characteristics of natural gas when forecasting its losses during storage will significantly affect the organisation and optimisation of maintenance of storage equipment and, in particular, the compressor station.

Risk-benefit perceptions of natural gas export in Oregon

ABSTRACT Public perceptions of fracking and natural gas have received significant scholarly attention recently. However, opinion research is scant with respect to natural gas export (the transport and sale of natural gas from one country to another via pipeline or ship) and its associated economic benefits and environmental risks. Understanding public views on export, particularly in places where export facilities are proposed, is important because the U.S. has rapidly increased its natural gas exports overseas in the wake of the shale revolution. Moreover, such facilities have been targeted by anti-fossil fuel and climate activists as a weak link in the chain of the fossil fuel economy, particularly on the U.S. West Coast where proposals for export terminals have proven unsuccessful. Using a web-based opinion survey in the state of Oregon (n = 500), we evaluate risk and benefit perceptions of natural gas export and the role of socio-demographic, political ideology, and place-based factors in shaping these perceptions. We find that men, conservatives, urban residents, and those who perceive that their community’s economic identity is tied to extractive industries are less likely to perceive risks and more likely to perceive benefits from natural gas export. Respondents with a bachelor’s degree and those who perceive that their community’s economic identity is tied to renewable energy are more likely to perceive risks and less likely to perceive benefits. Whereas much of energy social science is focused on sites of extraction, our results contribute to the growing understanding of the social dimensions of energy export.

E&amp;P Notes (February 2022)

E&amp;P Notes (February 2022)

LNG Distribution Optimization using Set Partitioning Problem Method

The Indonesian government’s commitment to increase the use of gas for domestic demand, by issuing the Decree of the Minister of Energy and Mineral Resources Number 13K/13/MEM/2020 concerning the Assignment of the Implementation of the Supply and Development of LNG Infrastructure and the Gasification 52 power plants in Indonesia. Therefore, a study on the supply chain design that can support the gasification process of the 52 power plants is crucial. Power plant data is imperative to identify receiving terminals which are then grouped into 8 clusters using the K-Means method. The design will use operating LNG refineries, which will then go to the hub for each cluster. Considering the feasibility factor of the receiving terminal and using the center of gravity method carries the determination of the hub. Considering the investment and operational costs form the feasible route as the most optimal by using the Set Partitioning Problem (SPP) method. The optimization considers several types of ships with six different sizes. The total investment cost required was $107,815,749.11, and the operational cost was $68,993,709.11. The results of the economic analysis indicate the distribution will reach a payback period within 10 years if gas sales use a margin of 1,75 USD.

Modelling Flare Gas Recovery System for Recovery and Utilization of Stranded Associated Gas in the Niger Delta

In this paper, the modeling of a flare gas recovery system (FRGRS) for the recovery and utilization of stranded associated gas in the Niger Delta region of Nigeria was investigated. The gas recovery system is a novel modular plant with several integrated units and operational features. The FGRS was modeled for the recovery, treatment, processing of stranded associated gas. Two cases were considered, one was the compression of the treated gas from the FGRS to pipeline as sales gas while the other was the conversion of the treated gas to premium transport liquids by gas-to-liquids technology. 25 MMScfd of recovered stranded associated flare gas was used as feedstock and it yielded 23.22 MMscfd of treated natural gas and 1.77 Mscfd of acid gas. The treated gas met all pipeline sales gas specifications. In modeling the GTL plant, an autothermal reforming method of synthesis gas production was used and an H₂/CO ratio of 2.33 was recovered which was acceptable for Fisher-Tropsch reaction downstream. The entire GTL plant simulation was modeled in Honeywell Unisim with Peng-Robinson as the fluid property package. Gas-to-liquids (GTL) product produced from the 23.22 Mscfd treated gas fed to the GTL plant were 2350 b/d of liquid transport fuels comprising 1100 b/d of diesel and 1250 b/d of gasoline. Economic analyses revealed thata net present value (NPV) of US$ 109.9 million was realized from the sales of GTL liquids while an NPV of US$58.5 million was realized from the sales of pipeline quality gas. Thus, the sales of GTL products represent an increase in NPV of 87.8% when compared with that of pipeline gas. However, the Pay-out time (POT) for pipeline sales gaswas 1.16 years, the internal rate of return (IRR) was 86% while the profit-per-dollar invested was 16.18. Furthermore, the pay-out time for GTL product sale was 5.29 years, the internal rate of return was 18.3% and the profit-per-dollar invested was 2.78. The project showed that the gas may be sold outright (as pipeline gas) if the market was available and in the absence of a ready market for the gas, the gas could be converted to liquids that are easier to store and have greater market potentials in the long run.

