Нефтеналивной танкер «Академик Губкин» вышел на ходовые испытания

  • Market: Crude oil, Oil products
  • 24/04/23

Судостроительный завод «Звезда» (Большой Камень, Приморский край) приступил к ходовым испытаниям нефтеналивного танкера «Академик Губкин» дедвейтом 114 тыс. т, который относится к типоразмеру Aframax и строится по заказу «Роснефтефлота», судоходного подразделения «Роснефти».

Танкер «Академик Губкин» имеет ледовый класс 1А и предназначен для перевозки нефти и нефтепродуктов в неограниченном районе плавания. Длина судна составляет 250 м, а ширина — 44 м. Танкер может работать как на традиционном судовом топливе, так и на сжиженном природном газе (СПГ). Грузовместимость танкера составляет 130 тыс. м³ сырья, по данным «Звезды».

Ходовые испытания являются финальным этапом проверки двигателей танкера и его скоростных характеристик, тестирования систем жизнеобеспечения и навигации. Ранее «Академик Губкин» успешно прошел швартовные испытания.

«Академик Губкин» — это четвертое судно в серии танкеров Aframax, которые строятся на «Звезде». Открытие первой очереди самой верфи «Звезда» состоялось в 2016 г., а контракты на строительство судов типа Aframax были заключены в 2016-2017 гг. До этого танкеры Aframax в России не строились.

Подписанные «Звездой» контракты предполагают строительство 12 танкеров типоразмера Aframax, из которых 10 должны поступить в распоряжение «Роснефтефлота», а два предназначены для судоходной компании «Совкомфлот».

«Роснефтефлот» уже получил два судна из этого заказа: в конце 2020 г. компания приняла в эксплуатацию танкер «Владимир Мономах», а в конце 2021 г. — судно «Владимир Виноградов». «Совкомфлот» в конце 2022 г. получил первое судно из своего заказа – танкер «Океанский проспект». Церемония имянаречения судов «Океанский проспект» и «Академик Губкин» состоялась в сентябре 2022 г., она была приурочена к датам проведения Восточного экономического форума (ВЭФ) во Владивостоке.

По данным участников рынка, «Роснефть» разместила танкер «Владимир Мономах» в нейтральных водах порта Кавказ (Краснодарский край, outside port limits), где он используется как накопитель для формирования более крупных партий из нефтепродуктов, которые доставляются из портов Азовско-Черноморского бассейна малотоннажными танкерами и для речных объемов в период начавшейся навигации.

Танкер «Океанский проспект» в конце января взял на борт первую партию нефти сорта Смесь ВСТО объемом около 100 тыс. т для перевозки из дальневосточного порта Козьмино в Китай, по данным судовых агентов.

«Роснефть» управляет проектом по развитию судостроительного комплекса «Звезда» и является крупнейшим заказчиком продукции этого завода. Общий портфель заказов верфи насчитывает более 60 различных судов, из которых 28 строятся для «Роснефти».

Помимо нефтеналивных танкеров, газовозов и многофункциональных судов снабжения, «Звезда» будет строить атомные ледоколы серии «Лидер» для государственной корпорации «Росатом». Эти ледоколы с двигателями 120 МВт станут самыми мощными в России и в мире, сдача в эксплуатацию первого из них запланирована на 2027 г.

На верфи «Звезда» в настоящее время функционируют блок корпусных производств, окрасочные камеры, открытый тяжелый достроечный стапель и самый крупный в России сухой док, а также ведется строительство объектов второй очереди.


Sharelinkedin-sharetwitter-sharefacebook-shareemail-share

Related news posts

Argus illuminates the markets by putting a lens on the areas that matter most to you. The market news and commentary we publish reveals vital insights that enable you to make stronger, well-informed decisions. Explore a selection of news stories related to this one.

