APPLICATION OF METHODS OF ASSOCIATED PETROLEUM GAS UTILIZATION FOR THE EASTERN SIBERIA

From an economic point of view, the flaring of associated petroleum gas (APG) entails significant losses of a resource that can be usefully used. In addition, it has a negative impact on the environment. Russian oil and gas companies are actively engaged in the APG utilization, but the question of choosing the most effective and reasonable solutions for its useful use remains open. The purpose of the study is to analyze the known and used methods of APG utilization in the world, the level and directions of APG utilization by Russian oil and gas companies, as well as to assess the prospects for the development of APG deep processing projects based on Russian oil and gas companies to produce gas chemistry products. The general situation on the utilization of APG in Russia was considered, the study showed that the volume of flaring has been increasing in absolute terms over the past 5 years, due to the fact that companies do not have time to develop infrastructure for gas utilization, as well as with the growth of oil production in Russia. The analysis of the level and main trends of APG utilization by the largest Russian oil and gas companies was carried out, which showed that companies are already engaged in the development of the gas chemical segment, however, they often use simpler methods of utilization (injection of APG into the reservoir, generation of electricity, injection of APG into Unified Gas Supply System). The study of the gas chemistry market showed the prospects for growth in demand for gas chemistry products at least until 2030, which confirms the relevance of the development of this direction. For a complex assessment of the prospects for the creation of gas chemical production facilities on the basis of Russian oil and gas companies, a SWOT analysis was carried out, which helped to systematize ideas about the potential for the development of the gas chemical direction by oil and gas companies. Methods of statistical research, methods of comparative and causal analysis, strategic and managerial analysis, as well as the method of SWOT analysis were used to conduct the study.

The article analyzes the current state and prospects of associated petroleum gas (APG) utilization, the main components of which are methane and other low-molecular-weight alkanes. When separated from crude oil, APG contains such hydrocarbons as ethane, propane, butane and pentane, as well as water vapor, hydrogen sulfide (H2S), carbon dioxide (CO2), nitrogen (N2) and other components. Associated petroleum gas containing such impurities cannot be used without purification. The authors noted that, the shortage of APG processing capacities both in the Russian Federation and in the world as one of the reasons for the high level of gas flaring at the oil fields. Rational methods of associated petroleum gas utilization, which depend on oil production conditions, such as field characteristics, oil/gas ratio (gas-oil factor), as well as market opportunities for the recovered gas, were identified. An algorithm was proposed for choosing a technology for the rational utilization of APG in oil and gas companies. An overview of all APG utilization methods is given, in which the main attention is paid to unit costs, economic benefits and the nature of the environmental impact. The innovative experience of the effective use of APG in the USA and Canada is analyzed. Particular attention is paid to the need to solve the problem of effective use of APG in the world, especially to reduce the flaring volume.KeywordsAssociated petroleum gasAPG utilizationAPG flaringEnvironmental pollutionDeep processingElectricity generation

The goal of this contribution is the introduction of a multinational research project aimed to the development of a novel concept for the utilization of associated petroleum gas (APG) using small-scale facilities located in remote areas in the Russian North. This project is funded by the ERA.Net RUS Plus program focused on the enhancement of the collaboration between European Union and Russia in the R&D area. It involves research institutions and companies from Russia, Germany and Poland and will be started in September 2015. The key step of the mentioned APG utilization route is the Syngas-to-Fuel (STF) process for the conversion of syngas into high-quality gasoline. One of the main challenges will be the selection of an appropriate technology for the syngas formation from APG, which is optimal adapted to the specific composition of APG usually containing (besides methane) higher hydrocarbons, CO2, N2, noble gases, sulfur-containing impurities, etc. The Russian-German-Polish project will be focused on the development of a comprehensive model for the overall process chain, including syngas generation, gas treatment, generation of heat and electricity, liquid fuels synthesis. Based on this model, technically viable and economically beneficial process integration schemes have to be defined taking into account the available infrastructure and the severe boundary conditions of the Russian North. For instance, a compact process design is desirable in terms of the reduction of capital costs. The final result of the ERA.Net RUS Plus project will be a technical and economical assessment of the novel technology for the APG utilization in remote areas, which is able to satisfy the needs of Russian oil and gas companies.

