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The article examines the problems of Russia’s cooperation in the gas sector within the Eurasian Economic Union, and on the world stage. With the advent of the new millennium, many states began to face more and more questions of their energy security and energy supply. Russia, as one of the world leaders in reserves, production and export of hydrocarbons, constantly faces increased competition at the regional and international levels. As the result, our state has to respond to such a volatile situation in foreign markets by establishing close mutually beneficial cooperation with both producers and consumers of energy resources. Therefore, the incessant changes in the international arena and the emergence of new circumstances leading to problems in the energy sector, makes this study very relevant.

This paper compares different variants for development of gas-condensate fields in harsh Arctic environments. These variants were based on a case study (development of Arctic offshore gas condensate field) presented at RAO/CIS Offshore 2021 conference during a panel discussion of young scientists. The paper discusses and analyses main solutions in the suggested concepts, highlighting their common points and identifying their advantages and drawbacks. As a result, the authors suggest a generic development concept for an imaginary gas condensate field that might be the most promising from the technical standpoint and also in terms of cost efficiency. This concept could be regarded as a baseline solution for development tasks of real Arctic fields.

Статья посвящена вопросам развития газового сектора в Туркменистане. Определены стратегические приоритеты национальной энергетической политики. Доказана ведущая роль газовой промышленности в экономике страны. Рассмотрены основные географические направления экспорта туркменского газа. Особое место посвящено взаимодействию Туркменистана и Китая в осуществлении проектов по сооружению магистральных газопроводов, через которые туркменская нефть поступает в Китай. Делается вывод о заинтересованности Туркменистана в наращивании инвестиций для газовой индустрии., The article is devoted to the development of the gas sector in Turkmenistan. Strategic priorities of the national energy policy have been determined. The leading role of the gas industry in the country's economy has been proved. The main geographical directions of export of Turkmen gas are considered. A special place is devoted to the interaction of Turkmenistan and China in the implementation of projects for the construction of main gas pipelines through which Turkmen oil enters China. It is concluded that Turkmenistan is interested in increasing investments for the gas industry., Экономика и предпринимательство, Выпуск 11 (148) 2023, Pages 403-406

It is essential to characterize fluid flow in porous media to have a better understanding of petrophysical properties. Many approaches were developed to determine reservoir permeability among which the integrated analysis of hydraulic flow unit (HFU) and electrofacies (EF) is considered to be useful one. However, the application of HFU and EF analysis has not been totally understood with a limited data to develop correlation for less distance offset wells. In this study, an attempt was made to show the application of integrating HFU and EF for reliable estimation of permeability using core and wireline log data in one of the gas fields in Pakistan. The results obtained indicate that the integrated approach proposed in this study can be used, especially in less distance offset wells when a limited number of data are available for petrophysical characterization.

Pure kinematic models are classically used to validate and balance geological cross sections in fold-and-thrust belts, impacting the interpretation of the structural style, the kinematics, and finally their exploration potential. During the 1960s and 1970s, surface geological data were largely used to interpret the structural style of the “Faja Plegada,” along the outer sector of Chos Malal Triangle Zone (Argentina), with the aim to steer the hydrocarbon exploration. Some of the original proposed concepts are still considered valid nowadays. The discoveries of El Portón and Filo Morado fields encouraged the acquisition of seismic data in the area, to better image these structures, both for field development and further Hydrocarbon exploration. The use of a thin-skinned structural model, with multiple detachments (Choiyoi Group, Vaca Muerta and Huitrín Formations), and a “Rocky Mountain structural style” have been used since the sixties to describe the anticline geometries and propose subthrust structures, enhancing hydrocarbon prospectivity in Chos Malal. Nevertheless, a thick-skinned structural model is considered more appropriate, even though the style of the area is still debated, and several alternative models have been illustrated in the scientific literature. Despite the effort put into seismic acquisition, design, and processing, the subthrust images are still unclear and alternative interpretations can be proposed with a strong impact on the exploration potential. This paper illustrates the impact that the improvement of the seismic reprocessing had in better understanding the kinematics and structural style of the area, and the consequent evolution of the exploration concepts, in terms of geometry and structural uncertainties. In addition, we discuss the role played by multiple detachments in controlling the localization and growth of the anticlines and also in the migration of the deformation from thick to thin-skinned along the outer front of the Chos Malal thrust belt.

�� ������������ ������������������������������ �������������� �������������� �� ������������ �������������� ���������������� �������������������������� �������������������������������� �������������� ���� ���������������������� �������������������������������� ������������������������. �� ���������� �� ���������������������� �������������������� �������������� �������������������������� ���� ������������������ ������ ���������������������� ���������������������������� �������������� ����������������-���������������������������� ���������������� ���������������� ������������ ������������������, ���������������������� �������������������� �������������������������� �������������������� ���������������������� �������������� �������� �� ���������������� �������������������� �������������������� ����������������. �������������������� ������������������������������ �� �������������� ��� �������������������������� ���������������� ��������������������. ������������������������ ���������������� ������������ ���������������������� �� ������, ������ ������������������������ ���������� �������� ������������������������ ������ ���������������������� ������������������������������ �� ��������������-�������������������������� ������������������ �������������������� ���������������������� �������������� �������� �� ���������������� ���������������� �������������������� ����������������., The article deals with the analysis and evaluation of the current production characteristics of production wells based on the results of gas-dynamics studies. Due to the increasing depletion of oil fields over the past two decades, the primary task of fuel and energy companies is to assess the criteria for determining the effectiveness of the development of Cenomanian gas deposits in reduced reservoir pressure. There are technological, technical and economic criteria for such development. The practical significance of the article lies in the fact that the study can be used to substantiate the technological, technical and economic criteria for the development of Cenomanian gas deposits in conditions of reduced reservoir pressure., �������������������������� ������������-���������������������������������� ������������, ������������ 1 (115) 2022, Pages 187-191