News
09/05/24

Singapore's GCMD to test long-term biofuel shipping use

Singapore's GCMD to test long-term biofuel shipping use

Singapore, 9 May (Argus) — Singapore-based Global Centre for Maritime Decarbonisation (GCMD) and Japanese shipping firm NYK Line will trial the continuous use of a biofuel blend over six months. The study aims to evaluate the effects of the continuous use of B24 biofuel blend of 24pc fatty acid methyl ester (Fame) and 76pc of very low sulphur fuel oil (VLSFO) on a short-sea vehicle carrier that will call at multiple ports, allowing for the regular sampling and testing of fuels stored on the ship. Fame is a "promising" fuel alternative, the firms said, but added that there are concerns about the impact of its extended use on vessel operations. The study hence aims to study the long-term impact of biofuel usage on ship engine performance and fuel delivery system operations. It will also examine the total cost of ownership of using biofuel, including fuel costs and associated maintenance costs, as well as identify potential operating challenges and suggest mitigation strategies. B24 is the current blend of alternative marine fuel that is being used or trialled for bunkering at some key Asian ports like Singapore and Zhoushan. Its usage is expected to rise, especially because the industry is pushing for higher emission cuts from shipping. Participants in the shipping industry are exploring solutions to meet the International Maritime Organization's (IMO) net zero carbon emission target by 2050, with operational safety and costs surfacing as some of the key concerns of alternative fuel adoption . "This knowledge will empower stakeholders across the ecosystem, from shipowners and charterers to biofuels producers and regulators – to make more informed business and policy decisions," GCMD chief executive officer Lynn Loo said. "Ultimately, this pilot will lead to greater confidence for biofuels use at scale, accelerating progress towards decarbonising the maritime industry." Argus assessed B24 biofuel bunker prices at $744.25-759.25/t delivered on board (dob) Singapore on 8 May. By Cassia Teo Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Find out more
News

Australia’s ANZ bank to end new gas, oil lending


09/05/24
News
09/05/24

Australia’s ANZ bank to end new gas, oil lending

Sydney, 9 May (Argus) — Australia-based bank ANZ has updated its oil and gas policy, with it to no longer provide direct financing to new or expanding upstream oil and gas projects. The bank declared its new policy as part of its 2024 half-year results released on 7 May, saying it would also decline to integrate new customers primarily focused on upstream oil and gas. ANZ said that while it believes gas plays a "material and important part in meeting Australia's current energy needs and will do so for the foreseeable future", it will instead collaborate with energy customers to help finance their transition away from fossil fuels. The bank has a 26pc greenhouse gas (GHG) emissions reduction by 2030 goal and committed in 2020 to exit all lending to companies with exposure to thermal coal, either through extraction or power generation by 2030 as part of lending criteria to support the 2015 UN Paris climate agreement target of net zero GHG emissions by 2050. ANZ has however promised to consider exceptions on a case-by-case basis, if any national energy security issues arise. Australia's banks have been under sustained pressure by environmental groups to exit lending to fossil fuel projects, as upstream gas firms also face shareholder rebellions over climate action plans. But Australia's federal government has conceded gas will likely be needed post-2050 as a firming power source for renewables and industrial feedstock for some sectors. But investment in upstream exploration has been extremely low in recent years, with imports of LNG likely in southern Australia from about 2026 to meet demand for industrial users and power generation. By Tom Major Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

Japanese ethylene producers unite for decarbonization


08/05/24
News
08/05/24

Japanese ethylene producers unite for decarbonization

Tokyo, 8 May (Argus) — Japanese petrochemical producers Mitsui Chemicals, Mitsubishi Chemical and Asahi Kasei have agreed to co-operate on decarbonization of their ethylene crackers in west Japan, targeting to decide a pathway within the current April 2024-March 2025 fiscal year. They plan to accelerate carbon neutrality at Mitsubishi Chemical and Asahi Kasei's 496,000 t/yr Mizushima cracker in Okayama prefecture and Mitsui Chemicals' 455,000 t/yr Osaka cracker in Osaka prefecture. The partners aim to introduce biomass feedstocks such as biomass-based naphtha and bioethanol and low-carbon cracking fuels like ammonia, hydrogen and electricity. They said joining forces will enable them to accelerate reducing greenhouse gas emissions, although they have not yet decided any further details. Mitsui Chemicals has experience in using bio-naphtha and recycled pyrolysis oil at its Osaka cracker. Japanese petrochemical producers have increasingly united to achieve decarbonization of their production processes, which account for around 10pc of the Japanese industrial sector's carbon dioxide emissions, according to the trade and industry ministry. Mitsui Chemicals, Sumitomo Chemical and Maruzen Petrochemical agreed to study the feasibility of chemical recycling and using bio-feedstocks at the Keiyo industrial complex in Chiba. By Nanami Oki Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