Assessment of environmental responsibility of oil and gas companies in Russia: the rating method

The article analyzes the current state and prospects of utilization of associated petroleum gas (APG), the main components of which are methane and other low molecular weight alkanes. When separated from crude oil, APG contains hydrocarbons such as ethane, propane, butane, and pentane, as well as water vapor, hydrogen sulfide (H2S), carbon dioxide (CO2), nitrogen (N2) and other components. Associated petroleum gas containing such impurities cannot be used without purification. The authors noted that the shortage of APG processing capacities both in the Russian Federation and in the world is one of the reasons for the high level of gas flaring in oil fields. In 2022, oil production decreased by 8% (from 82 million barrels per day in 2021 to 76 million barrels per day), while global gas flaring decreased by 5% (from 150 billion cubic meters in 2021 to 142 billion cubic meters). Russia, Iraq, Iran, the United States of America, Algeria, Venezuela, and Nigeria have remained the top seven countries in gas flaring for nine consecutive years since the first of two satellites to monitor gas flares from space was launched in 2012. These seven countries produce 40% of the world's oil annually, but they account for about two-thirds (65%) of the world's gas flaring. Rational methods of utilization of associated petroleum gas were determined, which depend on the conditions of oil production, such as the characteristics of the field, the oil/gas ratio (gas-oil factor), as well as market opportunities for the extracted gas. An algorithm for choosing the technology of rational use of APG in oil and gas companies is proposed. An overview of all APG utilization methods is given, which focuses on unit costs, economic benefits, and the nature of the environmental impact. The innovative experience of the effective use of APG in the USA and Canada is analyzed. Particular attention is paid to the need to solve the problem of the effective use of APG in the world, especially to reduce the volume of flaring.

Purpose: The invention relates to the oil industry, inorganic chemistry, in particular, to the methods of complex processing of formation water, using flare gas of oil and gas field as fuel for producing enriched concentrates of iodine, bromine, magnesium and valuable trace elements, as well as desalinated water (technical and drinking water). The technology includes pre-cleaning of formation water from mechanical impurities and oil using adsorbents, followed by evaporation of water under vacuum, condensing water vapor in the barometric condenser, using of condensed water vapor as the coolant, using of saline water as a coolant of hot water coming out of the barometric condenser to 15–20 °C. The novelty of the design?: The novelty of the design is to get a comprehensive treatment of formation water, using flare gas of oil and gas field as fuel for obtaining enriched concentrates of iodine, bromine, magnesium and valuable trace elements, as well as desalinated water (technical and drinking water)....

Статья посвящена расчетному анализу особенностей образования газовых гидратов в попутных нефтяных газах (ПНГ) с высоким содержанием азота. Постановлением Правительства РФ № 1148 от 8 ноября 2012 г. нефтедобывающим компаниям разрешается сжигать в факелах не более 5 % объема полученного попутного нефтяного газа, а оставшиеся 95 % должны быть утилизированы. На некоторых месторождениях нефти Удмуртской Республики ПНГ сильно забалластирован азотом (до 90 % по объемному составу) и имеет малое значение низшей теплоты сгорания, менее 8,00 МДж/м3, что существенно сужает выбор путей его утилизации. В статье рассматривается способ утилизации попутного нефтяного газа с высоким содержанием азота, заключающийся в использовании процесса гидратообразования для отделения азота от всех остальных компонентов попутного нефтяного газа. Выделенный азот может рассеиваться в окружающем воздухе без каких-либо экологических последствий, а также использоваться как товарный продукт. Смесь горючих газов, полученная после удаления балласта (азота), имеет высокую теплоту сгорания, которая эффективно может утилизироваться сжиганием в различных теплоэнергетических установках для выработки электрической энергии, а также в нагревательных печах или топках котлов без превышения предельно допустимой концентрации (ПДК) по оксидам азота, что избавит нефтяные компании от уплаты штрафов. Для заключения о технической реализуемости газогидратных технологий отделения азота от остальных компонентов попутного нефтяного газа необходимо дать ответ на вопрос о принципиальной возможности образования газогидратов в газе с высоким содержанием азота (до 90 %). Этому вопросу посвящено данное исследование.

