Liquefied Natural Gas Projects Research Articles

2023 Development and production review

Geopolitical uncertainty remained high in 2023 with Israeli actions in the Gaza strip, the continuing war in Ukraine and tension between China and several neighbouring countries. However, global inflationary pressures, surprisingly, eased during the year, and the prospect of a global recession faded from where it had been in 2022. In Australia continued activism around climate change issues, has impacted project developments and sentiment in the industry remained subdued. This paper looks back at the oil and gas production and development activities in Australia in 2023 providing historical context and trying to understand future implications for the industry. Liquefied natural gas (LNG) production in Australia remained close to record high levels although, not without problems. Both the Scarborough/Pluto 2 LNG project and the Barossa project continued to have legal and approval hurdles resulting in suspension of some execution activities. Elsewhere other projects continued with their plans, including the Kipper field in the Gippsland Basin, the Crux project in the Browse Basin and the Walyering project in the Perth Basin which was brought online in September 2023. The domestic markets also continued to have unique issues with major concerns about gas supply in the East, stalled developments and failing supply in the Northern Territory, and a renewed ban on any exports (including to other states) of gas from Western Australia.

Charting a path to low-carbon leadership: unlocking up to 90% emissions reductions in greenfield LNG

The liquefied natural gas (LNG) industry stands at the cusp of a transformation driven by the climate imperative. Focussing on the Middle Arm Industrial Precinct, this paper shows how carbon dioxide (CO2) emissions are being reduced in a proposed world-class LNG project by assessing, screening and selecting known technologies using a Marginal Abatement philosophy linked to key emissions drivers. (1) We propose a new breed of electrified LNG facilities that could deliver an up to 90% reduction in CO2 intensity. (2) We show that through developing strategic partnerships in upstream renewable power, hydrogen supply, and enabled downstream carbon capture and storage (CCS), the significant low carbon energy requirements of an LNG facility can be delivered. (3) We discuss a Marginal Abatement assessment strategy which ensures a pathway to viable lowest cost opportunities selected in an ‘Avoid & Mitigate’ first approach. This proposed strategy ensures that CO2 emission reduction opportunities are assessed and selected consistently to determine both a lifecycle cost ($) and volume (tons CO2e) of emission reduction. These innovative strategies collectively articulate a roadmap for a low carbon future for LNG and other heavy industrial industries, underlining Australia’s potential to become a leading provider of low-carbon natural resources.

Assessing the role of LNG in global carbon neutrality efforts: A project management review

This paper review explores the role of LNG in the context of global carbon neutrality efforts. It examines various aspects such as the current state of LNG usage, its environmental impacts, technological advancements, regulatory frameworks, and the challenges and opportunities associated with its integration into the energy mix. Through a comprehensive analysis, this review aims to provide insights into how project management principles can facilitate the effective implementation of LNG projects to support the transition towards a carbon-neutral future. The transition to a carbon-neutral global economy is an imperative challenge of the 21st century, necessitating a profound shift in energy systems and practices. At the forefront of this transition, liquefied natural gas (LNG) has emerged as a potential bridge fuel, offering a pathway towards decarburization. This project management review delves into the multifaceted role of LNG within the context of global carbon neutrality efforts, examining its current usage, environmental implications, technological advancements, regulatory frameworks, and the associated challenges and opportunities. Through a comprehensive analysis, this review aims to shed light on how project management principles can effectively facilitate the implementation of LNG projects to support the transition towards a carbon-neutral future. LNG's emergence as a potential bridge fuel stems from its relatively lower carbon intensity compared to other fossil fuels. As nations strive to reduce greenhouse gas emissions and meet their commitments under the Paris Agreement, LNG presents an opportunity to mitigate climate change while addressing energy security and economic development objectives. However, a nuanced understanding of LNG's role requires a thorough examination of various dimensions. Firstly, the current state of LNG usage underscores its growing significance in the global energy landscape. With LNG trade reaching record highs in recent years, countries are increasingly turning to LNG to meet their energy needs. Major LNG-producing nations such as Qatar, Australia, and the United States have invested in liquefaction infrastructure, enabling the export of LNG to markets around the world. Additionally, LNG is utilized across diverse sectors, including power generation, industrial processes, transportation, and residential heating, highlighting its versatility and applicability. Despite its potential benefits, LNG is not without environmental impacts. The extraction, production, and transportation of natural gas, the primary component of LNG, can result in methane emissions, a potent greenhouse gas. In conclusion, LNG has emerged as a potential bridge fuel in the transition towards a carbon-neutral global economy. Its relatively lower carbon intensity, versatility, and scalability make it a viable option for reducing greenhouse gas emissions while meeting energy demand. However, realizing the full potential of LNG requires careful consideration of its environmental impacts, technological advancements, regulatory frameworks, and associated challenges. By applying project management principles, stakeholders can effectively navigate the complexities of LNG projects and contribute to the achievement of global carbon neutrality goals.

