No full-text available
To read the full-text of this research,
you can request a copy directly from the authors.
Influence of storage technologies' cost development on the economics of power transmission grids
Abstract
Grid integration for renewable energy (RE) is in many studies observed as the major option to increase energy system reliability and decrease costs: overflows in the grid can support the system in case of component failure and decrease the need for balancing capacities. Energy transmission grids additionally increase capacity utilisation and efficiency by smoothing of total demand, especially for geographically wide expanded grids. Wherefore it had been often assumed that a development of close to 100% RE systems may be only possible with the installation of extended power grids as was discussed in the Desertec or Gobitec vision and other comparable centralised RE approaches. In this work impacts of the different levels of high voltage direct current (HVDC) grid integration on cost optimized 100% RE system were researched for the example of Northeast Asia. Three grid scenarios were applied for the area: region-wide open trade, where the energy system integration happens only inside one region; country-wide open trade, where a HVDC transmission grid connects regions inside one country; and area-wide open trade scenario, where all the countries are interconnected. These scenarios were simulated using the LUT energy system model for the two cost years 2020 and 2030. The optimized energy system included solar photovoltaics (PV), concentrating solar thermal power, wind onshore, hydropower, geothermal energy and biomass as energy sources. The storage options are batteries, thermal energy storage, pumped hydro storage, adiabatic compressed air energy storage (A-CAES) and gas storage including power-togas. It was found, that grid integration leads to a significant decrease of total levelised cost of electricity (LCOE) for the years 2020 and 2030: LCOE for the area-wide scenario was 8% lower than the region-wide scenario for the year 2020 and 5% lower for year 2030. However, the cost spread for 2030 is 50% lower (3 €/MWh vs 6 €/MWh) because of expected storage cost development and consequently different storage and grid utilisation. The optimal storage structure for both years is 20% of long-term storage and 80% of short to mid-term storage. Short-term storage technologies, Li-ion batteries and PHS are insignificant for the Northeast Asian case. The cost development of storage technologies results in increased storage and reduced grid supply share of 16% to 22% and 14% to 9% for the year 2020 and 2030, respectively, i.e. reduced storage costs lead to a reduced relevance of long distance grid integration. The total share of the flexible power sources stays stable for both cost years at around 30%. Finally, the lower cost spread for the year 2030 makes it possible in some cases to take a transformation towards 100% RE into account without massive grid installations.
Supplementary resource (1)
... Due to long distances and local storage technologies being more cost-competitive, low-cost RE from Australia cannot be exported to high demand centers in Indonesia and further into China due to high transmission costs. The increasing cost competitiveness of storage compared to grids had already been found for Northeast Asia [47]. However, according to research done by Taggart et al. [4,18], large scale connectivity of different regions would cancel out the need for large-scale storage technologies, to which the authors of this research agree to some extent, since such an effect can be observed in the decrease in need for storage technologies from the region-wide to the area-wide scenario. ...
... East Asia and EuropeEurasiaMENA show the same characteristic, that a deep integration from a region-wide to an area-wide integration within a region is highly beneficial in the range of 5%-16%, since this had been found for all five major regions involved: Northeast Asia (11%) [23], Southeast Asia (5%) [22], Europe (11%) [49], Eurasia (16%) [50], and MENA (10%) [51]), but not for an integration of two neighboring major regions. Very long power lines between 1500 and 2000 km or more do not generate financial benefits, as found so far for Northeast Asia [47]. Other limiting factors include an inability to integrate the vast wind resource potential of Northwest Russia for Europe [52], utilize excellent solar and wind resources in the Maghreb region for synthetic fuel production [53], and connect Australia to East Asia, as shown in this article. ...
The Paris Agreement points out that countries need to shift away from the existing fossil-fuel-based energy system to limit the average temperature rise to 1.5 or 2 °C. A cost-optimal 100% renewable energy based system is simulated for East Asia for the year 2030, covering demand by power, desalination, and industrial gas sectors on an hourly basis for an entire year. East Asia was divided into 20 sub-regions and four different scenarios were set up based on the level of high voltage grid connection, and additional demand sectors: power, desalination, industrial gas, and a renewable-energy-based synthetic natural gas (RE-SNG) trading between regions. The integrated RE-SNG scenario gives the lowest cost of electricity (€52/MWh) and the lowest total annual cost of the system. Results contradict the notion that long-distance power lines could be beneficial to utilize the abundant solar and wind resources in Australia for East Asia. However, Australia could become a liquefaction hub for exporting RE-SNG to Asia and a 100% renewable energy system could be a reality in East Asia with the cost assumptions used. This may also be more cost-competitive than nuclear and fossil fuel carbon capture and storage alternatives.
