scholarly journals Development of the digital oil and gas complex in Arctic areas of Russia

2021 ◽  
Vol 1201 (1) ◽  
pp. 012075
Author(s):  
A N Dmitrievskiy ◽  
N A Eremin ◽  
A T Kondratyuk ◽  
I K Basnieva
Keyword(s):  
Large Scale ◽  
Oil And Gas ◽  
Cost Optimization ◽  
Research Work ◽  
Digital Technologies ◽  
Integrated Approach ◽  
Climatic Conditions ◽  
Gas Production ◽  
Capital Productivity ◽  
Gas Fields

Abstract This article examines the issues of digital modernization of the oil and gas complex of Russia, the evolution of digital oil and gas technologies. The main results of research work in the field of creating digital technologies for preventing complications and accidents, transferring drilling data in blockchain format, monitoring the state of pipelines using magnetic tomography are briefly outlined. The digital modernization strategy is aimed at large-scale digitalization of oil and gas production facilities and lays a reliable basis for the growth of capital productivity of fields in the long term. The approach is based on improving the quality of management, analyzing the effectiveness of control actions when using an integrated model or a digital twin of the field. The integrated application of digital technologies for effective management is the basis for cost optimization, ensuring the transition to robotic control, and increasing the capital productivity ratio of key gas assets. These solutions are especially effective in regions with difficult natural and climatic conditions or undeveloped infrastructure, Arctic fields. The proposed integrated approach makes it possible to extend the periods of profitable exploitation of gas fields at the stage of declining production and complicated production conditions. By the end of 2025, the number of digital fields using technologies for processing Big Geo Data will exceed 10% of the total number of oil and gas fields in Russia.

A new way to predict sediment production and deposition: integrated Source to Sink maps at pluri-basins-scale

2021 ◽  
Author(s):  
Alexandre Ortiz ◽  
Charlotte Fillon ◽  
Eric Lasseur ◽  
Justine Briais ◽  
Francois Guillocheau ◽  
...  
Keyword(s):  
Cross Sections ◽  
Large Scale ◽  
Oil And Gas ◽  
Research Work ◽  
Integrated Approach ◽  
Source Tracking ◽  
Reservoir Properties ◽  
Surface Evolution ◽  
Sediment Routing ◽  
Source To Sink

<h3>The knowledge acquired on the exhumation of the Pyrenean chain and the evolution of the adjacent foreland basins makes this Alpine-type domain a good laboratory to better constrain a full sediment routing system in a compressive context and to apprehend the driving processes controlling the sediment routing in space and time. This integrated approach aims at enhancing our basin mastering approach as well as improving our predictions of reservoir properties for oil and gas exploration and storage.</h3><h3>This Source-to-Sink study seeks to understand the evolution of sedimentary routing from the Source (orogenic relief, craton, basin recycling) through the transfer zone (peripheral or internal to the basin) to the final sink (flexural basin, deep turbiditic margin). Within the framework of this new cartography, we propose to compile the available and newly acquired data from the S2S project (TOTAL, BRGM), over the entire peri-Pyrenean domain. We produced large scale quantitative and qualitative maps and wheeler diagrams to better observe and interpret the tectonic, climatic and surface processes impacts of the SRS behavior.</h3><h3>The maps include kinematic reconstructions of the Iberian-European-Mediterranean system, restored sequential cross-sections, history/magnitude of exhumation by thermochronology, source tracking, characterization of weathering and erosion surfaces, synthesis of the major structural accidents activity, paleogeographic reconstructions, analysis of sedimentary geometries and transport directions as well as the quantification of volumes preserved in the basins. Their interpretation is combined with a time representation along the routing system, linking classical basin wheeler diagram representation to source erosion and lithologies to obtain a continuous view on the sediment journey.</h3><h3>The time steps chosen for these 5 maps account for the different stages of tectono-sedimentary evolution of the peri-Pyrenean system at the early-orogenic, syn-orogenic and post-orogenic stages. The compilations carried out compare exhumed domains and sedimentation zones in terms of fluxes and volumes and make it possible to map the routing systems and discuss the drivers for the surface evolution during the construction/destruction cycle of an orogen.</h3><h3> </h3><h3>Research work financed and carried out as part of the BRGM-TOTAL Source-to-Sink program</h3><p> </p>

scholarly journals Hazardous natural processes and risks at offshore fields development with the use of subsea production of hydrocarbons (In English).