Case Study on Decarbonization Strategies for LNG Export Terminals Using Heat and Power from CSP/PV Hybrid Plants

The race towards decarbonization is driving major oil and gas companies to explore means to use renewable heat and power for their plants as part of their commitment to reduce their carbon intensity by 80% to 100% by 2050 [1]. In terms of greenhouse gas (GHG) emissions, natural gas is considered the cleanest fossil fuel option available, and decarbonization of new liquefied natural gas (LNG) projects is on the radar of many LNG projects developers. In addition, LNG cargos will have to be certified in the future by accredited authorities to meet defined GHG emission levels [2].
 This research study investigates a concept of providing both heat and power from a photovoltaic (PV) and concentrated solar power (CSP) solar tower hybrid plant to meet the energy demand of LNG export terminals. Two locations have been investigated for potential future LNG projects: Karratha in Australia and Ras Laffan in Qatar. Both locations have direct normal irradiance (DNI) values higher than 2000 kWh/m2/year, which is the minimum level required for CSP technology [3]. A techno-economic assessment was carried-out taking into consideration the electricity price, the grid carbon intensity and the carbon dioxide (CO2) tax in the region.
 The results indicate that the CSP/PV hybrid plant significantly accelerates the decarbonization of energy supply to the “All electric” LNG Plant. The quantity of CO2 emitted between 2025 and 2050 is reduced by 81% for Karratha (Australia) and by 88% for Ras Laffan (Qatar) compared to a grid connected LNG plant.

Современное состояние глобального рынка сжиженного природного газа и перспективы реализации российских арктических СПГ-проектов

Transitioning from coal to natural gas and renewable energy sources has become a global trend over the past decade. Despite efforts made by the EU, USA, Japan, and several other nations to replace fossil fuels with alternative sources, significant success in this domain remains elusive, with hydrocarbons continuing to dominate the energy landscape. Notably, the share of liquefied natural gas (LNG), once perceived as a weak alternative to pipeline gas, constituted 56 % of the global gas exports by the end of 2022, with the number of consumer countries reaching 47. This study aims to assess the potential capabilities of key LNG suppliers in increasing production and export volumes to meet the growing demand in the global LNG market. A primary focus is placed on evaluating the capabilities and plans of Russian companies to execute large-scale LNG projects. The research employs methods of systems and statistical analysis, along with economic forecasting. The article discusses the key trends in the global LNG market's development and identifies the factors exerting the most significant impact on its trajectory. An analysis of the current long-term program supporting LNG production in Russia is conducted, highlighting the key support measures available to domestic companies. The practical significance of this study lies in identifying countries poised to increase their production volumes and enter the LNG production and export arena within six to seven years. The research pinpoints key large-scale domestic LNG projects set to make the Russian LNG share in the world market grow from 8 % to 15–17 %. Subsequent steps of this research will involve assessing the prospects for selling Russian and American LNG in the Asia-Pacific (APAC) market.

