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Far Eastern Federal District
You've read it in the editorials of JPT or heard it preached from the podium at one of the industry's technical conferences over the years: The oil and gas industry is notoriously slow to innovate and adopt new technologies. Since 1999, the slow-moving oil and gas industry has only managed to push the needle from 75 million B/D to more than 102 million B/D--a remarkable 36% increase in global supply. This growth came in spite of what turned out to be fairly valid concerns openly expressed by many a quarter century ago that all the so-called "easy oil" had been discovered. Much of the world's new supply indeed flows out from complex and/or difficult-to-access reservoirs that in 1999 were far from the minds of most. This includes the rise of the North America's tight oil and gas plays, the deepwater sector, and a myriad of other megaprojects from Sakhalin to Kashagan to Manifa that have each pushed the petroleum engineering envelope to new limits.
- Asia > Middle East (0.47)
- Asia > Russia > Far Eastern Federal District > Sakhalin Oblast (0.25)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drilling Equipment (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- (7 more...)
Features of Modeling the Load from Hummocks in the Ice Basin
Bekker, Alexander T. (Far East Federal University, Vladivostok) | Anokhin, Pavel V. (Far East Federal University, Vladivostok) | Sabodash, Olga A. (Far East Federal University, Vladivostok) | Nechiporenko, Grigoriy Yu. (Far East Federal University, Vladivostok) | Kornishin, Konstantin A. (Arctic Research Centre, Moscow) | Efimov, Yaroslav O. (Arctic Research Centre, Moscow) | Tarasov, Petr A. (Arctic Research Centre, Moscow) | Demidov, Valentin A. (Arctic LNG 2)
_ This article deals with the modeling of the impact in the ice basin on offshore oil and gas structures (OOGS) from the hummock, the field data of which were studied during Arctic expeditions in the Khatanga Bay of the Laptev Sea. The ice basin is located in the ice laboratory at the Far Eastern Federal University (FEFU) in Vladivostok. The room is equipped with a modernized freezer, which allows one to maintain a given temperature regime quickly and in a wide range to control the mode of freezing ice. The ice basin allows for the modeling of hummocks on an acceptable scale. A rectangular steel indenter was used as a model of the structure. Models of hummocks were made according to a specially developed technology. The methodology for conducting model tests in the ice basin included the manufacture of hummock models, testing by introducing an indenter into the body of a hummock model with a given speed, registration of the required parameters of the experiment (contact force, speed of movement of the indenter, geometric dimensions of the hummock model, and physical and mechanical properties of the ice formation model), and photo and video fixation of the process of interaction of the indenter with the model hummock above and below water. A total of eight experiments were conducted. The study was carried out in compliance with the similarity criteria—geometric, kinematic, and dynamic—to recalculate the results from model tests to full-scale values. The results obtained can be used in the analysis of the processes of ice load formation at the OOGS on the shelf of freezing seas.