Modeling the Proposal of the Simultaneous Purchases and Sales of Electricity and Gas for the Energy Market in a Microgrid Using the Harmony Search Algorithm

The use of different energy carriers together, known as an energy hub, has been a hot topic of research in recent years amongst scientists and researchers. The term energy hub refers to the simultaneous operation of various infrastructures for energy generation and transfer, which has gained momentum in the form of microgrids (MGs). This paper introduces a new strategy for the optimal performance of an MG consisting of different energy carriers for each day. In a smart distribution network (DN), MGs can reduce their own costs in the previous-day market by bidding on sales and purchases. The sales and purchases bidding problem is challenging due to different uncertainties, however. This paper proposes a two-stage strategy for making an optimal bid on electricity sales and purchases with electricity and gas price dependency in the previous-day and real-time markets for an energy hub. In this model, the MG behavior regarding the electricity and gas energy sales/purchase, the simultaneous effects of electricity and gas prices, as well as the energy carriers’ dependence on one another are all examined. Due to the inherent uncertainty in the sources of clean energy production, the probabilistic model and the production and reduction scenario have been used in the paper to cover this issue. In the proposed grid, energy sales/purchases are presented in a multi-carrier MG in a two-stage model. This model is solved by using the harmony search algorithm in MATLAB. Numeric results demonstrate the benefits of this model in reducing energy hub costs of operation.

Design and Simulation of Natural Gas Liquid Recovery Process from Rich Natural Gas

Natural gas plays a growing role in the energy mix by displacing coal due to its relative economic and/or environmental advantages A process of natural gas liquid (NGL) recovery utilizing internally generated energy to achieve energy efficiency was designed. The process utilizes heat generated from the compressor end of the turbo-expander to provide heat energy required to maintain the appropriate operating conditions at the intermediate and bottom sections of the demethanizer column, rather than utilizing dedicated steam generators that requires additional construction, installation, operations and maintenance cost. Simultaneously, the temperature of the hot residue gas is also dropped to the required range for export, rather than utilizing dedicated process gas coolers. The various unit operations such as heat exchangers, liquid separators, Joules Thompson Valve coefficient, demethanizer column, reflux condenser, and bottom reboiler were designed, and cost evaluation performed for each unit, while models were solved using MatLab software. The quality and composition of NGL and residue gas produced are consistent with industrial process plant data. In addition, condenser and reboiler showed that the heat removed from the condenser is 3.180.5kW and 1.65m 2 area was exchanged, while the heat for the reboiler is 474.5kW at 47.25m 2 exchanged area. Also, the temperature profile of the demethanizer column is not uniform as lower temperature is required for the rectifying section (cryogenic absorption). Thus, temperature of -90 o C to – 95 o C favours the production of sales gas as the top product stream, while a temperature range of 30 o C to 36 o C at the bottom favours the recovery of NGL product as the bottom stream. The height and diameter of demethanizer column for distillation and absorption sections are 28m and 1.55m and 7.24m and 3m respectively. Keywords: Natural Gas Liquid, Heat Exchanger, Separator, J-T Valve, Demethanizer Column, DOI: 10.7176/CPER/64-04 Publication date: January 31 st 2022

OPTIMIZATION OF CONTROL OF OPERATING MODES OF GAS TRANSPORT SYSTEM USING UGS

The Soyuz, Urengoy-Pomary-Uzhhorod and Progress gas pipeline systems form the basis of the trans-Ukrainian trans-Ukrainian pipeline system. The complex gas transmission system contains a number of gas pipelines forming a linear part and several compressor stations. The amount of capacity of pipelines depends on the number and characteristics of compressor stations. Reliability of work, regulation of transit flows and ensuring uninterrupted gas supply is carried out with the help of underground gas storage facilities, which are an integral part of the GTS of Ukraine. The use of underground storage facilities is considered to be one of the most efficient ways of gas supply, improving the quality of gas supplies to consumers and the efficiency of gas sales within the country and abroad. With the use of storage, you can reduce the unevenness of seasonal consumption and ensure security of supply. The use of underground storage facilities is an integral part, as during the year the maximum daily gas extraction exceeds the minimum more than three times, and the supply of gas through the main gas pipelines is almost constant. The maximum storage capacity cannot be represented as the sum of the absolutely free flow rates of all production wells. This is explained by the fact that the productivity of the underground gas storage during the extraction period is affected by the hydraulic resistance of the gas collection system to the underground storage and its technical condition, which is determined by the coefficient of hydraulic efficiency of loops and collectors.&#x0D; Studies show that the location of gas storages in the system has an impact on the amount of energy consumption. Therefore, the strategy of rational use of underground gas storage facilities in pipeline transport (in terms of minimizing energy consumption) is based on the study of the impact of their location in the gas transmission system. The principle of energy efficiency of the use of underground gas storage facilities for long-distance transportation (in order to equalize the unevenness of gas consumption) is based on the sequence: the most remote UGS should be used first. These are the objects that are located at the end points of the GTS route and whose location corresponds to the proximity to consumers.