Fragile Equilibrium: Balancing LNG Trade and Market Risks

_ Liquefied natural gas (LNG) has been in global energy supply discussions for decades. Geopolitical tensions, however, recently elevated it from a bullet point to the entire conversation. Rarely does a day pass without mention of signed long-term LNG purchase agreements or LNG terminal construction projects advancing, one day making it possible to transport the curiously cold molecules across oceans to eventually power industries or heat homes. So strong are the fundamentals of the LNG industry, for example, that they were cited as a primary driver in the conversion of one of the largest pure-play US-listed shipping companies—Capital Product Partners led by Greek shipowner Evangelos Marinakis—to a pure-play LNG shipping company. In addition to changing its name to Capital New Energy Carriers, the partnership is selling off its modern fleet of 15 Neo-Panamax and Panamax container vessels. It will spend $3.13 billion to purchase 11 newbuild LNG carriers (LNGC). According to an announcement on 13 November, the first of the new vessels arrived in October 2023. The company already had seven LNG carriers in its fleet, with the remaining 10 newbuild vessels scheduled for delivery through March 2027. Jerry Kalogiratos, chief executive of Capital Product Partners, said the acquisition was transformative, noting that the partnership “expects our contracted revenues to increase by 87% percent to $3.1 billion, our revenue weighted charter duration to 7.2 years as of the closing date, and the average age of our LNG fleet to decrease to 3.2 years by the time all LNGCs have been delivered in 2027.” LNG Market Overview Events like the Russian invasion of Ukraine in February 2022 and the sudden loss of Russian pipeline gas supplies upended global energy markets. European buyers turned to LNG imports to meet demand. According to Wood Mackenzie, the current conflict in Israel/Gaza, possible pipeline sabotage in the Baltics, and the threat of fresh strike action at Australian LNG facilities all pushed spot prices up 35% through October. In a November blog post, Wood Mackenzie noted that a record 200 mtpa of new supply is under construction as “players bet big on Asia’s push to reduce its dependence on coal and Europe’s need to replace Russian gas.” While the proliferation of LNG projects is prompting concerns that there may be too much LNG on the market once these projects are completed, this is not the case, according to Wood Mackenzie. “Increased supply availability will bring prices down and boost demand growth,” said Gavin Thompson, vice chair of Europe, Middle East, and Africa, and Massimo Di Odoardo, vice president, gas and LNG research for Wood Mackenzie, noting that the market will need another 60 mtpa of new LNG by 2033. “Much will hinge on sustained economic growth, driving increased demand across emerging markets in Asia. China’s LNG demand will increase by 12% in 2023, and with 50 mtpa of LNG contracted over the past 2 years, imports will double by 2030. LNG demand in South and Southeast Asia will also grow twofold by this time,” they said.

The Liquefied Natural Gas (LNG) Puzzle: A Singular and Misunderstood Commodity in World Trade

The ocean‐going trade in liquefied natural gas (LNG) is more than half a century old. The first US LNG project began commercial operation in 1971. World trade in LNG arose as countries and regions with warm climates, small populations, and no ready application for such a fuel as natural gas, like Algeria, Qatar, and Western Australia, sought to monetize their local natural resources by building large export facilities (usually at state expense) targeting industrial countries with cold winters and without indigenous fossil fuels, like Japan, Korea, parts of Europe, and New England. But great costs, complexities, paradoxes, and business failures have always accompanied the international LNG trade. Age‐old rules of thumb for other commodities in world trade do not apply to LNG.