В статье рассматривается история освоения газовых месторождений Крайнего Севера в СССР, начало которому было положено во второй половине XX века. Выделены основные события в процессе освоения новых месторождений Западной Сибири. Авторы отмечают влияние эксплуатации новых месторождений на интенсификацию газификации крупных городов страны, что привело к улучшению социально-бытовых условий граждан страны и к значительной экономии энергоснабжения жилых домов и предприятий. Процесс строительства газотранспортной инфраструктуры и большие запасы газа создали условия для экспорта газа в страны Европы, что на сегодняшний день является стратегически важным для топливно-энергетического комплекса России., The article explores the history of the development of the main gas fields of the Far North in the USSR, which started in the second half of the XX century. The main events in the process of developing new fields of Western Siberia are highlighted. The authors note the influence of the exploitation of new fields on the intensification of gasification of large cities of the country, which led to an improvement in the social and living conditions of the country's citizens and significant savings in energy supply to residential buildings and enterprises. The process of building gas transportation infrastructure and large gas reserves have created conditions for gas export to European countries, which today is strategically important for the fuel and energy complex of Russia.

Данная работа включает в себя рассмотрение вопросов безопасности на объектах нефтегазового комплекса. Поскольку процедура газодинамических и газоконденсатных исследований скважин является регулярной и проводится на опасных производственных объектах, то оценка риска возникновения аварий является важным звеном в управлении безопасностью на таких объектах. В соответствии с полученными результатами оценки рисков экспертным методом и на основе анализа статистических данных возможна разработка мероприятий, направленных на снижение аварийности на месторождениях. This work includes consideration of safety issues at oil and gas facilities. Since the procedure of gas-dynamic and gas-condensate studies of wells is regular and is performed using hazardous production facilities, the assessment of the risk of accidents based on the expert method and analysis of statistical data helps to reduce the accident rate at the fields.

Горный журнал Казахстана, Выпуск 4 (192) 2021, Pages 22-27

В статье рассмотрено воздействие объектов нефтедобывающей промышленности на окружающую среду, в частности на атмосферный воздух. В настоящее время возникают новые задачи и требования для нефтегазодобывающей промышленности России. Это связано с геополитической потребностью разработки новых нефтегазодобывающих месторождений. Возрастания объемов добычи сказывается на интенсивности негативного воздействия на окружающую среду, причем проявляется данное воздействие как на этапе строительства, так и на этапе их эксплуатации. Актуальность этой проблемы возрастает, учитывая обычно тяжелые природно-климатические условия в перспективных регионах добычи нефти и газа, что обуславливает необходимость изучения геоэкологических рисков для различных объектов добывающей промышленности. Целью работы является оценка ущерба атмосферному воздуху при разработке наиболее значимых месторождений для региона и их сравнительный анализ. В результате анализа было установлено, что Ярактинское месторождение наносит наибольший экономический ущерб атмосферному воздуху. Предприятию, проводящему разработку данного месторождения, необходимо внедрить и организовать более современные меры по контролю и снижению степени негативного воздействия.

В статье рассмотрены причины остановки эксплуатационных газовых скважин (ЭГС) и подходы по прогнозированию критических параметров в них для оценки необходимости перевод в стадии капитального ремонта. Изложены подходы обоснования и оценки влияния критических значений параметров ПЗП на работу ЭГС для прогнозирования времени остановки скважин. Рассмотрены геологические, технологические и аналитические этапы по переводу скважин в КРС. Изложены основные критерии, по которым выполняется оценка эффективности работы ЭГС и необходимости перевода скважины в программу проведения КРС, являющейся совокупность геолого-технических, геолого-промысловых и производственных параметров, характеризующих состояние ПЗП, эксплуатационных скважин и газосборной сети. Рассчитаны значения пороговых давлений для сеноманского продуктивного пласта, присвоены значения кодов геологического состояния скважин по пластовому давлению. Приведены первичные исходные данные для расчета прогнозных дебитов скважин и срока их работы с рентабельным уровнем дебитов ЭГС. Определены условия выбора скважин для проведения успешного КРС с учетом величины текущего пластового давления, позволяющего при требуемой депрессии не допустить выпадения ретроградного конденсата в ПЗП. Планирование скважин при переходе в КРС рекомендуется осуществлять в три этапа: геологический, технологический и аналитический. Изложены главные критерии выбора скважин для проведения КРС, позволяющие получение потенциальных супер-, высоко- и средних дебитов скважин. Прогноз дебитов газовых скважин необходимо проводить для объективной оценки результатов КРС. Сопоставление прогнозных и фактических данных о продуктивности скважины дает реальную возможность выявить причины несопоставимых, в том числе низких дебитов, и наметить мероприятия для получения оптимальных дебитов., The article discusses the reasons for a development gas well shutdown and approaches to predicting critical parameters in them to assess the need for a major workover. The paper describes the methods of substantiation and evaluation of the impact of critical values of the hole-bottom region parameters on the operation of development wells for predicting the time of the shutdown. The article details the geological, technological and analytical stages of converting the wells to workover. The article contains the main criteria for evaluating the efficiency of the development wells and the need to transfer the wells to the program for conducting the workover, which is a set of geological-technical, geological-industrial and production parameters that characterize the state of the hole-bottom region, production wells and the gas-collection systems. During the research, the values of threshold pressures for the Сenomanian productive strata were calculated and the values of codes for the geological state of wells for reservoir pressure were assigned. The article gives the primary source data for calculating the forecast for the well flow rates and their operating life with a cost-effective level of the development well flow rates. The current article determines the conditions for selecting the wells for a successful workover, taking into account the current reservoir pressure, which makes it possible to prevent the retrograde condensate formation in the hole-bottom region with the required pressure drawdown. It is recommended to plan the transition to the well workover in three stages: geological, technological and analytical. The paper describes the main criteria for the selection of wells for the workover, which enables the obtainment of potential super, high and medium well flow rates. The forecasting of gas well flow rates should be carried out for an objective assessment of the results of the workover. The comparison of inferred and actual data on well productivity provides a real opportunity to identify the causes of disparate and low flow rates, and plan measures to obtain optimal flow rates., Международный научно-исследовательский журнал, Выпуск 11 (101) 2020, Pages 56-63

