|Theme||Visible||Selectable||Appearance||Zoom Range (now: 0)|
Though expensive and complex, extended-reach drilling (ERD) is moving more into the mainstream as the industry is driven to develop frontier reserves in fragile environments like the Arctic where drilling from shore to offshore targets reduces a project's infrastructure costs and environmental footprint. A form of directional drilling, ERD is also being used increasingly to tap into hard-to-produce reservoirs, making viable projects that might otherwise be written off as noncommercial. This article highlights how the Russian Far East became the ERD epicenter in the past decade, given ExxonMobil and Rosneft's extensive use of ERD in developing Arctic resources offshore Sakhalin Island, and how ERD is becoming more widely used in regions as diverse as the Gulf of Thailand, offshore Brazil, and the Arab Gulf. By definition, an extended-reach well (ERW) is one in which the ratio of the measured depth (MD) vs. the true vertical depth (TVD) is at least 2:1 (PetroWiki). An ERW differs from a horizontal well in that the ERW is a high-angle directional well drilled to intersect a target point, a feat requiring specialized planning to execute well construction.
Russia has taken its first steps toward regulating carbon emissions since joining the Paris climate accords in 2019 with President Vladimir Putin's signing of legislation in early July requiring the country's largest greenhouse-gas emitters (GHG) to report carbon data to a new government agency. The new law makes carbon reporting mandatory as of January 2023 for companies emitting 150,000 tons of carbon or more, and January 2025 for carbon emitters in the 50,000 to 150,000 range, according to the Russian news agency TASS. "An accounting system is being introduced, carbon dioxide is becoming a substance subject to government regulation," Greenpeace spokesman Vladimir Chuprov told Reuters. "An emissions accounting and reduction system is emerging. This is a prerequisite for a greenhouse-gas emissions trading system."
India is on track to overtake China within the next year or two as the world's most populous nation, pandemic or not. So, while near-term forecasts suggest that the current health crisis has slowed industrial growth, and thus muted the expected rise in demand for energy, India's baseline metrics are not likely to change, nor will the country's impact on global energy markets. By 2040, India will be the world's biggest energy consumer, and the country is betting on natural gas, developed in parallel with renewable energy, to reduce its carbon footprint, which, in 2020, saw India ranked third in greenhouse gas (GHG) emissions after China and the United States, according to the International Energy Agency's (IEA) India Energy Outlook 2021. Gas demand is growing, too, as the Indian government sees gas as critical to controlling carbon emissions while it develops renewables in parallel to provide energy to a population that is forecast to grow to 1.6 billion by 2040. Now fast-forward to 2040 when India is projected to account for 25% of the growth in world energy demand, more than any other country, according to the IEA's Sustained Energy Policy Scenario outlined in its 2021 outlook.
Shareholders of Russia's second-largest gas producer, Novatek, have approved $11 billion in external financing for the Arctic LNG 2 project on which Novatek has pledged its 60% equity stake in the project as collateral. The approval came 23 April at the company's annual shareholders' meeting. In making the announcement, Novatek CEO Leonid Mikhelson said that responsibility for fundraising will be split three ways between Russia, China, and the tandem of Japan and Europe acting together. The $21-billion project, which received final investment approval in 2019, is expected to launch production in 2023 as Novatek expands its LNG exports east and west along Russia's now navigable Arctic coast. Arctic LNG 2 will reach full capacity of almost 20 mtpa in 2026, according to the company.
Abstract Well test is one of the crucial steps required to forecast production investments of their fields. However, the operators face many challenges such as reduced capex, exploration budgets, and bad weather conditions that limit the well testing time window. To overcome these challenges, an automated well testing platform enabled a real time monitoring and controlling more zones in a single run for appraisal wells in the Sea of Okhotsk, Russia. This article highlights the test objectives, the job planning, and automated execution of wirelessly enabled operations in very hostile conditions and limited time period. The use of a telemetry system to well test seven zones allowed real-time data acquisition, control of critical downhole equipment, data transmission to the operator's office in town. Various operational cases will be discussed to demonstrate how automated data acquisition and downhole operations control has optimized operations for both the service company and the operator.
Rosneft's planned sale of three underperforming oil assets by the end of May has a lot more to do with Russia's desire to dominate future LNG markets globally, than it does any routine tweaking of the company's portfolio. Russia's largest oil producer (in which BP holds a 19.75% ownership stake) has made no secret of its LNG ambitions. Rosneft and BP cooperate under a "Strategic Gas Partnership" created in 2017 to "jointly implement gas projects in both Russia and abroad, focused on gas exploration and production, LNG production, supply and marketing," according to BP's website. The reason for cooperation is obvious as analytical forecasts are clear that, while oil is on the way out, the demand for natural gas in all of its forms--including as a feedstock to produce blue hydrogen--will grow and play the lead role (together with renewables) in powering the world economy by mid-century. So it was no surprise when Rosneft announced in early March the sale of three mature, southern oil assets as part of a larger strategy to shed marginal brownfields and shift the company's investment focus to its Vostok Oil joint venture with Neftegazholding – an Arctic play likely to cost upwards of $150 billion dollars in investment in a project comparable in size to the exploration of West Siberia in the 1970s or the US Bakken shale play of the last decade.