- Europe (1.00)
- North America > United States > California (0.46)
- Asia > Russia > Far Eastern Federal District > Primorsky Krai > Vladivostok (0.24)
- Research Report > New Finding (0.66)
- Research Report > Experimental Study (0.48)
Justifying the applicability of conformance control technologies in terrigenous reservoirs of Eastern Siberia (Russian)
Cherepanova, N. A. (Tyumen Petroleum Research Center LLC) | Kochetov, A. V. (Tyumen Petroleum Research Center LLC) | Tagirov, K. D. (Tyumen Petroleum Research Center LLC) | Krever, A. S. (Tyumen Petroleum Research Center LLC) | Ivanov, E. N. (Taas-Yuryakh Neftegazodobycha LLC) | Kopylov, A. V. (Taas-Yuryakh Neftegazodobycha LLC)
The reservoir heterogeneity in terms of permeability and availability of high-water-cut wells in the Botuobinsky horizon within the Eastern Siberia fields determines the need for introducing conformance control by creating seals and barriers to the injected water in the flushed zones of the formation. The Eastern Siberia reservoirs are generally characterized by low reservoir temperatures and high salinities of formation water. The paper describes the results of laboratory studies of cross-linked polymer systems in low-temperature formations (12 °C) with high salininy of formation water (up to 400 g/l). It also presents the technologies based on high-molecular polymers of partially hydrolyzed acrylamide with chromium-salts-based crosslinking agents. Laboratory tests and simulations have confirmed the performance of polymer-based conformance control technologies for the Bt reservoir of Srednebotuobinskoye field. The polyacrylamide (PAA) brands available on the domestic market dissolve in 140 g/l formation water, and, as part of solutions with chromium acetate, form strong structured gels at low reservoir temperatures. At reservoir temperatures of 10-12 °C, the gelling time increases up to 3-4 days. The rheological parameters of cross-linked gels at low temperatures are comparable to the strength of gels which are structured at elevated temperatures. Structured PAA gels under the influence of high-salinity water are not subject to destructive changes at low reservoir temperatures. The highly permeable cores of the Botuobinsky horizon were used in physical modeling units and allowed to demonstarte the ability to create high water flow resistances using cross-linked polymer systems. The results of rheological tests and flow experiments allow to recommend cross-linked polymers for injection into the Botuobinsky horizon rocks. A pilot program has been developed, candidate wells have been selected for technology testing, the volume of polymer slug and the well shut-in period required for structuring have been determined, and incremental oil production has been estimated.
ABSTRACT In ice gouging analyses, the seabed is usually represented by a uniform material domain ignoring the complexities and implications that may arise from layered seabeds that are quite common in many of the Arctic geographical locations. In this study, the response of different layered seabed comprising soft over stiff clay, stiff over soft clay, and the loose and dense sand over soft and stiff clay to the ice gouging were investigated by performing large deformation finite element (LDFE) analysis using a Coupled Eulerian Lagrangian (CEL) algorithm. The study showed the significance of considering seabed layers in ice gouging analysis. INTRODUCTION Floating icebergs or ice ridges during their long trip from Arctic oceans reach the shallow waters and start scouring the sea bottom by the ice keel tip. This is called "ice gouging", an Arctic seabed geohazard that may jeopardize the structural integrity of subsea pipelines. Pipelines are buried below the deepest potential gouge depth for physical protection. However, due to the shear strength of the soil, the subgouge soil displacement may significantly extended deep through the soil. Determining the optimum burial depth for protection against iceberg attack is a challenging design aspect of Arctic offshore pipelines. The pipe response to ice gouging is currently determined by a decoupled approach in engineering practice. For this purpose, first, a free-field (with no pipeline) ice gouging analysis is conducted using continuum large deformation finite element analysis (LDFE). Then the obtained subgouge soil deformations are transferred to the end of a set of springs connected to a simple beam-spring model to capture the pipeline structural response (Woodworth-Lynas et al., 1996; Phillips and Barrett, 2012). Although the accuracy of this approach suffer from the superposition of idealization and directional load decoupling as two sources of errors (Konuk and Gracie, 2004; Nobahar et al., 2007b; Lele et al., 2011; Peek and Nobahar, 2012; Phillips and Barrett, 2012; Eltaher, 2014; Pike and Kenny, 2016), but this is still cost-effective solution that compromise some level of accuracy and is followed by the pipeline industry. The accurate simulation of free-field ice gouging can have a significant impact on the ultimate results in the decoupled method. In free-field ice gouging analysis, the seabed stratum is usually simplified by uniform soil. This can be a gross simplification in the areas with complex layered seabed strata. Modeling the ice gouging in layered seabed such as soft over stiff clay, stiff over soft clay, and sand over clay has not been sufficiently explored in the literature while such a non-uniform soil strata have been broadly observed in offshore Arctic areas with lots of gouging signatures (e.g., Chukchi Sea (Winters and Lee, 1984; C-CORE, 2008); Alaskan Beaufort Shelf (C-CORE, 2008); Russian Sakhalin Island (C-CORE, 1995e) etc.) (see Figure. 1).