The Yamal Peninsula occupies the northern part of the West Siberian Plain in Russia. This territory has rapidly developed due to the exploitation of several gas fields. At the same time, the Yamal Peninsula is one of the most severely gullied landscapes in the Arctic. The potential risk of damage to the environment or structures and the cost of such damages are very high there. The erosion potential is the cumulative erosion by runoff above critical, calculated for each point at a catchment. Calculations take into account the geomorphic, lithological, and vegetation cover thresholds, realized in the form of critical runoff depth of erosion initiation. It also takes into account action of all flows between the critical and maximum runoff. The calculations for several gullied catchments on the Yamal Peninsula show the uneven distribution of erosion potential level with the maximum of gully erosion on the steep banks of the river valleys and on gully heads with bare soil. The area with potential erosion in these catchments varies within the range of 17&ndash, 33%. The erosion on the Yamal Peninsula is mainly of natural origin. It occurs on steep slopes and at the heads of gullies. These landforms are not used for exploitation camps and settlements. Nevertheless, the linear structures, such as railways, roads and pipelines, can cross these unstable landforms with the risk of damage. Erosion potential increases at the spots with bare soil, which appear due to both construction work and natural processes, such as slumping.

Background: Existence of coordinated and professional safety system to prevent occurrence of accidents and potential hazards seem to be essential in installing networks of gas distribution projects. Objective: To survey work-related accidents and safety performance indices in project implementation unit of Yazd gas agency. Methods: This analytical study was conducted on 197 of workforce in Yazd gas agency in 2013 that were selected by census and they were male. Demographic and accident information were gathered using a self-made questionnaire and face- to- face interview, and required information obtained from dossier to determine the safety performance indicators. Safety performance indicators were calculated in separately of 13 types occupations in project implementation unit of gas agency and data were analyzed using T-test. Findings: The highest accident frequency and severity rate were related to digging occupation and then metal line welding. Consequences of accidents were cuts (%56.7) and soreness (%14.9). The causes of accidents were related to uselessness of personal protective equipment (%25.2) and lack of precision in the task (%19.3). The highest rate of accident was observed among the age group 20-29 years with work experience of 4-6 years. Conclusion: According to the findings of this study and the risk of gas processes, it seems to be necessary the implementation of integrated management systems and training of workers about safety rules to improve the safety culture and prevent accidents.

Depleted gas fields have been identified as potential targets for CO2 storage. In order to maximise storage capacity, a target field must be deep enough to ensure that the CO2 is in a dense phase (either liquid or supercritical). Accurate assessment of the storage capacity also requires an estimation of the amount of CO2 that can be safely stored beneath the reservoir seal which can be estimated in several ways. In this paper we develop a methodology to convert known pre-production gas column heights into CO2 column heights in order. to estimate storage capacities. Several authors have correctly identified that the differences in interfacial tension and wettability act to reduce the threshold capillary entry pressure for CO2 compared to natural gas, consequently reducing column height estimates. However, under reservoir conditions the density of CO2 is substantially higher than natural gas so the buoyancy force on the seal for a fixed column height is much lower for dense phase CO2 increasing column height estimates; we investigate the effects of this trade off on storage estimates and apply it to a typical dataset, in this case the UK North Sea.

The offshore gas fields in The Netherlands provide a storage capacity of about 1 Gt, which will become available over the next few decades. Existing production facilities may be re-used for injection. Uncertainties in storage capacity, injection rates and time of availability require an analysis of the feasibility of storing CO2 at the rates currently projected for the period 2015 - 2050. This paper investigates the availability of storage capacity and the feasibility of injecting CO2 at the rate that current capture scenarios foresee. The cost of storage in depleted gas fields is estimated, assuming either re-use of existing installations or the construction of new platforms and wells. Unit cost of storage, non-discounted, in the range of 10 €/tCO2 is feasible for larger fields; costs for small fields are estimated to range up to 40 €/tCO2. Constructing new, dedicated facilities is not always the more expensive option, due to sometimes long hibernation times and higher operational cost of existing facilities. Two capture scenarios are used for the Rotterdam and Amsterdam areas, with captured volumes increasing to 25 Mt/yr or 40 Mt/yr. In both cases, injection rate limitations become apparent when 70 - 75% of the storage capacity is used, which is around 2055 and 2045, respectively. To ensure continuity of storage, alternatives for storage in offshore gas fields need to be in place by then. © 2011 Published by Elsevier Ltd. © 2011 Published by Elsevier Ltd.