2020 ◽  
Vol 1 (8) ◽  
pp. 5-13
Author(s):  
Aleksandr Dziublo ◽  
Keyword(s):  
Oil And Gas ◽  
Climatic Conditions ◽  
Gas Production ◽  
Soil Liquefaction ◽  
Project Implementation ◽  
Remedial Measures ◽  
Oil And Gas Fields ◽  
Sakhalin Shelf ◽  
Depth Analysis ◽  
Gas Fields

Introduction. The article considers the main risks (technological, geological, societal and environmental) of offshore fields development, facilities construction and exploitation with the use of subsea production of hydrocarbons. Research aim is to analyze the main risks of offshore oil and gas projects implementation, which are associated with harsh natural and climatic conditions of the Sakhalin Island shelf, their impact on subsea facilities and to develop the remedial measures for the risks. Methodology. Risk analysis made it possible to identify the main risk factors in offshore projects development and determine remedial measures that are high-priority in offshore field exploitation at the stage of design and, most importantly, at the stage of project implementation. Analysis and discussion. Based on actual data of large oil and gas fields development, an in-depth analysis of the main risks associated with the climatic conditions on the Sakhalin shelf has shown that the region’s main geological risks are: seismicity, surface gas, seabed gouging by ice and soil liquefaction. Therefore, it is necessary to use modern environmentally sound technologies of subsea oil and gas production, which are based on successfully implemented projects abroad and the experience of shelf fields development in Russian. Conclusion. Effective development of oil and gas fields on the Sakhalin shelf is possible only if in the course of project implementation the geological, technological, societal and environmental risks are taken into account and controlled based on the developed remedial measures.

scholarly journals SEARCH AND DEVELOPMENT OF NEW DEPOSITS: METHODOLOGICAL APPROACH TO ECONOMIC ASSESSMENT OF APPLICATION IN THE OIL AND GAS INDUSTRY DIGITAL TECHNOLOGIES

2021 ◽  
Vol 3 (37) ◽  
pp. 53-66
Author(s):  
R.Kh. Azieva ◽  
Keyword(s):  
Oil And Gas ◽  
Digital Technologies ◽  
Economic Assessment ◽  
Oil And Gas Industry ◽  
Gas Production ◽  
Gas Industry ◽  
Oil And Gas Production ◽  
Oil And Gas Fields ◽  
Gas Fields ◽  
Oil And Gas Companies

The oil and gas complex is one of the main triggers of the industrial potential of the Russian Federation. An extremely important aspect for the Russian economy is the analysis of the introduction of intelligent digital technologies in the oil and gas industry, since it is necessary to immediately organize the transition from the traditional economy to the modern one – information, intellectual, digital. The use of digital technologies in the oil and gas industry is reduced to the automation of the entire process of oil and gas production and processing, and they are successfully integrated with digital control systems that are developed to solve the tasks of oil and gas processing enterprises in general. The article examines the features of the use of digital technologies by enterprises of the oil and gas complex at the stages of search and development of new oil and gas fields. The empirical basis of the study was made up of data on the reporting on the sustainable development of oil and gas companies of PJSC Gazprom Neft, PJSC Lukoil, PJSC NK Rosneft, PJSC Tatneft. The author identifies the problems of using digital technologies in the oil and gas industry, including: bimodal age distribution of the labor force; a significant increase in applications and data formats; global division of working groups; instant receipt of a huge amount of data in real time; a stable decrease in the number and size of new field discoveries; an increase in the cost of advanced technologies for restoring oil and gas production. In the context of the economic assessment of the search and development of new oil and gas fields, the use of an integral index of the use of digital technologies by oil and gas companies is proposed, which includes a number of indicators: the share of digital assets in the company's asset structure; the ratio of capital expenditures for digitalization of activities to the company's net profit; the share of employees with digital competencies; the share of new developed fields with the use of digital technologies; the profitability of the use of digital technologies (coefficient). The conclusion is substantiated that it is advisable for oil and gas companies to use the proposed conceptual model in order to identify the level of digitalization of the search and development of new oil and gas fields, which will allow improving the mechanism of state regulation of the country's oil and gas complex.