Reservoir fluid characterization is one of the most important steps in hydrocarbon reservoir engineering calculations and studies. The reservoir fluid composition is not constant along the entire hydrocarbon column and varies along the vertical and horizontal directions. In most cases, such variations have been observed along the vertical direction. This is known as compositional grading phenomenon and has a strong impact on the calculation of original hydrocarbon in place, reservoir development, and oil recovery factor. In this paper, a simulation study was carried out to investigate the effects of compositional grading on reservoir fluid properties and the injection of various gases such as carbon dioxide (CO2), nitrogen (N2), associated petroleum gas (APG), N2–CO2 mixture, and water-alternating-CO2 injection into different depths of a conventional black oil reservoir in the southwest of Iran in order to detect the best injection depth and achieve the highest oil recovery factor. Due to increase in minimum miscibility pressure (MMP) with depth in compositionally grading reservoirs, MMP variations with depth is one of the main challenges in determining the optimal gas injection depth in such reservoirs. The results showed that N2, APG and N2–CO2 mixture were immiscibly injected into all depths of the reservoir due to their high miscibility pressures. The occurrence of gas override and channelling phenomena during the course of immiscible gas injection significantly reduced oil displacement efficiency. On the other hand, CO2 was miscibly injected to all reservoir layers and revealed a higher efficiency in comparison with the injection of N2, APG and N2–CO2 mixture. In fact, better miscibility development was observed in upper reservoir parts, as compared to the lower parts. Through completing injection wells at upper reservoir parts and then injecting gas into these parts, one can thus further enhance oil recovery and extend production plateau. Moreover, the results confirmed that water-alternating-CO2 injection into all reservoir depths, compared to other gas injection scenarios, was associated with increased macroscopic sweep efficiency as well as enhanced oil recovery factor.

Background. The present work is devoted to one of the key areas of research activity of the modern oil and gas scientific world: decarbonization and increasing the efficiency of the natural and associated gas usage. One of the eco-friendly ways of processing natural and associated gas is the production of carbon black (soot) from it. This method is also included in the list of best available technology (BAT). 
 
 Nowadays, soot is a raw material for massive scale production of rubber products, which accounts for a large share of the manufacture of tyres, besides, carbon black is a valuable component in the paint-and-varnish and petrochemical industry (inks, plastics and many other things). The aim of the project is to assess the applicability of technologies for processing the surplus of associated petroleum gas (APG) into carbon black (CB). 
 
 Materials and methods. The technology is based on the pyrolysis of hydrocarbons under the influence of high temperature with a lack of air. In the work, the following tasks were performed: CB market was studied; the analysis and choice of the optimal method for obtaining soot from APG for the N field, technological calculation, and selection of equipment and economic evaluation of the technology were performed. 
 
 Results. Calculations have shown that the use of this method of APG utilization is cost-effective. The PI of the project is more than 2. 
 
 Conclusion. The main advantages of this technology are: relatively low capital outlays, efficient gas utilization, reduction of carbon dioxide emissions into the atmosphere, additional income from the sale of a new product in high demand. The main disadvantage of this method of gas utilization is the lack of experience and practice of oil companies in the possibilities and methods of carbon black from APG.

In the context of oil field development remote from export infrastructure, excess APG (associated petroleum gas) represents an administrative and economic obstacle due to the significant cost of building the infrastructure for associated petroleum gas export or implementing methods of its utilization on site. APG should be handled somehow in order to allow a greenfield development but due to relatively small oil reserves and remoteness some conventional methods might undermine the whole case. The solution to this problem is APG reinjection into an oil reservoir, which will allow both its utilization and a positive effect of additional oil production (McGuire, 2017, Orangi et al., 2011, Kleppe, 2006) The need for APG utilization arose at one of the fields of the Remote Group. A few ideas on what to do with APG were generated and assessed and the best one was integrated into the actual project and is currently in operation.

Current legislation of the Russian Federation sets requirements for oil companies for utilization of produced associated petroleum gas (APG) at the level of 95%. Thus limiting its burning in torches in the fields. The most convenient way of APG utilization for oil companies is to pump it back into the reservoir, which sometimes allows to increase oil recovery. APG is also used for commercial generation of electricity and heat in fields by burning in gas turbine and gas-piston installations. Given the cheapness of associated gas in comparison with natural gas (NG), it is promising to replace NG with APG for large production boilers located in the immediate vicinity of the associated petroleum gas pipeline. The article provides a comparative analysis of the parameters of APG and NG, a scheme for preliminary preparation of APG for its subsequent combustion in the boiler room, an analysis of the performance of the boiler house to generate thermal energy, the feasibility of using APG as the main fuel for the production boiler room.

Purpose: the main idea of the article is to prove that the level of corporate social responsibility (hereafter CSR) of large gas and oil companies can be improved. This is a necessary condition for providing sustainable development of these companies because on the one hand the new paradigm of their development considers transition to low-carbon technologies, on the other hand, the main activity of gas and oil companies is associated with natural resources consumption, which inevitably leads to certain negative environmental consequences. At the same time, it is these consequences that trigger the process of establishing a green economy.Methods: the authors conducted a comparative and iterative analysis of the CSR development process of four major Western and four major Russian oil and gas companies.Results: large oil and gas companies around the world are deeply involved into the implementation of various areas of CSR in different directions to ensure long-term sustainable development. Our analysis showed that CSR areas are different and correspond to the basic set of CSR activities. Also, there are more advanced activities, though this applies only to individual companies. Oil companies have demonstrated certain features in their CSR practice, such as the variety of issues being addressed, the wide presence of intersectoral partnerships, and interaction with social entrepreneurs. However, not all companies are equally involved in the implementation of CSR.Conclusions and Relevance: the results of research allow us to determine the main reserves for improving the competitiveness of the analysed companies. The practical application of the results of this study is possible in the field of corporate governance, strategic planning for oil and gas companies. The results of the study are also of interest from the point of view of the development of scientific ideas about modern ways of implementing corporate social responsibility and the specifics of its implementation in the oil and gas industry.