- North America > United States > Colorado > Cheyenne County (0.44)
- Asia > Russia > Far Eastern Federal District > Sakhalin Island > Sea of Okhotsk (0.24)
- North America > Canada > Quebec > Arctic Platform (0.93)
- North America > Canada > Nunavut > Arctic Platform (0.93)
The Pre-Verkhoyansk foredeep is territorially confined to the Republic of Sakha (Yakutia), in tectonic terms it is part of the Siberian Platform, being its eastern frame, its area is 520 thousand km2. According to the oil and gas geological zoning, the study area belongs to the Predverkhoyansk oil and gas region, which is part of the Leno-Vilyui oil and gas province. The trough stretches from the lower reaches of the Lena River to the middle course of the Aldan River. The shape of the deflection resembles an arc. The geological study of the Pre-Verkhoyansk foredeep territory begins at the end of the 40s and the beginning of the 50s of the last century. In 1951 specialists of the Yakutsk Geological Administration drew up a long-term plan for prospecting and exploration of oil and gas for 1955-1960. During the implementation of the plan, two deposits were discovered: Ust-Vilyuiskoye (1956) and Sobo-Khainskoye (1961). Parametric drilling was carried out on the territory of the trough, and seismic surveys were carried out using the common depth point method in the basin of the river Sobolokh-Mayan in the 70-80s, however, as a result of these and subsequent exploration, no commercial accumulations of hydrocarbons were discovered. Thus, the high prospects for the oil and gas potential of the Predverkhoyansk foredeep have not been proven at present. The authors carried out 3D basin modeling on the basis of published data on the territory of the Republic of Sakha (Yakutia) within the Lena branch of the Predverkhoyansk trough. Qualitative and quantitative criteria are analyzed and described for the prospects for oil and gas in the study area. Recommendations on promising areas of exploration work are presented. Schlumberger PetroMod software was used for basin modeling. Based on the results of the performed 3D modeling, the following oil and gas conditions were analyzed: paleostructural, lithofacies and geochemical conditions. The catagenetic evolution, the degree of depletion of the generation potential of oil and gas source rocks are also considered, the processes of migration and accumulation of hydrocarbons are evaluated.The Pre-Verkhoyansk foredeep is territorially confined to the Republic of Sakha (Yakutia), in tectonic terms it is part of the Siberian Platform, being its eastern frame, its area is 520 thousand km. According to the oil and gas geological zoning, the study area belongs to the Predverkhoyansk oil and gas region, which is part of the Leno-Vilyui oil and gas province. The trough stretches from the lower reaches of the Lena River to the middle course of the Aldan River. The shape of the deflection resembles an arc. The geological study of the Pre-Verkhoyansk foredeep territory begins at the end of the 40s and the beginning of the 50s of the last century. In 1951 specialists of the Yakutsk Geological Administration drew up a long-term plan for prospecting and exploration of oil and gas for 1955-1960. During the implementation of the plan, two deposits were discovered: Ust-Vilyuiskoye (1956) and Sobo-Khainskoye (1961). Parametric drilling was carried out on the territory of the trough, and seismic surveys were carried out using the common depth point method in the basin of the river Sobolokh-Mayan in the 70-80s, however, as a result of these and subsequent exploration, no commercial accumulations of hydrocarbons were discovered. Thus, the high prospects for the oil and gas potential of the Predverkhoyansk foredeep have not been proven at present. The authors carried out 3D basin modeling on the basis of published data on the territory of the Republic of Sakha (Yakutia) within the Lena branch of the Predverkhoyansk trough. Qualitative and quantitative criteria are analyzed and described for the prospects for oil and gas in the study area. Recommendations on promising areas of exploration work are presented. Schlumberger PetroMod software was used for basin modeling. Based on the results of the performed 3D modeling, the following oil and gas conditions were analyzed: paleostructural, lithofacies and geochemical conditions. The catagenetic evolution, the degree of depletion of the generation potential of oil and gas source rocks are also considered, the processes of migration and accumulation of hydrocarbons are evaluated.