... Due to long distances and local storage technologies being more cost-competitive, low-cost RE from Australia cannot be exported to high demand centers in Indonesia and further into China due to high transmission costs. The increasing cost competitiveness of storage compared to grids had already been found for Northeast Asia [47]. However, according to research done by Taggart et al. [4,18], large scale connectivity of different regions would cancel out the need for large-scale storage technologies, to which the authors of this research agree to some extent, since such an effect can be observed in the decrease in need for storage technologies from the region-wide to the area-wide scenario. ...
... East Asia and EuropeEurasiaMENA show the same characteristic, that a deep integration from a region-wide to an area-wide integration within a region is highly beneficial in the range of 5%-16%, since this had been found for all five major regions involved: Northeast Asia (11%) [23], Southeast Asia (5%) [22], Europe (11%) [49], Eurasia (16%) [50], and MENA (10%) [51]), but not for an integration of two neighboring major regions. Very long power lines between 1500 and 2000 km or more do not generate financial benefits, as found so far for Northeast Asia [47]. Other limiting factors include an inability to integrate the vast wind resource potential of Northwest Russia for Europe [52], utilize excellent solar and wind resources in the Maghreb region for synthetic fuel production [53], and connect Australia to East Asia, as shown in this article. ...
Energy is a key driver for social and economic change. Many countries trying to develop economically and socially and many developed countries trying to maintain their economic growth will create a huge demand for energy in the future. The growth in energy production will put our climate at risk, without change in the existing fossil fuel based energy system. In this paper, 100% renewable energy based system is discussed for East Asia, integrating the two large regions of Southeast Asia and Northeast Asia. Regional integration of the two regions does not provide significant benefit to the energy system in terms of cost reduction. However, reduction of 0.4-0.7% in terms of total annual cost of the system can be achieved for East Asia, mainly realised in optimising the bordering regions of South China and Vietnam, Laos and Cambodia. The idea of Australia being an electricity source for Asia, does not pay off due to the long distances and local storage of the generated electricity in the regions is more cost competitive. However, such an integration provides a sustainable and economically feasible energy system with the cost of electricity between 53-66 €/MWh for the year 2030 with the assumptions used in this study. The described energy system will be very cost competitive to the widely discussed nuclear and fossil carbon-capture and storage (CCS) alternatives.
... Solar PV electricity is typically not traded among the sub-regions, because the solar resource is quite evenly distributed and roughly accessible in the same hours. In addition, transmission over many thousands of kilometres has been found to be not economical attractive, mainly because of the cost competitiveness of local storage [30,40,45,78]. ...
The global energy system has to be transformed towards high levels of sustainability in order to comply with the COP21 agreement. Solar photovoltaic (PV) offers excellent characteristics to play a major role in this energy transition. The key objective of this work is to investigate the role of PV in the global energy transition based on respective scenarios and a newly introduced energy transition model developed by the authors. A progressive group of energy transition scenarios present results of a fast growth of installed PV capacities and a high energy supply share of solar energy to the total primary energy demand in the world in the decades to come. These progressive energy transition scenarios can be confirmed. For the very first time, a full hourly modelling for an entire year is performed for the world, subdivided in 145 sub-regions, which is required to reflect the intermittent character of the future energy system. The model derives total installed solar PV capacity requirements of 7.1–9.1 TWp for the electricity sector (as of the year 2015) and 27.4 TWp for the entire energy system in the mid-term. The long-term capacity is expected to be 42 TWp and, because of the ongoing cost reduction of PV and battery technologies, this value is found to be the lower limit for the installed capacities. Solar PV electricity is expected to be the largest, least cost and most relevant source of energy in the mid-term to long-term for the global energy supply.
... The electricity trading among the sub-regions is in the global average about 15% of the total demand in the integrated scenario (and similar in the area-wide scenario), which implies that the 100% RE system solution shows a strong decentral distributed structure. Solar PV electricity is typically not traded among the sub-regions, since the solar resource is quite evenly distributed and roughly accessible in the same hours and transmission over many thousands of kilometres has been found to be not economical attractive, mainly due to the cost competitiveness of local storage [44,45,30,72]. ...