Impact of liquefaction ratio and cold energy recovery on liquefied natural gas production

The partial liquefaction of natural gas (NG) is commonly conducted in the liquefied natural gas (LNG) industry toward facilitating the use of non-liquefied gas for power generation and utility systems, while simultaneously achieving the desired heating value of LNG. This study investigated the impact of the partial liquefaction of NG and the recovery of cold energy from non-liquefied gas on the efficiency of the liquefaction process, in terms of specific work. The optimal liquefaction ratio (LR) with no recovery was 64.2% (778.7 kJ/kg LNG), which is 21.7% reduction of specific work in relation to that achieved through full liquefaction (995.0 kJ/kg LNG). The result showed a trade-off relationship between a higher LR to compensate energy consumption for cooling NG to its dew-point temperature with no liquid production and produce flash gas at a cryogenic temperature and lower LR to avoid the liquefaction of light components, which are difficult to condense. However, this trade-off resolved upon cold energy recovery, because there was no energy consumption until an LR of 8.1% could be achieved through an expansion of high-pressure NG feed by the recovery. For practical reason, a case study was conducted with lower bounds of the LR at 85%, 90%, and 95%. The findings of this study can guide the decision-making of future LNG projects for an optimal LR.

Development and production review 2022

The Petroleum Exploration Society of Australia (PESA) Year in Review Development and Production review looks back at the oil and gas production and development activities in Australia in 2022, with a look at both the historical context of these activities, and the future implications. With the invasion of Ukraine, increasing inflationary pressures, supply chain problems, the prospect of a global recession looming, the impact of COVID-19 still lingering, and increased activism around climate change issues, sentiment was subdued for most of the year, yet there were still several highlights and events. Liquefied natural gas (LNG) production again hit record high levels although, as expected, Australia lost its position as the top LNG exporting country in the world to the USA. The development of the Scarborough/Pluto 2 LNG project continued, as did the Barossa project, although the latter hit legal and approval hurdles resulting in suspension of drilling activities (which are not expected to impact the overall schedule). Final investment decisions were taken on the further development of the Kipper field in the Gippsland Basin, the Crux project in the Browse Basin and the Walyering project in the Perth Basin. The domestic markets continue to have unique issues with major concerns about gas supply in the East co-existing with stalled developments and falling supply in the Northern Territory in stark contrast to the West, where there is significant development and take-over activity.

Location, Location—Tanzania, Mozambique Soon To Join Club of Global LNG Suppliers to India, China, Southeast Asia

_ East Africa is positioning itself as a global player in liquefied natural gas (LNG) with the world’s supermajors staking out projects that will ramp up this decade to supply India, Southeast Asia, and China through 2050. With three LNG megaprojects—two in Mozambique and one in neighboring Tanzania—soon to take off after years of false starts and delays, it is no wonder that India’s External Affairs Minister Subrahmanyam Jaishankar visited the region in April with energy security top of mind. Jaishankar’s East Africa trip was the first official visit to the region by an Indian foreign minister in over a decade. He stopped first in Uganda where oil is in play after Uganda inked a deal in February to complete the long-delayed East African Crude Oil Pipeline (EACOP) and deliver first oil in 2025 from Uganda’s Lake Albert oil fields to Tanzania’s port of Tanga on the Indian Ocean. After spending 3 days in Uganda, Jaishankar traveled to Mozambique where state-owned ONGC Videsh leads an Indian consortium holding a 30% stake in the country’s $20-billion Offshore Area 1 project, Mozambique LNG, which stalled in April 2021 after the operator, TotalEnergies, declared force majeure over terrorist attacks in Cabo Delgado Province near the Afungi peninsula plant site. Mozambique LNG’s 13.1-mtpa capacity, two-train facility is one of two megaprojects that will help transform East Africa into a global LNG supplier. The other is ExxonMobil’s Rovuma LNG project, another two-train facility for which a final investment decision (FID) was delayed as the Islamic insurgency that had been building since 2020 intensified along the Cabo Delgado coast. India imports 85% of its oil and 55% of its natural gas. In 2022, it consumed about 22 mpta of LNG, according to Shell’s LNG Outlook 2023. India’s business daily Mint reported that during Q1 2023, India’s LNG imports were worth $14.88 billion, an amount that was 36.46% higher than the $10.90 billion value of LNG India imported in Q1 2022. So far in 2023, Qatar has been India’s No. 1 LNG supplier followed by the UAE and the US. By 2030, Mozambique, Tanzania, and possibly the Republic of Djibouti (with access to the Indian Ocean via the Gulf of Aden) will be joining the list. Considering that tankers can deliver LNG and oil from the East African coast to the subcontinent in 3 days, it’s no wonder that Mint described the foreign minister’s visit as “signifying New Delhi’s push to develop Africa as a key (energy) supplier.” India and China Claim Big Stakes in Future East African Energy Flows Indian partners ONGC Videsh Rovuma, Beas Rovuma Energy Mozambique, and BPRL Ventures Mozambique control 30% of the Mozambique LNG project (10% each). Total E&P Mozambique Area 1 holds a 26.5% operator interest with remaining shares distributed among Mozambique state-owned ENH Rovuma Área Um (15%); Japan’s Mitsui E&P Mozambique Area 1 (20%), and Thailand’s PTTEP Mozambique Area 1 (8.5%).