It is recognized that most of the available geological storage capacity for CO 2 is in saline aquifers. The best aquifers are likely to be in sedimentary basins (and in many cases near to fossil energy sources). However, unless the formations have been explored for hydrocarbon potential, it is likely that little data exists so significant work will be required to evaluate the realistic storage potential. Depleted gas fields offer more limited capacity but are better characterized, have seals that have successfully retained hydrocarbon gas for millions of years, and may offer a shorter route to practical implementation for early projects. Estimates indicate that depleted offshore gas fields in UK waters have the potential to store around 3.8 billion tonnes of CO 2 . This is a significant capacity and an inviting target particularly if existing infrastructure and wells can be reused. This paper explores the issues around injecting and storing CO 2 in highly depleted gas fields using a case study based on the characteristics of a Southern North Sea gas field. The study shows that assessing and managing the flow control aspects of CO 2 injection, particularly initially when the reservoirs are at very low pressure is going to be a major technical challenge. The challenges include a requirement for a high -tech flow control device at the base of the tubing to allow the dense phase CO 2 to be expanded in a controlled manner. Also the requirement for CO 2 -specific well flow performance software as conventional software, designed to model the flow of hydrocarbons, is not necessarily suffciently rigorous when modeling a complex fluid like CO 2 , particularly the thermodynamics aspects. Understanding and mitigating Joule Thomson effects is necessary to avoid the possible formation of ice and gas hydrates. Without a comprehensive understanding of CO 2 flow systems and accurate modeling of the thermodynamic effects it may not be possible to realize the potential that gas field storage offers.

Eksploatacijsko polje Sjeverni Jadran od velike je važnosti za Republiku Hrvatsku zbog velike proizvodnje prirodnog plina. Unutar njega nalaze se plinska polja Ivana, Ida, Ika, Ika JZ, Annamaria, Irina, Ana i Vesna. Na polju se nalazi 15 proizvodnih te jedna servisna platforma. U radu su obrađene sve platforme na pripadajućim plinskim poljima., Exploatation field North Adriatic is of great importance for Croatia due to high natural gas production. Whitin it there are gas fields Ivana, Ida, Ika, Ika JZ, Annamaria, Irina, Ana i Vesna. There are 15 producion platforms and one service platform. In thesis all platforms and gas fields are described.

The oil and gas sector in Ethiopia, currently at a very early stage of development, shows good potential for development on the long-run. The sector will benefit from strategies and policies to implement the broader vision for the sector. Development of the oil and gas sector in Ethiopia has the potential to transform the country’s economy. To this end, the Government of Ethiopia (GoE) has requested technical assistance and capacity building support from the World Bank as part of a wider package of support provided by the Bank (in coordination with other development partners) to develop the extractive industries (oil, gas, and mining) sector of Ethiopia. The main objective of the work to be undertaken, is to provide guidance and build capacity in GoE as it undertakes the wider update of its policy, legal, and regulatory framework of the oil and gas sector. Adam Smith International (ASI) was contracted to review the policy and regulatory framework for the oil and gas sector and provide recommendations. This final report on policy and regulatory options has been prepared at the conclusion of the analytical stage of the project, and was preceded by the initiation report submitted in July 2015. This report has two objectives. Firstly, to provide a comprehensive review of the current policy of the GoE towards the oil and natural gas sector. Secondly, to evaluate the regulatory framework in terms of good international practice.

The steep decline in the world oil price in the last quarter of 2014 slashed fuel price subsidies. Several governments responded by announcing that they would remove subsidies for one or more fuels and move to market-based pricing with full cost recovery. Other governments took advantage of low world prices to increase taxes and other charges on fuels. However, the decision to move to cost recovery and market prices, ending budgetary support, has not been implemented consistently across countries. Policy announcements have varied in the way they were communicated and the level of detail provided. When petroleum product prices bounced back during the first half of 2015, some reforming governments failed to raise prices correspondingly. Recent experience suggests that regular and frequent price adjustments, however small—as in Jordan and Morocco—help the government and consumers to get accustomed to fluctuations in world fuel prices and exchange rates. By contrast, freezing prices, even for a few months—for socioeconomic considerations or because the needed adjustments are small enough to be absorbed—increases the risk of reversion to ad hoc pricing and price subsidies. The more formally the decision to move to market-based pricing is communicated, the more public new price announcements, and the higher the frequency of price changes, the more likely the implementation of the announced pricing policy reform will be sustained.

Здійснено аналіз стану газової промисловості України. Досліджено проблеми енергонезалежності України. Представлено тенденцію видобутку природного газу в Україні. Оцінено рівень запасів газу в наявних вітчизняних родовищах. Запропоновано концептуальні рішення з розвитку газової промисловості. Доведено необхідність збільшення державних інвестицій на підтримку і розвиток газовидобувних компаній у напрямку зростання показників видобутку газу. Визначено значення розвитку вітчизняної газовидобувної промисловості в підвищенні загального рівня економічної безпеки України. З’ясовано взаємозв’язок розвитку і видобування газу на кінцевий рівень розвитку національної економіки. Запропоновано шляхи зміцнення енергетичної незалежності України., The analysis of the state of the gas industry of Ukraine was conducted. The problems of energy independence of Ukraine were examined. The trend of natural gas production of Ukraine was presented. Gas reserves in existing domestic fields were estimated. The conceptual solutions for the development of the gas industry were proposed. The need for the increased governmental investment in the support and development of the natural gas producers was proved. The importance of development of domestic gas producing industry was highlighted in order to increase the overall level of economic security of Ukraine. The influence of the specific indicator of gas production on the ultimate level of development of the national economy was examined. The ways to overcome energy dependance of Ukraine were offered.