The global energy system has to be transformed towards high levels of sustainability for executing the COP21 agreement. Solar PV offers excellent characteristics to play a major role for this energy transition. Key objective of this work is to investigate the role of PV for the global energy transition based on respective scenarios and a newly introduced energy transition model developed by the authors at the Lappeenranta University of Technology (LUT). The available energy transition scenarios have no consensus view on the future role of PV, but a progressive group of scenarios present results of a fast growth of installed PV capacities and a high energy supply share of solar energy to the total primary energy demand in the world in the decades to come. These progressive energy transition scenarios can be confirmed by the LUT Energy system model. The model derives total installed solar PV capacity requirements of 7.1 – 9.1 TWp for today's electricity sector and 27.4 TWp for the entire energy system in the mid-term (year 2030 assumptions set as reference). The long-term capacity is expected to be 42 TWp and due to the ongoing cost reduction of PV and battery technologies, this value is found to be the lower limit for the installed capacities. The cost reductions are taken into account for the year 2030, but are expected to further proceed beyond this reference year. Solar PV electricity is expected to be the largest, least cost and most relevant source of energy in the mid-to long-term for the global energy supply.
The Gobitec concept represents the idea of producing clean energy from renewable energy sources in the Gobi Desert and delivering the produced energy to high-demand regions. It is planned to transmit this energy via the planned Asian Supergrid (ASG), which would connect Russia, Mongolia, China, South Korea and Japan.
The overall potential of solar and wind energy in the Gobi Desert is about 2,600 TWh. It is proposed to implement a group of projects with planned installed capacity of roughly 100 GW. The overall cost for this, including generation plants and transmission lines, is estimated to be around USD 293 bln, with yearly maintenance and system costs of USD 7.3 bln.
The Gobitec and the Asian Supergrid initiatives will deliver a number of economic, social and environmental benefits to the countries in the Northeast Asian region. The benefits will include, among others, improved energy security, job creation, economic growth and reduction of carbon dioxide emissions.
The study concludes that a legal framework, the Energy Charter Treaty, is necessary for the Gobitec and ASG initiatives, ensuring a positive investment climate, reliable transit regime and protection of property rights. Furthermore, electricity exchange and transmission regulations are to be developed and deployed.
Five partner organisations have jointly prepared this study. The organisations include the Energy Charter Secretariat, the Energy Economics Institute of the Republic of Korea, Ministry of Energy of Mongolia, the Japan Renewable Energy Foundation, and the Energy Systems Institute of the Russian Federation. The preparation of the study was assisted by Fraunhofer-Institute for Systems and Innovation Research ISI of Germany.
Full report: http://www.energycharter.org/what-we-do/investment/investment-thematic-reports/gobitec-and-the-asian-supergrid-for-renewable-energy-sources-in-northeast-asia-2014/
Photovoltaic installations are usually guaranteed to operate for 25 to 30 years, with a warranty of 80% of initial performance remaining after this time. However, in order to determine the profitability of a project, it is important to estimate the performance of the photovoltaic modules over their lifetime, depending on their environment. In this study, a first version of an ageing model for photovoltaic systems is considered, taking into account the influence of the environmental stress factors, which are the temperature, the relative humidity, and the exposure to UV radiation. Another stress factor also needs to be taken into account: the module's voltage potential versus ground (Potential Induced Degradation). The impact of cell cracks on the modules is also included in the model, their impact over the years depending on the temperature, but mainly to thermal cycles, due to the differences in temperature between day and night (thermal dilatation). Accelerated Damp Heat tests, thermal cycling tests, PID tests and UV tests are interpreted and used for calibrating the model, in addition to other degradation studies taken from relevant literature. A simple model is first built for the corrosion, with the temperature and humidity as stress factors, considering only the maximum power degradation. A more advanced model is then built, considering the degradation of the two-diode model parameters. A model has been built for each degradation, that is to say corrosion (temperature and humidity), AR coating and EVA discoloration (UV exposure), PID causes (temperature, humidity and voltage), and cell cracks (Thermal cycling). First simulations have been done, with weather data from the south of France (Mediterranean climate), Miami (hot and humid), and Dubai (hot and dry) showing that the power output after 30 years is still above the warranty limit of 80%.
To properly evaluate the prospects for commercially competitive battery electric vehicles (BEV) one must have accurate information on current and predicted cost of battery packs. The literature reveals that costs are coming down, but with large uncertainties on past, current and future costs of the dominating Li-ion technology. This paper presents an original systematic review, analysing over 80 different estimates reported 2007-2014 to systematically trace the costs of Li-ion battery packs for BEV manufacturers. We show that industry-wide cost estimates declined by approximately 14% annually between 2007 and 2014, from above US$1,000 per kWh to around US$410 per kWh, and that the cost of battery packs used by market-leading BEV manufacturers are even lower, at US$300 per kWh, and has declined by 8% annually. Learning rate, the cost reduction following a cumulative doubling of production, is found to be between 6 and 9%, in line with earlier studies on vehicle battery technology. We reveal that the costs of Li-ion battery packs continue to decline and that the costs among market leaders are much lower than previously reported. This has significant implications for the assumptions used when modelling future energy and transport systems and permits an optimistic outlook for BEVs contributing to low-carbon transport.