- Geology > Sedimentary Basin (1.00)
- Geology > Geological Subdiscipline > Geochemistry (0.94)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.44)
Russia's largest independent gas producer, Novatek, is poised to acquire Shell's 27.5% stake in the Far East Sakhalin-2 gas and LNG project after the Kremlin greenlighted a scheme enabling Novatek to legally transfer the 1.21-billion purchase price to the supermajor. Novatek applied to the Russian government on 3 April to acquire Shell's unallocated shares in Sakhalin Energy LLC, the project operator. The next day, President Vladimir Putin consented to a process allowing Novatek to legally transfer the 1.21 billion (94.8 billion rubles) agreed by all sides to Shell from Novatek's foreign currency account, as reported by Russia's Kommersant business daily, citing sources familiar with the matter. Leonid Mikhelson, Novatek's CEO and chairman, suggested the payment scheme to which Putin later agreed, Kommersant wrote. Making the payment to settle the purchase requires Kremlin approval because under a presidential decree of 30 June 2022, Shell can only receive money transfers to a type "C" account in Russia, where the funds will remain blocked. In June, Putin signed a decree transferring all rights and obligations of the former operator of the Sakhalin-2 project, Bermuda-registered Sakhalin Energy Investment Company Ltd., to a specially created Russian limited liability company, Sakhalin Energy LLC. Gazprom became the owner of the controlling stake in the new company.
- Government > Regional Government > Europe Government > Russia Government (1.00)
- Government > Regional Government > Asia Government > Russia Government (1.00)
- Energy > Oil & Gas > Midstream (1.00)
Russia and China are nearing agreement on a 2024 construction start for the long-discussed 6700 km Power of Siberia 2 (PoS2) pipeline that would deliver Russian gas from West Siberia, previously designated for European export, to industrial areas north of Beijing via Mongolia by 2030. The proposed pipeline's 50 Bcm/year capacity nearly matches that of the 55 Bcm/year Nord Stream 1 which had carried a third of Russian gas deliveries to the EU before being shut down in September. Once built, PoS2 would double Russia's current gas exports to China as it would join up with the Russian gas network that connects to the Yamal Peninsula (West Siberia), enabling Russia to direct gas to markets east or west at will. After 3 days of talks in Moscow with Chinese President Xi Jinping in March, Russia's President Vladimir Putin announced that "nearly all parameters" have been decided to proceed with PoS2. Authorities anticipate a 2024 construction start.
- Asia > Russia > Far Eastern Federal District (1.00)
- Asia > China > Beijing > Beijing (0.28)
- Europe > Russia > Central Federal District > Moscow Oblast > Moscow (0.26)
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- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Midstream (1.00)
- Government > Regional Government > Europe Government > Russia Government (0.70)
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- Asia > Russia > Siberian Federal District > Irkutsk Oblast > Irkutsk Basin > Kovyktinskoye Field (0.99)
- Asia > Russia > Far Eastern Federal District > Sakhalin Island > Sea of Okhotsk > East Sakhalin - Central Sea of Okhotsk Basin > North Sakhalin Basin > Kirinsky Block > Kirinskoye Field > Kirinskoye Formation (0.99)
- Asia > Russia > Far Eastern Federal District > Sakha Republic (Yakutia) > East Siberian Basin > Nepa-Botuoba Basin > Chayandinskoye Field (0.99)
Identification of high-molecular weight naphthenic acids in crude oil and methods of management of their calcium salts depositson Sakhalin-2 project assets (Russian)
Kunaev, R. U. (Sakhalin Energy LLC) | Glukhova, I. O. (Sakhalin Energy LLC) | Patrushev, M. G. (Institute of Chemistry, Far-East Branch of the RAS) | Sukhoverkhov, S. V. (Institute of Chemistry, Far-East Branch of the RAS)