Reviewing the economic viability of LNG projects in African Nations

The economic viability of Liquefied Natural Gas (LNG) projects in African nations stands as a pivotal subject in the global energy landscape. This Review encapsulates a comprehensive review, shedding light on the multifaceted aspects that determine the success and sustainability of LNG initiatives across the African continent. The analysis encompasses key elements such as investment frameworks, regulatory environments, and socio-economic considerations, providing a nuanced understanding of the economic dynamics shaping LNG projects. Examining case studies and regional variations, the review delves into the challenges and opportunities that characterize LNG ventures in Africa. The study identifies the critical factors influencing economic viability, including infrastructure development, market dynamics, and governmental policies. It explores the impact of global energy trends on the African LNG market and scrutinizes the role of international collaborations in fostering economic success. Additionally, the review assesses the potential socio-economic benefits, job creation, and local community engagement stemming from LNG projects, adding a socio-economic dimension to the economic evaluation. Furthermore, the Review emphasizes the need for adaptive strategies that acknowledge the unique challenges faced by African nations, from political stability concerns to the varying levels of technological infrastructure. The economic viability of LNG projects is inherently linked to the alignment of national goals, industry interests, and environmental sustainability. In summary, this Review provides a succinct overview of the comprehensive review on the economic viability of LNG projects in African nations. It sets the stage for an in-depth exploration of the economic intricacies, offering valuable insights for policymakers, industry stakeholders, and researchers vested in the sustainable development of LNG projects across the African continent.

Case study on decarbonization strategies for LNG export terminals using heat and power from CSP/PV hybrid plants