This Energy Sector Policy Note is intended to support the Government of Mozambique in determining priorities for policy decisions with the aim of delivering efficiently produced, technically and financially sustainable electricity supply to the Mozambican population. To support the development of recommendations, this Note includes simulation analysis based on the current finances of the sector. Electricidade de Macambique’s (EDM) corporate financial model was adapted for this work. Targets for electrification are based on discussions with government officials. EDM’s current generation pipeline and its timing was taken as a given in order to simulate investment needs and evolution of sector finances under various tariff and funding availability assumptions. The various simulations and the broader sector quantitative and qualitative discussion should support policy formulation and prioritization going forward. The power sector in Mozambique faces three key challenges: i) to provide reliable and efficient electricity supply to its customers; ii) to cope with the increase in the electricity demand from its current (and future) customer base by expanding its generation and transmission capacity; and, iii) to provide access to electricity to the vast majority of the population. The importance of the timing of new generation to export power to South Africa also points to the importance of the backbone transmission project to evacuate the power from the center of the country – thereby enabling exports. Increasing access in line with Government targets will require major investments. The Government needs to consider the trade-offs between the ambition of the access targets imposed upon EDM and the sector’s broader financial viability for carrying out operations, maintenance and investment. Relaxation of the access target so that the 50 percent target is achieved by 2030 instead of 2023 gives EDM more liquidity in the first years.

Предлагается и исследуется метод адаптивной идентификации и интерпретации результатов газодинамических исследований, актуальность которого обусловлена необходимостью сокращения времени простоя скважин. Основой предлагаемого метода является интегрированная система моделей кривой восстановления давления с переменными, зависящими от времени параметрами, позволяющая учитывать дополнительную априорную информацию и восстанавливать начальный участок забойного давления. Цель исследования: разработка метода адаптивной идентификации и интерпретации, позволяющего определять параметры пластов и скважин в процессе проведения газодинамических исследований с восстановлением начального участка кривой восстановления забойного давления и учитывать дополнительную априорную информацию. Методы исследования. Использованы теоретические и практические разработки в области газодинамических исследований скважин, системного анализа, идентификации систем с учетом дополнительной априорной информации, оптимизации функций и линейной алгебры. Решение задач проводилось на основе промысловых данных исследований скважин газоконденсатного месторождения по кривой восстановления давления, с учетом экспертных оценок фильтрационных параметров пласта. Приведены результаты сравнительного анализа предлагаемого метода интерпретации с идентификацией начального участка кривой восстановления давления и без его идентификации, а также результаты интерпретации, полученные с использованием компьютерной программы Saphir. Результаты. Разработан метод адаптивной интерпретации газодинамических исследований скважин с идентификацией начального участка кривой восстановления давления, позволяющий синтезировать достаточно широкий спектр оптимальных алгоритмов определения параметров пластов и скважин в процессе проведения исследований, определять время их завершения и учитывать дополнительную априорную информацию. На примере обработки промысловых данных газодинамических исследований показано, что метод позволяет повысить точность и устойчивость определения параметров нефтяных пластов, значительно сократить время простоя скважин. The paper introduces and studies the method of adaptive identification and interpretation of the results of gas-dynamics research. Its relevance is caused by the need to reduce well downtime. The base of the method proposed is the integrated system of pressure recovery curve with the variables, time-dependent parameters. The system allows taking into account additional a priori information and restoring the initial part of bottom-hole pressure. The aim of the research is to develop the method of adaptive identification and interpretation which allows determining the parameters of reservoirs and wells at gas-dynamics researches restoring the initial part of the bottom-hole pressure recovery curve and taking into account the additional a priori information. Methods of the research. The authors have applied the theoretical and practical developments in the field of gas-dynamics researches of wells, system analysis, system identification considering additional a priori information, function optimization and linear algebra. The problems were solved on the basis of field data of well exploration in gas condensate deposit by the pressure recovery curve considering expert estimates of the reservoir filtration parameters. The paper introduces the results of comparative analysis of the proposed interpretation method with identification of the initial part of the pressure recovery curve and without its identification as well as the inter pretation results obtained while using the computer program Saphir. Results. The authors developed the method of adaptive interpretation of gas-dynamics research of wells with identification of the initial part of the pressure recovery curve which allows synthesizing a wide range of optimal algorithms for determining the parameters of reservoirs and wells at exploration, determining the time of their completion and considering additional a priori information. By the example of processing the field data of gas-dynamics researches it was shown that the method can improve the accuracy and stability of determining parameters of oil reservoirs, greatly reduce downtime.

Very high-resolution reflection seismic investigations off the Belgian coast have revealed an extensive area marked by poor seismic penetration that is probably caused by the presence of shallow gas. The gas is believed to be of biogenic origin, and its geographical distribution is bound to a wide band oriented more or less parallel to the coast. The main origin of the gas could to some extent be linked to the presence of a shallow, thin peat-rich layer of Late Pleistocene/Early Holocene age. Local high sedimentation rates furthermore favoured gas formation in the shallow fine-grained Holocene sediments. The gas-related features observed on the seismic profiles include acoustic turbidity and blanking, strong multiple reflections, and to a lesser extent bright spots and phase reversal. The sea-floor morphology does not reveal any clear gas escape from the sea bed, although there are some indications of local seepage of small bubbles or dissolved gas into the water column. The top of the acoustically turbid layer is located between 0 and 7 m below the sea-bed surface. It generally forms a sharp boundary, often marked by a varying offset probably due to different levels of gas penetration which could be related to the lithology of the overlying sediments. Seismic characteristics and velocity data seem to suggest a low concentration of gas, most likely less than 1%.