Doubts abound over US midcon E15 shift: NATSO


07/05/24
News
07/05/24

Doubts abound over US midcon E15 shift: NATSO

Houston, 7 May (Argus) — An effort by eight US midcontinent states to start selling 15pc ethanol (E15) gasoline blends year-round starting in 2025 remains unlikely, according to US fuel retailer trade association NATSO. The US approved last month the request from Illinois, Iowa, Minnesota, Missouri, Nebraska, Ohio, South Dakota and Wisconsin for year-round E15 gasoline sales starting next year. But even with that approval there are many barriers to making those sales a reality, said David Fialkov vice president of government affairs for NATSO, which represents truck stops and travel center operators. This includes a lack of investment from pipelines and refiners to prepare for the changes, as well as the higher costs of separating and selling different gasoline specifications at the retail level. "I remain pessimistic that it will come to fruition," Fialkov said Tuesday at a conference held by fuel retail industry group SIGMA in Austin, Texas. Political pressure to delay or abate the change in the midcontinent states will probably continue until refiners, pipeline companies and retailers begin to make the investments necessary, said Fialkov. E15 has been available for sale across the US since 2019, but a federal court in 2021 found that the Clean Air Act offers a fuel volatility waiver to refiners to produce only 10pc ethanol gasoline. The Environmental Protection Agency (EPA) has worked around this ruling for the last two summers by issuing temporary emergency orders allowing the sale of E15 because of the war in Ukraine's squeeze on crude prices. A group of midcontinent refiners has petitioned the EPA to delay implementation of the E15 rule until the summer of 2026. The EPA has not yet ruled on the request. Fialkov said a legislative solution to the issue at the federal level would provide a clear and uniform pathway to E15, as opposed to the the EPA's rule which leaves some states still relying on the waiver and others opting to go with year-round E15. By Zach Appel Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

EPA sets new oil and gas methane reporting rules


07/05/24
News
07/05/24

EPA sets new oil and gas methane reporting rules

Washington, 7 May (Argus) — Federal regulators have updated emissions reporting requirements for oil and gas facilities as they prepare to implement a methane "waste" fee for the industry. The US Environmental Protection Agency (EPA) on Monday finalized new rules it says will improve the accuracy of data from the oil and gas sector under the federal greenhouse gas emissions reporting program. Oil and gas facility owners and operators will be required to estimate emissions from additional types of equipment under the rule, and they can draw on newer technologies, like remote sensing, to help estimate emissions. "EPA is applying the latest tools, cutting edge technology, and expertise to track and measure methane emissions from the oil and gas industry," agency administrator Michael Regan said. "Together, a combination of strong standards, good monitoring and reporting, and historic investments to cut methane pollution will ensure the US leads in the global transition to a clean energy economy." Data to support new fee The revisions to the "Subpart W" reporting requirements will be used to determine the amount of methane that will be subject to a "waste emissions charge" created by the Inflation Reduction Act. Under the law, the charge will be calculated based on the annual data that about 8,000 oil and gas sources are now required to report. The charge will begin at $900/t for 2024 methane emissions above a minimum threshold using current measurement data. It will then rise to $1,200/t in 2025 and $1,500/t in subsequent years. Industry officials had raised "serious concerns" about several aspects of the original proposal , warning it could lead to inflated emissions data. "We are reviewing the final rule and will work with Congress and the administration as we continue to reduce GHG emissions while producing the energy the world needs," American Petroleum Institute vice president of corporate policy Aaron Padilla said. The industry group previously said it will ask Congress to repeal the fee, which is only likely to occur if Republicans win control of the White House. Data collected since 2010 Oil and gas facilities have reported emissions under Subpart W since 2010. To simplify reporting, operators often count the equipment they have deployed, and use industry-wide averages to estimate emissions, in addition to other direct and indirect measurements. The industry has argued the Subpart W data is not accurate enough to collect the methane charge, which is expected to cost operators more than $6bn over the next decade. Environmental groups have had their own criticisms of the data, which they say omits vast amounts of emissions such as those from "super-emitter" events and poorly maintained flares. The final rule seeks to respond to some of those concerns by relying on updated emission factors, incorporating additional empirical data on emission rates, collecting data at a more granular level and relying on remote sensing technologies to detect large emission events. EPA also revised Subpart W to include more types of sources, including produced water tanks, nitrogen removal units and crankcase venting. The final rule also sets a threshold of 100 kg/hr of methane for requiring the reporting of emissions from "other large release events." The new data rules will take effect on 1 January 2025 and will first apply to reports submitted in early 2026 for next year's emissions. EPA is allowing the use of the new methodologies for calculating 2024 emissions, but operators can still use the existing rules. By Michael Ball Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Business intelligence reports

Get concise, trustworthy and unbiased analysis of the latest trends and developments in oil and energy markets. These reports are specially created for decision makers who don’t have time to track markets day-by-day, minute-by-minute.

Learn more