Access and Logistics Challenges in Mountain Terrain Pipeline Projects

2014 ◽  
Author(s):  
Mark McDougall ◽  
Ken Williamson
Keyword(s):  
Construction Projects ◽  
Large Scale ◽  
Oil And Gas ◽  
Large Diameter ◽  
Gas Production ◽  
Additional Time ◽  
Oil And Gas Production ◽  
Road Design ◽  
Regulatory Constraints ◽  
The Right

Oil and gas production in Canada’s west has led to the need for a significant increase in pipeline capacity to reach export markets. Current proposals from major oil and gas transportation companies include numerous large diameter pipelines across the Rocky Mountains to port locations on the coast of British Columbia (BC), Canada. The large scale of these projects and the rugged terrain they cross lead to numerous challenges not typically faced with conventional cross-country pipelines across the plains. The logistics and access challenges faced by these mountain pipeline projects require significant pre-planning and assessment, to determine the timing, cost, regulatory and environmental impacts. The logistics of pipeline construction projects mainly encompasses the transportation of pipe and pipeline materials, construction equipment and supplies, and personnel from point of manufacture or point of supply to the right-of-way (ROW) or construction area. These logistics movement revolve around the available types of access routes and seasonal constraints. Pipeline contractors and logistics companies have vast experience in moving this type of large equipment, however regulatory constraints and environmental restrictions in some locations will lead to significant pre-planning, permitting and additional time and cost for material movement. In addition, seasonal constraints limit available transportation windows. The types of access vary greatly in mountain pipeline projects. In BC, the majority of off-highway roads and bridges were originally constructed for the forestry industry, which transports logs downhill whereas the pipeline industry transports large equipment and pipeline materials in both directions and specifically hauls pipe uphill. The capacity, current state and location of these off-highway roads must be assessed very early in the process to determine viability and/or potential options for construction access. Regulatory requirements, environmental restrictions, season of use restrictions and road design must all be considered when examining the use of or upgrade of existing access roads and bridges. These same restrictions are even more critical to the construction of new access roads and bridges. The logistics and access challenges facing the construction of large diameter mountain pipelines in Western Canada can be managed with proper and timely planning. The cost of the logistics and access required for construction of these proposed pipeline projects will typically be greater than for traditional pipelines, but the key constraint is the considerable time requirement to construct the required new access and pre-position the appropriate material to meet the construction schedule. The entire project team, including design engineers, construction and logistics planners, and material suppliers must be involved in the planning stages to ensure a cohesive strategy and schedule. This paper will present the typical challenges faced in access and logistics for large diameter mountain pipelines, and a process for developing a comprehensive plan for their execution.

scholarly journals NATURAL AND ANTHROPOGENIC DYNAMICS OF PERMAFROST SOILS IN THE AREAS OF OIL AND GAS PRODUCTION IN YAMALO-NENETS AUTONOMOUS OKRUG

2015 ◽  
pp. 99-104 ◽  
Author(s):  
N. L. Mamaeva ◽  
S. A. Petrov
Keyword(s):  
Oil And Gas ◽  
Gas Production ◽  
Oil And Gas Production ◽  
Permafrost Rocks ◽  
Oil And Gas Fields ◽  
Permafrost Soils ◽  
Extreme North ◽  
Gas Fields ◽  
Cryogenic Processes ◽  
Nenets Autonomous

A research and comparison of natural and damaged (due to the active development of oil and gas fields) permafrost soils in the Jamalo-Nenets Autonomous Okrug were carried out. The analysis was run of correlation between an average monthly temperature of air, an average monthly sum of precipitation, the weight humidity and the thickness of the seasonal thawed layer. The conclusions were drawn about a poor resistance of landscapes on the permafrost rocks to the anthropogenic interventions, which in its turn is accompanied by the cryogenic processes and unfavorable influences on the Extreme North biosphere.