Multi-temporal Interferometric Synthetic Aperture Radar (MT-InSAR) technique has proven to be a powerful tool for the monitoring of time-series ground deformations along the line-of-sight (LOS) direction. However, the one-dimensional (1-D) measurements cannot provide comprehensive information for interpreting the related geo-hazards. Recently, a novel method has been proposed to map the three-dimensional (3-D) deformation associated with underground fluid flows based on single-track InSAR LOS measurements and the deformation modeling associated with the Green’s function. In this study, the method is extended in temporal domain by exploiting the MT-InSAR measurements, and applied for the first time to investigate the 3-D time series deformation over Sebei gas field in Qinghai, Northwest China with 37 Sentinel-1 images acquired during October 2014–July 2017. The estimated 3-D time series deformations provide a more complete view of ongoing deformation processes as compared to the 1-D time series deformations or the 3-D deformation velocities, which is of great importance for assessing the possible geohazards. In addition, the extended method allows for the retrieval of time series of fluid volume changes due to the gas extraction in the Sebei field, which agrees well with those from the PetroChina Qinghai Oilfield Company Yearbooks (PQOCYs). This provides a new way to study the variations of subsurface fluids at unprecedented resolution.

Well abandonment in the context of CO2 storage operations demands a mitigation strategy for CO2 leakage along the wellbore. To prevent possible CO2 transport toward the surface and to protect the wellbore material from contact with acid brine, we propose forming a salt seal around the wellbore at reservoir level, after CO2 injection into a depleted gas field. The mechanism of water evaporation into dry gas and subsequent salting-out of the dissolved halite is a well-known issue in hydrocarbon production. We propose alternating injection of brine and CO 2 to facilitate intentional salt clogging of the reservoir. Salt clogging was studied with TOUGH2, simu-lating multiple cycles of brine and CO2 injection. We developed two near-well reservoir models - a homogeneous 2D model and a more complex heterogeneous 2D model - using certain characteristics of the K12-B depleted gas field. The homogeneous 2D model yields a 50-cm thick salt bank around the well and complete permeability impairment after eight cycles of brine-CO2 injection. Addition of vertical permeability heterogeneities causes variation in the lateral extent of salt precipitation and hence vertical discontinuities in the salt bank. A carefully designed injection strategy - with more injection cycles and lower injection rates - improves the vertical sealing. Predictions of the amount of required clogging for effective sealing would benefit from more accurate porosity-permeability relationships and insights in the long-term stability of the salt bank regarding re-dissolution. We conclude that alternating brine-CO2 injection could be a promising method for intentional salt-clogging of the near-wellbore area. © 2013 Society of Chemical Industry and John Wiley & Sons, Ltd.

Well abandonment in the context of CO2 storage operations demands a mitigation strategy for CO2 leakage along the wellbore. To prevent possible CO2 transport toward the surface and to protect the wellbore material from contact with acid brine, we propose forming a salt seal around the wellbore at reservoir level, after CO2 injection into a depleted gas field. The mechanism of water evaporation into dry gas and subsequent salting-out of the dissolved halite is a well-known issue in hydrocarbon production. We propose alternating injection of brine and CO 2 to facilitate intentional salt clogging of the reservoir. Salt clogging was studied with TOUGH2, simu-lating multiple cycles of brine and CO2 injection. We developed two near-well reservoir models - a homogeneous 2D model and a more complex heterogeneous 2D model - using certain characteristics of the K12-B depleted gas field. The homogeneous 2D model yields a 50-cm thick salt bank around the well and complete permeability impairment after eight cycles of brine-CO2 injection. Addition of vertical permeability heterogeneities causes variation in the lateral extent of salt precipitation and hence vertical discontinuities in the salt bank. A carefully designed injection strategy - with more injection cycles and lower injection rates - improves the vertical sealing. Predictions of the amount of required clogging for effective sealing would benefit from more accurate porosity-permeability relationships and insights in the long-term stability of the salt bank regarding re-dissolution. We conclude that alternating brine-CO2 injection could be a promising method for intentional salt-clogging of the near-wellbore area. © 2013 Society of Chemical Industry and John Wiley & Sons, Ltd.

International audience; The Rousse CO2 storage project has consisted in injecting over a 3-year period (from 2010 to 2013) about 50 000 tons of CO2 into a depleted gas field located near the city of Pau. This project has been a unique opportunity to investigate various scientific and technological issues related to CO2 storage, with scopes/applicabilities exceeding those of this particular projet. University of Pau & Pays de l'Adour has been involved in these investigations along with other academic or research institutions including BRGM, IFPEN, IPGP and University of Nancy. The topics examined by UPPA are seal and fault response to CO2. The methodologies devised and implemented for assessing top seal integrity and the evolution of rock joint roughness and shear behaviour in presence of CO2 have made use of samples from the overburden of the Rousse reservoir.

The flaring of natural gas produced as part of crude oil production operations is a well-known practice which increasingly becomes a non-acceptable option around the globe. In 2010, the Global Gas Flaring Reduction Partnership (GGFR) at the World Bank reported that nearly 5TCF (trillion standard cubic feet or 135 billion cubic meters) of associated gas (AG) was flared worldwide, equal to 20 percent of US consumption emitting 320MM tons of unnecessary CO2 into the atmosphere. This paper provides a high-level overview of the status of gas conversion technologies that are developed for, or are applicable to, the monetization of associated gas. Gas conversion technology is but one out of about half a dozen options to manage or utilize AG such as gas re-injection, power production, compressed natural gas (CNG), liquefied natural gas (LNG) and pipelines. More than 15 technologies were evaluated analyzing the overall technology approach, the strengths and weaknesses of the technology, commercial readiness and technical risk along with product acceptance issues and high level economic attractiveness. The gas volume application range was from sub 1 MMscfd (million standard cubic feet per day) to a maximum of 25MMscfd with the sweet spot at 15MMscfd. The in depth evaluation was based on both publicly available information from websites, papers and patents and on private files by the reviewer. Personal phone calls with all companies answered any open questions. A standard survey was sent to all companies with questions relating to the building of a plant with a capacity of 15MMscfd. The responses are compared and discussed in detail.