The race towards decarbonization is driving major oil and gas companies to explore means to use renewable heat and power for their plants as part of their commitment to reduce their carbon intensity by 80% to 100% by 2050 (Holbrook, 2023). In terms of GHG (Greenhouse Gas) emissions, natural gas is considered the cleanest fossil fuel option available, and decarbonization of new LNG (Liquefied Natural Gas) projects is on the radar of many LNG projects developers. In addition, LNG cargos will have to be certified in the future by accredited authorities to meet defined GHG emission levels (Stern, 2019).This research study investigates a new concept of providing both heat and power from a PV (Photovoltaic) and CSP (Concentrated Solar Power) hybrid plant to meet the energy demand of an LNG export terminal. Two locations have been investigated for potential future LNG projects: Karratha in Australia and Ras Laffan in Qatar. Both locations have DNI values higher than 2000 kWh/m2/year, which is the minimum level required for CSP technology (Lovegrove and Stein, 2021).The LCCA (Levelized Cost of CO2 abatement) was used to compare the various solar configurations to select the option that will bring the greatest amount of CO2 reduction for the same investment cost (CGEP, 2020). The solar configurations technical parameters were defined based on the surface land available, natural gas feed composition and LNG plant design characteristics. The techno-economic assessment was carried-out taking into consideration the electricity price, the grid carbon intensity, and the CO2 tax in the region.Whilst in Australia a collocated single plant is favourable in terms of land availability and DNI (Direct Normal Irradiation) level, in Qatar, heat and power production have been separated into two distinct locations. Next to the LNG plant, a CSP plant provides heat only, whereas 130 km away, the hybrid PV/CSP plant located at Qurain EL Bawl provides electric power.The results indicate that the PV/CSP hybrid plant significantly accelerates the decarbonization of energy supply to the “All electric” LNG Plant. Depending on the solar field size, the quantity of CO2 emitted between 2025 and 2050 is reduced by 78–81% for Karratha (Australia) and by 82–88% for Ras Laffan (Qatar) compared to a grid connected plant.In addition, the economic assessment indicated that buying electricity from the grid during the period 2025–2050 would be more expensive for Australia then investing in a PV/CSP plant. In Qatar, the LCOE range of 93–110 US$/MWh is not competitive with the price of electricity in the region Qatar, mainly because of energy subsidies, however both the carbon tax and electricity price will need to be raised to the same level as in Australia to diversify and expand the power sector in the region.

Enhanced megaproject management systems in the LNG industry: A case study from Qatar

Despite the development of several industrial Liquefied Natural Gas (LNG) megaprojects worldwide, minimal literature on LNG megaprojects is available in the non-proprietary public domain and academia, with the consequent lack of availability of practical tools, guidelines, and benchmarks for the use of professionals engaged in developing and managing LNG megaprojects. Cognizant of this fact, the authors have attempted a study of standard project management systems to explore practical ways to meet the unique needs of LNG megaprojects management and systematically assimilate lessons learned to replicate successes and avoid failures. Considering the complexity of the LNG value chain, a management system approach has been adopted. Combining academic and industrial knowledge, this study identifies nine significant areas that, when improved, should enhance the management of LNG megaprojects throughout their lifecycle — from initiation to handover for operation. With hundreds of billions of dollars invested in current LNG projects, even minor improvements can be worth billions. This study also addresses the challenges of megaprojects development, gaps that need to be overcome, and the importance of quality and lessons learned. Finally, although the focus of this study is the management of LNG megaprojects, it is expected that many improvements identified here would find relevance in managing large and complex projects, even in other industrial sectors.

Тенденции развития мирового рынка сжиженного природного газа и перспективы реализации российских арктических проектов

The environmental agenda, as well as issues of reducing carbon dioxide emissions into the atmosphere, are currently treated as a global trend. In such conditions, developed countries openly and actively declare their plans to switch from coal to natural gas and renewable energy sources in their energy consumption. At the same time, the liquefied natural gas (LNG) market is developing at such a pace that in 10–15 years, according to experts, it will bypass the pipeline market. Nevertheless, a significant increase in prices for “blue fuel” at the end of 2021 and the first half of 2022 called into question the reality of following the chosen course in the near future. The study identified the main LNG importers by the end of 2021 (China, Japan, South Korea, Taiwan and India), as well as the key exporters (Australia, Qatar, USA, Russia, Nigeria, Algeria, Malaysia, Oman and Indonesia). The analysis showed that in the medium term, Qatar, the United States and Russia will be able to significantly increase the volume of natural gas and LNG production. Australia, despite its status as the largest exporter of LNG by the end of 2021, due to the shortage of natural gas in the domestic market, will not be able to increase export volumes in the near future. The purpose of the study is to analyze the main trends in the development of the global LNG market in new geopolitical conditions and to determine the prospects for the implementation of Russian Arctic LNG projects. The scientific novelty of the work lies in determining the potential of the largest LNG suppliers in terms of increasing the LNG production and export regarding the forthcoming 5–8 years. The next stage of the work will be the assessment of the prospects for the sale of Russian and American LNG in the European Union and the Asia-Pacific region markets.