scholarly journals THE MAIN RESERVE OF ACCELERATED EFFECTIVE OPENING OF OIL AND GAS FIELDS IN UKRAINE

2019 ◽  
pp. 31-37
Author(s):  
V. T. Kryvosheyev ◽  
V. V. Makogon ◽  
Ye. Z. Ivanova
Keyword(s):  
Shale Gas ◽  
Oil And Gas ◽  
Research Work ◽  
Oil And Gas Industry ◽  
The United States ◽  
Resource Base ◽  
Hydrocarbon Production ◽  
Oil And Gas Fields ◽  
High Level ◽  
Gas Fields

Economic hardship in Ukraine during the years of independence led to a sharp reduction of exploration work on oil and gas, a drop in hydrocarbon production, a decrease in inventories and a sharp collapse of research work to ensure the growth of hydrocarbon reserves.The hydrocarbon potential of various sources of Ukrainian subsoil is quite powerful and can provide future energy independence of the country. Potential hydrocarbon resources in traditional traps of various types are exhausted by only 25 %. Ukraine has recently experienced so-called “shale gas boom”. The experience of extraction of shale gas in desert areas of the United States can not be repeated in densely populated Ukraine in the absence of such powerful shale strata, resource base, necessary infrastructure, own technologies and techniques and economic, environmental and social risks.Taking into account the fuel and energy problems of the state, we constantly throughout the years of independence oriented the oil and gas industry and the authorities on the active use of our own reserves and opportunities for accelerated opening of new oil and gas fields.The results of geological exploration work in the old oil and gas basins at the high level of their study indicate that deposits in non-structural traps dominate among open deposits.A complex of sequence-stratigraphical, lithology-facies and lithology-paleogeographical studies is being successfully used to forecast undeformational traps in well-studied oil and gas bearing basin of the Ukraine – the Dniprovsko-Donetsky basin. The authors predict wide development of stratigraphic, lithologic, tectonic and combined traps in terrigenous sediments of Tournaisian and Visean age, reef-carbonate massifs of the lower Tournaisian, lower and middle Visean age and others. They should become the basis for exploration of oil and gas fields for the near and medium term and open the second breath of the basin.

Integrated Approach to Produced Water Disposal Management in a Brown Field: Safeguarding Production, Reducing Cost, Managing Deferment & Reducing HSSE Exposure

2021 ◽  
Author(s):  
Basil Ogbunude ◽  
Aniekan Obot ◽  
Abdul-Wahab Sa'ad ◽  
Sunday Maxwell-Amgbaduba ◽  
Etta Agbor ◽  
...  
Keyword(s):  
Water Management ◽  
Oil And Gas ◽  
Produced Water ◽  
Integrated Approach ◽  
Gas Production ◽  
Plant Oil ◽  
Endurance Time ◽  
Oil And Gas Production ◽  
Liquid Line ◽  
Positive Cash Flow

Abstract Often, the production of oil and gas from underground reservoirs is accompanied by produced water which generally increases with time for a matured field, attributable to natural water encroachment, bottom water ingress, coning effect due to higher production rates, channeling effects, etc. This trend poses a production challenge with respect to increased OPEX cost and environmental considerations of treatment/handling and disposal of the produced water considering the late life performance characterized by low reward margins. Hence, produced water management solutions that reduce OPEX cost is key to extending the field life whilst ensuring a positive cash flow for the asset. SK field is located in the Swamp Area of the Niger Delta, with a capacity of 1.1Bcf gas plant supplying gas to a nearby LNG plant. Oil and gas production from the field is evacuated via the liquid and gas trunk lines respectively. Due to the incessant tampering with oil delivery lines and environmental impact of spillage, the condensate is spiked through the gas trunk line to the LNG plant. Largely, the water/effluent contained in the tank is evacuated through the liquid line. Based on the availability of the liquid line (ca. 40%-60%), the produced water is a constraint to gas production with estimated tank endurance time (ca. 8 days at 500MMscfd). This leads to creaming of gas production and indeed gas deferments due to produced water management, making it difficult to meet the contractual supply obligation to the LNG plant. An interim solution adopted was to barge the produced water to the oil and gas export terminal, with an associated OPEX cost of ca. US$2Mln/month. Upon further review of an alternate barging option, this option was considered too expensive, inefficient and unsustainable with inherent HSSE exposure. Therefore, a produced water re-injection project was scoped and executed as a viable alternative to produced water management. This option was supported by the Regulators as a preferred option for produced water management for the industry.