The K12-B gas field is located in the Dutch sector of the North Sea. The top of the reservoir lies approximately 3800 meters below sea level, and the ambient temperature of the reservoir is over 127 °C. The K12-B gas field has been producing natural gas from 1987 onwards and is currently operated by GDF SUEZ E&P Nederland B.V. The natural gas has an initial CO2 content of 13%, which is relatively high. Since the start of the gas production the CO2 component has been separated from the natural gas stream on-site and since 2004 part of the separated CO2 is re-injected into the gas field. In 2004 a demonstration project commenced where CO2 was re-injected into K12-B. The goal was to investigate the feasibility of CO2 injection and storage in depleted natural gas fields. More than 6 years later CO2 injection is still taking place and numerous monitoring techniques have been applied in order to get a better understanding of various aspects of underground CO2 storage in nearly depleted gas fields. Over the years monitoring activities have mainly focused on the well integrity and on the behavior of the CO2 in the well and reservoir. The cap rock present at K12-B consists of hundreds of meters of rock salts from the Zechstein Super Group. The most likely migration pathway for any gas, should migration occur at all is therefore along the well bores. Establishing the conditions of wells is of great importance for safety issues. Some of the tools which have been used will be discussed. Another goal for the various monitoring activities is to gain a better understanding of the behavior of the CO 2 in the injection wells and the migration of the CO2 in the reservoir. How the CO2 migrates in the reservoir is important as regards the assessment of the potential for enhanced gas recovery (EGR) by CO2 injection. © 2011 Published by Elsevier Ltd.

In most cases, CO2 captured from power plants or large industrial sources contains impurities. As purification of the stream is energy and cost intensive it is necessary to allow a certain level of impurities. The effects of impurities on (short- and long-term) geological storage are, however, uncertain. In this work, geochemical modelling with PHREEQC is performed to describe such effects on a sandstone reservoir (depleted gas field). The impact of two possible CO2 streams, originating from pre-combustion and oxyfuel capture technology is investigated. The streams contain O2, H2, CO, H2S, SO2, and/or NO as potential chemically reactive components. H2S, SO2 and NO are computed to oxidize, thereby forming sulfuric or nitric acid, and decrease the pH of the formation water. A low pH of the brine may be the result of extensive dissolution and dissociation, and therefore accumulation in the brine phase, especially close to the injection well. The impact of impurities on fast reacting minerals (short-term effects) is predicted to be relatively insignificant, due to the low amount of brine generally present in a gas field. On the long-term (equilibrium stage), impurities cause a slightly different mineralogy compared to pure CO2 injection. For the latter case a final increase in porosity of 3.5% is predicted whilst impurities (especially oxygen) could mitigate the porosity increase to zero due to the precipitation of minerals with higher molar volumes, like alunite and nontronite. Overall, the impurities do not seem to have a significant impact on the reservoir, even if accumulation in the brine takes place. The possible limiting effect of diffusion of impurities within the supercritical CO2 towards the brine has not been taken into account, even though the effect could be relevant. It could delay the effect of the impurities due to retarded dissolution. Further research should focus on this issue. Also the spatial effects and effects on different reservoir types, cap rock and well cement need to be investigated. © 2010 Elsevier Ltd. © 2011 Published by Elsevier Ltd.

In most cases, CO2 captured from power plants or large industrial sources contains impurities. As purification of the stream is energy and cost intensive it is necessary to allow a certain level of impurities. The effects of impurities on (short- and long-term) geological storage are, however, uncertain. In this work, geochemical modelling with PHREEQC is performed to describe such effects on a sandstone reservoir (depleted gas field). The impact of two possible CO2 streams, originating from pre-combustion and oxyfuel capture technology is investigated. The streams contain O2, H2, CO, H2S, SO2, and/or NO as potential chemically reactive components. H2S, SO2 and NO are computed to oxidize, thereby forming sulfuric or nitric acid, and decrease the pH of the formation water. A low pH of the brine may be the result of extensive dissolution and dissociation, and therefore accumulation in the brine phase, especially close to the injection well. The impact of impurities on fast reacting minerals (short-term effects) is predicted to be relatively insignificant, due to the low amount of brine generally present in a gas field. On the long-term (equilibrium stage), impurities cause a slightly different mineralogy compared to pure CO2 injection. For the latter case a final increase in porosity of 3.5% is predicted whilst impurities (especially oxygen) could mitigate the porosity increase to zero due to the precipitation of minerals with higher molar volumes, like alunite and nontronite. Overall, the impurities do not seem to have a significant impact on the reservoir, even if accumulation in the brine takes place. The possible limiting effect of diffusion of impurities within the supercritical CO2 towards the brine has not been taken into account, even though the effect could be relevant. It could delay the effect of the impurities due to retarded dissolution. Further research should focus on this issue. Also the spatial effects and effects on different reservoir types, cap rock and well cement need to be investigated. © 2010 Elsevier Ltd. © 2011 Published by Elsevier Ltd.