Gorbachev, S. V. (RN-Shelf-Arctic LLC) | Nikulnikov, A. Yu. (RN-Shelf-Arctic LLC) | Kornev, A. S. (CGG Vostok LLC) | Nurmukhamedov, T. V. (RN-Shelf-Arctic LLC) | Myasoedov, D. N. (RN-Shelf-Arctic LLC) | Ulyanov, G. V. (RN-Shelf-Arctic LLC) | Samarkin, M. A. (Rosneft Oil Company)
In recent years, technologies of marine seismic data processing have made a huge leap due to rapid growth of computing power. Many algorithms for signal processing and depth imaging, which had no practical implementation before, now can be applied. Therefore, the question of their proper usage in the processing workflow and quality control of the results becomes as actual as never before. This paper shows an example of marine seismic data processing, acquired in different years offshore Sakhalin Island, which is characterized by complex geological conditions with the presence of near-surface gas in the upper layers of sedimentary rocks and variable acoustic characteristics of the water bottom. In the workflow various signal processing and imaging algorithms were used to improve the quality of data in order to increase the spatial and dynamic resolution for the prediction of reservoir characteristics. The ghost and multiple waves suppression, the results of the dynamic characteristics of different surveys matching are described in detail. Key results of velocity model building and prestack depth migration are also given. In conclusion, a comparison of the results of previous and new processing is given and allows to conclude that usage of modern technologies improved the dynamic characteristics and increased the resolution in the target intervals while preserving true signal characteristics. The processing approach implemented by Rosneft employees made it possible to significantly detail the geological structure of prospective deposits and identify new local prospecting targets.
Glotov, A. V. (TomskNIPIneft JSC) | Michailov, N. N. (Oil and Gas Research Institute of RAS) | Molokov, P. B. (National Research Nuclear University MEPhI) | Lopushyak, Yu. M. (Mayskoye Gold Mining Company LLC) | Shaldybin, M. V. (TomskNIPIneft JSC)
Evaluating of core saturation in case of oil source rocks of the Bazhenov formation by standard methods is not trivial task that hinders systematic measurements. An example is the existing method of distilling water in the Zaks (or Dean-Stark) apparatus, which does not allow to determine small amounts of water with high accuracy, in addition, the method is not "in-line" - it takes up to a week for one measurement. This leads to use for reserve calculation and planning mining values of oil saturation, which are not confirmed by actual data or determined on single core samples. The method was offered authors, based on combination of thermal and spectrometric techniques, let allowed measuring water saturation and oil saturation for core 12 oil fields. The results obtained indicate about significant variation in saturation by cross section of the Bazhenov formation, and the modal values of water saturation exceed those, that are usually used for reserve calculation. «Scale» factor significantly influences on the core properties, and actual values of water saturation may be higher. The degree of mobility of water in open porous space is important value. Established opinion that all water in the Bazhenov formation is associated with clays minerals is not confirmed by specially conducted researches. The dependence of water content and clayiness is linear with a high dispersion. The lowest values of water content tend to highly siliceous and carbonate rock, and the water in open voids is rather capillary-bound. The obtained values of chemically bound water released in process decomposition of minerals and transformation organic matter during heating, indicate high water content in closed pores. Studying of the features of water release in the temperature range corresponding to the decomposition (pyrolysis) of organic matter and minerals showed the presence of a large amount of water in closed pores.
The Severo-Labatyuganskoye oil field is one of the oilfields, which development began at the beginning of the XXI century. At this period the concept of sustainable development was formulated, that means the rational use of natural resources and the environmental protection. One of the key elements of sustainability is the regular environmental monitoring and transparency. Surgutneftegas PJSC keeps the same way with these ecological innovations. On the territory of all oil fields in Russia Federation the Company performs systematic ecological monitoring. The results of researches are annually published in different open information sources. Despite the high cost of researches, that increase the final cost of extracted oil, monitoring is performed statedly. It is necessary because of high importance of measures for environmental protection. The longer the research time, the more accurate it is possible to draw a conclusion about the impact of economic activities on the environment. This also applies to the territory of the Severo-Labatyuganskoye field, which has been developed for 20 years. The observation period within the framework of the program for monitoring the state of natural environments at the field is even longer. The experience in the development of the Severo-Labatyuganskoye field has shown that hydrocarbon production did not lead to a change in the initial state of natural environments. The current environmental indicators are in the same ranges as the background ones. The indigenous small-numbered peoples of the North continue to engage in traditional crafts on the territory of the Severo-Labatyuganskoye field.
The scientific article discusses the advantages of using modular equipment in the implementation of projects in the oil and gas industry. The technology of a mobile free water knock out is presented, which was developed by LLC AETC «Sapphire» within the framework of innovative activities of Rosneft Oil Company with the participation of specialists from the TomskNIPIneft Specialized Institute for Oil Field Development Technologies. The main task of the mobile free water knock out (MFWKO) is the primary preparation of the formation fluid directly at the field, near the well pad, while excluding the transport of ballast - produced water to the central processing and collection point. The developed solution is based on a unique technology that allows temporarily placing a set of equipment with the ability to quickly mount / dismantle and relocate to other facilities by road and rail. At the same time, technological equipment is placed in interconnected block-modules in the form of standard transport containers of full factory readiness using quick-disconnect couplings and flexible pipelines. The requirements for the placement of the complex are minimal; installation is carried out on a base of road slabs. MFWKO can be used both in the study of remote wells and wells during the trial operation, and in the development of small fields and fields at an early stage of the development. The scientific article presents the results of pilot industrial tests of the MFWKO, which were carried out at the site of Tyumenneftegas JSC in June 2020. The indicator of water and oil quality at the outlet from the MFWKO corresponded to the technical task, the design of the internal devices of the blocks ensured the implementation of the separation process for the preparation of oil and water, and a reserve for the productivity of the MFWKO was also ensured.