ANALYSIS OF THE USE OF ULTRASONIC TESTING METHODS IN THE FRAMEWORK OF CORROSION MONITORING OF INTERNAL CORROSION AT GAS PRODUCTION FACILITIES IN THE PRESENCE OF CARBON DIOXIDE

2020 ◽  
pp. 30-35
Author(s):  
D. N. Zapevalov ◽  
R. K. Vagapov
Keyword(s):  
Carbon Dioxide ◽  
Oil And Gas ◽  
Thickness Measurement ◽  
Gas Production ◽  
Corrosion Monitoring ◽  
Internal Corrosion ◽  
Ultrasonic Methods ◽  
Ultrasonic Thickness Measurement ◽  
Gas Fields ◽  
Production Facilities

The use of various intrusive and non-intrusive methods of corrosion monitoring makes it possible to assess the corrosion situation and the effectiveness of the applied corrosion protection agents in conditions of internal corrosion at gas production facilities due to the presence of aggressive gases. The analysis of the application of ultrasonic testing methods as part of corrosion monitoring of internal corrosion at gas production facilities in the presence of corrosive components is carried out. Ultrasonic thickness measurement is widely used as a non-intrusive method for monitoring internal corrosion and detecting corrosion defects in promising gas fields. Many gas fields (Bovanenkovskoye oil and gas condensate field, Urengoy oil and gas field and others) revealed corrosion defects due to cases of internal corrosion due to the presence of increased amounts of carbon dioxide in the produced hydrocarbons. Under conditions of corrosion in the presence of carbon dioxide, ultrasonic methods for measuring the thickness of a metal have certain limitations associated with the unpredictable local nature of carbon dioxide corrosion, which should be considered when used in gas facilities. The main method for measuring thickness under operational conditions is ultrasonic thickness measurement, which is used in conjunction with radiographic monitoring. Using these two main non-intrusive methods, corrosion monitoring monitors the thinning of the metal, the size and depth of local defects and the dynamics of their change over time. Based on the results of measuring the residual wall thickness of the pipe and equipment, the possibility of their further work is determined, and recommendations are made on extending the safe life of gas facilities. The authors analyzed the literature data on new options and technical solutions for the use of ultrasonic methods in the measurement of the thickness of a metal surface.

scholarly journals Some challenges and opportunities for Russia and regions in terms of the global decarbonization trend

Georesursy ◽  
2021 ◽  
Vol 23 (3) ◽  
pp. 8-16
Author(s):  
Danis K. Nurgaliev ◽  
Svetlana Yu. Selivanovskaya ◽  
Maria V. Kozhevnikova ◽  
Polina Yu. Galitskaya
Keyword(s):  
Carbon Sequestration ◽  
Large Scale ◽  
Oil And Gas ◽  
Hydrogen Generation ◽  
Biological Systems ◽  
Energy Transition ◽  
Gas Production ◽  
High Tech ◽  
Oil And Gas Production ◽  
Testing Area

This article discusses a possible scenario of energy transition in Russia, taking into account the economic structure, presence of huge oil and gas infrastructure and unique natural resources. All this allows to consider global trends of energy and economic decarbonization not only as a challenge, but also as a new opportunity for the country. Considering developed oil and gas production, transportation, refining and petrochemical infrastructure, as well as the vast territory, forest, water and soil resources, our country has unique opportunities for carbon sequestration using both biological systems and the existing oil and gas infrastructure. It is proposed to use the existing oil and gas production facilities for hydrogen generation in the processes of hydrocarbon catalytic transformation inside the reservoir. It is suggested to create and use large-scale technologies for CO2 sequestration using existing oil and gas production infrastructure. Considering high potential of the Russian Federation for carbon sequestration by biological systems, a network of Russian carbon testing areas is being developed, including one at Kazan Federal University (KFU), – the “Carbon-Povolzhye” testing area. The creation of carbon farms based on the applications at such testing areas could become a high-demand high-tech business. A detailed description of the KFU carbon testing area and its planned objectives are given.

Sign in / Sign up

Export Citation Format

Share Document