Maritime inventory routing with transshipment: the case of Yamal LNG

The LNG-ADP problem is a tactical planning problem for creating an annual delivery program (ADP) for a liquefied natural gas (LNG) producer. An ADP specifies the departure dates of the LNG carriers as well as the delivery dates at the different customers for a period of 12–18 months. The problem can be formulated as maritime inventory routing problem, as it is an important requirement to plan the deliveries such that inventory levels are kept within minimum and maximum limits at the customers as well as the LNG production facility. Inspired by the case of Yamal LNG, we propose a novel discrete-time formulation for the LNG-ADP problem with transshipment and intermediate storage. Our formulation also allows for waiting at the unloading ports. The problem is solved using a rolling horizon heuristic (RHH) for a case based on the Yamal LNG project. We study the impact of different RHH configurations on run time and solution quality. The results show that using a central period that is shorter than the forecast period provides the best objective function, whereas a central period that is longer than the forecast period improves run time. We also explore the effect of allowing waiting at the unloading ports. Waiting does not necessarily improve the objective function value, despite increasing the solution space. However, we observe a reduction in run time for instances where waiting is allowed.

Stages of development of LNG production and sales

In 1895 Carl von Linde developed the technology for liquefying natural gas, but only in the early twentieth century commercial production of liquefied natural gas was begun. Liquefied natural gas (LNG) is natural gas, primarily methane, that has been artificially liquefi ed by cooling to minus 160 °C for easy storage or transportation. It is a liquid that is colorless and odorless. Pure LNG is not fl ammable, does not ignite or explode on its own. There are several stages of development of LNG production and sales. The fi rst stage (1917–1941) — the first LNG plant was built in the USA. In 1917, an LNG plant was built in the US. The second stage (1959–1969) was the beginning of LNG exports from the US to Europe. The third stage (1969–2020) was the development of the world LNG market. As of early 2010, there were more than 30 large-capacity plants in the world aimed at LNG exports. The fourth stage (2020-present) is the impact of the coronavirus on the world LNG market. Since 2010, global LNG exports have increased from 302.4 billion cubic meters to 487.9 billion cubic meters in 2020. LNG already accounts for more than 40 percent of global gas trade. Leading LNG exporters include Qatar, Australia, the USA, Russia, Malaysia, Nigeria, Trinidad and Tobago, Algeria and Indonesia. Russia accounts for 8 % of global LNG exports. The pandemic situation in the world has caused oil prices to fall and remain low, so suppliers with low costs or high margins are in an advantageous position. Nevertheless, several LNG projects are planned to be launched in the near future, which will allow Russia to become one of the leaders in LNG production. The article outlines the stages of development of LNG production and sales, analyzes the current state of global LNG production, and also lists various LNG projects in Russia.

Strategic approach to implementation of innovation in the Arctics on the example of “Arctic Cascade” natural gas liquefaction technology

The article examines the current situation in the world production and consumption of the liquefied natural gas (LNG). The main global trends as well as the reasons for significant growth in LNG consumption in most countries are analyzed. The authors also study the structure of global import of LNG and the opportunities for increasing supplies by the Russian energy companies. Russian companies are primarily supplying LNG to European countries. However, the results of the analysis show high export potential of the Asian market. Realizing the potential is the most important strategic task for domestic energy companies. The article also examines the history and the current process of developing LNG production on the Russian territory. The authors reveal various aspects of the current implementation of such projects as “Yamal LNG” and “Arctic LNG 2” within the Arctic area of the Russian Federation. Particularly, the authors describe development of transportation-logistics system as part of these projects. Moreover, the article contains the analysis of the problem of ensuring technological independence in the process of implementation of LNG projects. Russian energy companies should increase their technological independence and localization of production by consistent implementation of the import substitution strategy. One of the solutions in ensuring technological independence is innovation technology of natural gas liquefaction “Arctic Cascade”. The article presents the detailed technical and economical aspect of implementing this technology. Using this technology ensures 30 % reduction of the LNG production cost price. Besides, this innovation technology can ensure 100 % localization of production.