Gas injection is one of the prospective methods in the development of unconventional oil reserves. Before implementation in the field, it is necessary to justify the effectiveness of using gas agents in specific object conditions. Experiments of oil displacement on physical models with subsequent numerical modeling can provide the information necessary to justify the feasibility of using gas injection in specific reservoir conditions. This work is devoted to a series of experiments determining the minimum miscibility pressure (MMP) on a slim tube model and the analysis of oil displacement dynamics for various gas compositions, as well as numerical modeling. Displacement experiments were carried out using a recombined oil sample from one of the fields in Western Siberia. The MMP was determined by the classical method of inflection point on the displacement efficiency versus injection pressure curve, which was 34.6 MPa for associated petroleum gas (APG) and 49.9 MPa for methane. The dysnamics of oil displacement for different gas compositions at the same injection pressure showed that APG and carbon dioxide (CO2) are the most effective in the conditions of the studied field. The influence of the gas composition on the gas breakthrough point was also shown. It is revealed that the change in the concentration of the displacing agent in the outgoing separation gas helps define in more detail the process of displacement and the processes implemented in this case for various displacing gas agents. Similarly, it is shown that the displacing efficiency of a gas agent in a miscibility injection mode is affected by the configuration of wells when it is necessary to achieve MMP in reservoir conditions. For the immiscible gas injection mode, no influence of the well configuration was observed.

Статья посвящена исследованию возможности применения газотурбинных установок (ГТУ) для утилизации попутного нефтяного газа (ПНГ) с высоким содержанием азота ( N2 ) в качестве основного топлива. Компонентный состав нефтяного газа представляет собой смесь предельных углеводородов, включающую метан, этан, пропан, бутан, изобутан и другие углеводороды, процентное соотношение которых варьируется от места нефтяного промысла, в зависимости от геологических особенностей. Эксплуатируемые месторождения Удмуртской Республики (УР) характеризуются добычей тяжелой, трудно извлекаемой нефти с попутным нефтяным газом, содержащим значительное количество азота и поэтому обладающим низкой теплотой сгорания, что существенно затрудняет его методы утилизации. Обычно такой газ сразу сбрасывается в атмосферу или бесполезно сжигается на факельных установках: в обоих случаях это негативно сказывается на состоянии окружающей среды. В Постановлении Правительства Российской Федерации (РФ) от 8 ноября 2012 года № 1148 устанавливается целевой показатель сжигания ПНГ на факеле: не более 5 % от общего количества получаемого газа. При превышении этого предельно допустимого показателя применяются повышающие коэффициенты, влияющие на размер выплат штрафов. Данные меры должны стимулировать нефтяные компании к разработке проектов по эффективному использованию попутного нефтяного газа. Существует несколько рациональных методов утилизации ПНГ: например, использование его в качестве сырья для нефтехимической промышленности или топлива для различных установок, вырабатывающих электрическую энергию и теплоту. В данной статье исследуется возможность утилизации попутного нефтяного газа с высоким содержанием азота путем его сжигания в когенерационных газотурбинных установках с преимущественной выработкой электроэнергии.

The purpose of the study is to analyze the efficiency of using associated petroleum gas (APG) and to identify the main problems, prospects and ways to increase the efficiency of its use. The article presents the results of studying the current state policy and national interests in the field of its rational use. The authors carried out an analysis of the current state of the oil and gas market at the international and regional level, as a result of which the main spectrum of problems of APG effective use was identified. A scheme was proposed which regulates the interaction between the APG market participants and is aimed at increasing the level of APG beneficial use in Russia. The authors’ research will make it possible to determine that the most significant factors that ensure a high level of APG flaring in Russia are as follows: the shortage of APG processing capacity, the restriction of oil companies’ access to the Unified Gas Supply System, the gaps in the current legal and regulatory framework, the absence of a single mechanism for the selection of projects on utilizing APG in a particular field/group of fields, as well as pricing in the oil and gas market. The findings are of practical value for scholars in the field of technology management, and for large industrial complexes.