The K12-B gas field is located in the Dutch sector of the North Sea. The top of the reservoir lies approximately 3800 meters below sea level, and the ambient temperature of the reservoir is over 127 °C. The K12-B gas field has been producing natural gas from 1987 onwards and is currently operated by GDF SUEZ E&P Nederland B.V. The natural gas has an initial CO2 content of 13%, which is relatively high. Since the start of the gas production the CO2 component has been separated from the natural gas stream on-site and since 2004 part of the separated CO2 is re-injected into the gas field. In 2004 a demonstration project commenced where CO2 was re-injected into K12-B. The goal was to investigate the feasibility of CO2 injection and storage in depleted natural gas fields. More than 6 years later CO2 injection is still taking place and numerous monitoring techniques have been applied in order to get a better understanding of various aspects of underground CO2 storage in nearly depleted gas fields. Over the years monitoring activities have mainly focused on the well integrity and on the behavior of the CO2 in the well and reservoir. The cap rock present at K12-B consists of hundreds of meters of rock salts from the Zechstein Super Group. The most likely migration pathway for any gas, should migration occur at all is therefore along the well bores. Establishing the conditions of wells is of great importance for safety issues. Some of the tools which have been used will be discussed. Another goal for the various monitoring activities is to gain a better understanding of the behavior of the CO 2 in the injection wells and the migration of the CO2 in the reservoir. How the CO2 migrates in the reservoir is important as regards the assessment of the potential for enhanced gas recovery (EGR) by CO2 injection. © 2011 Published by Elsevier Ltd.

The offshore gas fields in The Netherlands provide a storage capacity of about 1 Gt, which will become available over the next few decades. Existing production facilities may be re-used for injection. Uncertainties in storage capacity, injection rates and time of availability require an analysis of the feasibility of storing CO2 at the rates currently projected for the period 2015 - 2050. This paper investigates the availability of storage capacity and the feasibility of injecting CO2 at the rate that current capture scenarios foresee. The cost of storage in depleted gas fields is estimated, assuming either re-use of existing installations or the construction of new platforms and wells. Unit cost of storage, non-discounted, in the range of 10 €/tCO2 is feasible for larger fields; costs for small fields are estimated to range up to 40 €/tCO2. Constructing new, dedicated facilities is not always the more expensive option, due to sometimes long hibernation times and higher operational cost of existing facilities. Two capture scenarios are used for the Rotterdam and Amsterdam areas, with captured volumes increasing to 25 Mt/yr or 40 Mt/yr. In both cases, injection rate limitations become apparent when 70 - 75% of the storage capacity is used, which is around 2055 and 2045, respectively. To ensure continuity of storage, alternatives for storage in offshore gas fields need to be in place by then. © 2011 Published by Elsevier Ltd. © 2011 Published by Elsevier Ltd.

When the G-20 leaders met on 24-25 September 2009 in Pittsburgh, USA, they agreed in their Communiqué that, building on the efforts of many countries to, reduce fossil fuel subsidies while preventing adverse impact on the poorest?, they were committed to, rationalize and phase out over the medium term inefficient fossil fuel subsidies that encourage wasteful consumption. This draft report has been developed jointly by the International Energy Agency (IEA), Organization of the Petroleum Exporting Countries (OPEC), Organization for Economic Cooperation and Development (OECD) and World Bank in response to this request. It draws on the relevant expertise and work of the four tasked organizations, but also on input and comments from other organizations and experts. The report includes: a) discussion of the scope of energy subsidies; b) estimates of energy subsidies, and identification of the gaps in the existing data and issues around the measurement of energy subsidies; c) modeling-based analysis of the implications of phasing-out energy subsidies on the economy, including socio-economic and trade impacts, the environment, and the energy sector; and d) suggestions for the implementation of phase-out of inefficient subsidies leading to wasteful consumption, drawing on country case studies, including discussion of how to address social impacts.

The two piece plunger (a steel ball below and a hollow cylinder) seals the tubing when the ball is on the bottom of the cylinder. The plunger is designed to carry liquids from a producing gas well to prevent liquid loading. As such it can lift liquids when the components are together with gas pressure providing the lifting energy. When the two combined components reach the surface, the liquid is produced and the ball is pushed away from the cylinder to begin to fall against the flow. The cylinder is retained on the ball push rod until a short shut-in period of the well. Then the cylinder falls against the flow and hopefully combines with the ball at the bottom of the well to collect more liquids in the gas well and carry them to the surface with the combined ball and cylinder. There are many instances where using this plunger results in production increases. However in some cases, it appears to have a lesser effect. Results of testing show that above certain rates, the components will not fall against the flow in the well. Test results, and the result of drag models to fit the test data are extended to show the potential user what the allowable rates are from the well, before the individual components are predicted to fall more slowly or to be unable to fall in the well, thereby making application impossible without a temporary reduction in the flow rate. The results should allow the user to be able to better use the two piece plunger in a wider range of application conditions to remove liquids from a flowing gas well.

Thesis (PhD)--University of South Australia, 2003. The primary objective of this study is to provide a greater understanding of the tectonic evolution of the Warburton, Cooper, Eromanga and Lake Eyre Basins in central Australia. However, this study additionally attempts to provide a greater understanding of lineaments. This study compares lineament data with a traditional tectonic analysis in order to evaluate lineaments and to best understand the tectonic evolution of the region.

The paper deals with the surface wave data recorded in the area of gas field IVANA and IKA from 1978 to 1984 and partly from 1985 to 1986. It includes calculations of relative and cumulative frequencies of wave heights and periods and height distribution per seasons. Statistical analysis of the wave height, period and length was made for extreme speeds of characteristic winds, the Bora and Scirocco. The wave spectra were calculated from digitized records, with parameter approximation. Finally estimates of extreme values of significant wave heigths are given.