Exploring synergies between the 2030 Agenda for sustainable development and involuntary resettlement guidelines: the case of Mozambique’s natural gas project

This paper explores synergies between the 2030 Agenda for Sustainable Development, comprised of 17 Sustainable Development Goals (SDGs) as its roadmap, and existing involuntary resettlement guidelines. On one hand, the 2030 Agenda for Sustainable Development views displacement as a humanitarian problem but fails to address the potential effects of SDG-induced processes of economic and physical displacement and involuntary resettlement. On the other, involuntary resettlement guidelines pay limited attention to the sustainable development of resettled people as well as to the society in which resettlement becomes embedded. This paper explores possibilities to establish synergies between the SDGs and involuntary resettlement by drawing on the case of Mozambique’s liquefied natural gas (LNG) project, which was showcased in the Government of Mozambique’s 2020 Voluntary National Review (VNR) of SDG progress. The paper will critically analyse how Mozambique as a ‘donor darling’ remains silent about displacement and resettlement processes induced by an LNG project that is used to show its commitment to multiple SDGs. The paper shows that there is a misalignment between how SDGs are used to evaluate a development project and how involuntary resettlement guidelines are applied to the same project. The paper argues that, to truly ‘leave no one behind’, the SDGs and involuntary resettlement guidelines need to be realigned by integrating SDG-induced displacement and resettlement into SDG10 on migration and inequality, into SDG16 on conflicts, and SDG17 on global partnerships.

Learning from Africana critical theory: A historicized contextualization of the impacts of Mozambique's natural gas project

Over the past decade, Mozambique's liquefied natural gas (LNG) project in the province of Cabo Delgado has symbolized a new development opportunity for the country. The project attracted foreign investments to the province, and the national government has used it to showcase its progress towards achieving the Sustainable Development Goals. The project however also introduced various socioeconomic ills including the displacement of over 10,000 people from their homes and livelihoods. Since 2017, Cabo Delgado province has simultaneously been an epicenter of armed violence, predominantly attributed to radical Islamic insurgency, communities’ marginalization from an expanding frontier of extractivism, and overall economic development. In this paper, we argue that understanding and addressing the negative impacts of contemporary extractivism in Mozambique require a historicized contextualization. Drawing on Africana critical theory (ACT), we contribute to this scholarly gap by highlighting several ways in which the challenges presented by the LNG project in Cabo Delgado are reminiscent of or rooted in colonial extractivism. To address the contradictions of contemporary extractivism, we propose that ACT scholarship which influenced some of the progressive policies of the anti-colonial and early post-independence periods may be insightful.

Greenhouse Gas Estimates of LNG Exports Must Include Global Market Effects.

We conduct a consequential lifecycle analysis (LCA) of greenhouse gas (GHG) emissions from North American liquefied natural gas (LNG) export projects, estimating the change in global natural gas and coal use resulting from the market effects of increased LNG trade. We estimate that building a 2.1 billion cubic feet per day (Bcfd) LNG export facility, equivalent to one of the larger LNG projects under development in the US today, will change global GHG emissions -39 to 11 Mt CO2e (90% range) with a median value of -8 Mt CO2e. Previous attributional LCA methods for electricity generation with LNG replacing coal find a much larger benefit of LNG exports, a median value of -36 Mt CO2e for this size project. The smaller decrease in GHGs is attributable to higher domestic coal use and a smaller decrease in international coal use than assumed by previous methods. Net global emission change estimates are most sensitive to the uncertainty in economic elasticities outside of North America. Given the scale of planned and proposed LNG export terminals, project regulators and policymakers must account for market effects to more accurately estimate the global net change in GHG emissions.