Since the early 2000s in the world practice of offshore oil and gas production, the problem of deposits of high-molecular naphthenic acids calcium salts in process facilities of offshore platforms has become known. The rapid formation and accumulation of naphthenic acids calcium salts in oil treatment units (separators, coalescers) can cause disruption of oil production at offshore fields of the Russian Federation and in the production of heavy biodegradable oil onshore. At the Sakhalin-2 project facilities, such deposits were discovered in 2015 and unambiguously identified in 2020. The emulsions discovered in 2015 significantly worsened the oil preparation process and required increased demulsifier consumption. The deposits blocked process units (separators and coalescers) and reduced their throughput; this is led to a long-term annual shutdown of equipment for its purification. It has been proposed that the recovered deposits were products of undesirable interaction of produced oil and drilling fluids components or reaction products in the use of polymeric scale inhibitors. In 2019-2020 a deep analysis of the component composition of the formed sediments and, in particular, the search for "atypical" components was carried out. Obtained data showed that one of the likely causes of sediment formation may be naphthenic acids calcium salts. The composition of sediments from process units on the Piltun-Astokhskaya-B platform of Sakhalin Energy LLC has been investigated via several modern instrumental analytical methods. In addition, identification and semi-quantitative determination of high-molecular naphthenic acids by IR spectroscopy and HPLC/MS in oil were performed. The field trial of a reagent based on tetrakis (hydroxymethyl) phosphonium sulfate (THPS) as an inhibitor of naphthenate deposits finished, the reagent confirmed its effectiveness, and a program for its use was developed.
Determination of hydrate-free conditions for mineralized water injection at Eastern Siberian field (Russian)
Semenov, M. E. (Kazan (Volga Region) Federal University) | Stoporev, A. S. (Kazan (Volga Region) Federal University) | Bolotov, A. V. (Kazan (Volga Region) Federal University) | Kovalenko, V. A. (Gazpromneft STC LLC) | Kolpakov, V. V. (Gazpromneft STC LLC) | Belysh, A. V. (Gazpromneft-Zapolyarye LLC) | Varfolomeev, M. A. (Kazan (Volga Region) Federal University) | Anikin, O. V. (Kazan (Volga Region) Federal University)
The development of oil and gas fields can be complicated by forming gas hydrates at the bottom, in the downhole zone, and in wellbores. It is reliably known that gas hydrate issues during production occur in many Eastern Siberian fields characterized by low reservoir temperatures. Current research in this direction is limited to predicting the gas hydrates formation depending on the thermobaric conditions of well operation. The influence of salt solutions injection into the reservoir under the Chayandinskoye oil-gas-condensate field conditions (pressure and temperature) is studied in order to establish the boundary level of water mineralization preventing the hydrate formation. The calculation of equilibrium conditions for the formation of gas hydrates of the model gas of the Chayandinskoye field and mineralized water from water wells and formation water of the Srednebotuobinskoye field is compared with experimental data in high-pressure autoclaves, which established "safe" in terms of complete prevention of hydrate formation threshold concentrations of 16 wt. % and 20.1 wt. % at reservoir temperature 9 °С and pressures 13 and 30 MPa, respectively. The modes and criteria for nucleation and formation of gas hydrates in the flow and in the static mode are determined using a slim-tube model of two-phase flow of model gas and water of varying salinity. The final result in this work was the determination of a threshold level of brine salinity guaranteeing the absence of hydrate complications of brines at the contact between the liquid phase and the gas-cap gas in the wellbore, ensuring a hydrate-free flow regime in the reservoir conditions of the Chayandinskoye field. The data obtained will form the basis of subsequent tests on core models to assess the risks of hydrate formation in the porous medium when salinity water is injected into the reservoir.
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.40)
- Asia > Russia > Far Eastern Federal District > Sakha Republic (Yakutia) > East Siberian Basin > Nepa-Botuoba Basin > Kurugunsky License Block > Srednebotuobinskoye Field (0.99)
- Asia > Russia > Far Eastern Federal District > Sakha Republic (Yakutia) > East Siberian Basin > Nepa-Botuoba Basin > Chayandinskoye Field (0.99)