As electricity generation based on volatile renewable resources is subject to fluctuations, data with high temporal and spatial resolution on their availability is indispensable for integrating large shares of renewable capacities into energy infrastructures. The scope of the present doctoral thesis is to enhance the existing energy modelling environment REMix in terms of (i.) extending the geographic coverage of the potential assessment tool REMix-EnDaT from a European to a global scale, (ii.) adding a new plant siting optimization module REMix-PlaSMo, capable of assessing siting effects of renewable power plants on the portfolio output and (iii.) adding a new alternating current power transmission model between 30 European countries and CSP electricity imports from power plants located in North Africa and the Middle East via high voltage direct current links into the module REMix-OptiMo. With respect to the global potential assessment tool, a thorough investigation is carried out creating an hourly global inventory of the theoretical potentials of the major renewable resources solar irradiance, wind speed and river discharge at a spatial resolution of 0.45°x0.45°. A detailed global land use analysis determines eligible sites for the installation of renewable power plants. Detailed power plant models for PV, CSP, wind and hydro power allow for the assessment of power output, cost per kWh and respective full load hours taking into account the theoretical potentials, technological as well as economic data. The so-obtined tool REMix-EnDaT can be used as follows: First, as an assessment tool for arbitrary geographic locations, countries or world regions, deriving either site-specific or aggregated installable capacities, cost as well as full load hour potentials. Second, as a tool providing input data such as installable capacities and hourly renewable electricity generation for further assessments using the modules REMix-PlasMo and OptiMo. The plant siting tool REMix-PlaSMo yields results as to where the volatile power technologies photovoltaics and wind are to be located within a country in order to gain distinct effects on their aggregated power output. Three different modes are implemented: (a.) Optimized plant siting in order to obtain the cheapest generation cost, (b.) a minimization of the photovoltaic and wind portfolio output variance and (c.) a minimization of the residual load variance. The third fundamental addition to the REMix model is the amendment of the module REMix-OptiMo with a new power transmission model based on the DC load flow approximation. Moreover, electricity imports originating from concentrating solar power plants located in North Africa and the Middle East are now feasible. All of the new capabilities and extensions of REMix are employed in three case studies: In case study 1, using the module REMix-EnDaT, a global potential assessment is carried out for 10 OECD world regions, deriving installable capacities, cost and full load hours for PV, CSP, wind and hydro power. According to the latter, photovoltaics will represent the cheapest technology in 2050, an average of 1634 full load hours could lead to an electricity generation potential of some 5500 PWh. Although CSP also taps solar irradiance, restrictions in terms of suitable sites for erecting power plants are more severe. For that reason, the maximum potential amounts to some 1500 PWh. However, thermal energy storage can be used, which, according to this assessment, could lead to 5400 hours of full load operation. Onshore wind power could tap a potential of 717 PWh by 2050 with an average of 2200 full load hours while offshore, wind power plants could achieve a total power generation of 224 PWh with an average of 3000 full load hours. The electricity generation potential of hydro power exceeds 3 PWh, 4600 full load hours of operation are reached on average. In case study 2, using the module REMix-PlaSMo, an assessment for Morocco is carried out as to determine limits of volatile power generation in portfolios approaching full supply based on renewable power. The volatile generation technologies are strategically sited at specific locations to take advantage of available resources conditions. It could be shown that the cost optimal share of volatile power generation without considering storage or transmission grid extensions is one third. Moreover, the average power generation cost using a portfolio consisting of PV, CSP, wind and hydro power can be stabilized at about 10 €ct/kWh by the year 2050. In case study 3, using the module REMix-OptiMo, a validation of a TRANS-CSP scenario based upon high shares of renewable power generation is carried out. The optimization is conducted on an hourly basis using a least cost approach, thereby investigating if and how demand is met during each hour of the investigated year. It could be shown, that the assumed load can safely be met in all countries for each hour using the scenario's power plant portfolio. Furthermore, it was proven that dispatchable renewable power generation, in particular CSP imports to Europe, have a system stabilizing effect. Using the suggested concept, the utilization of the transfer capacities between countries would decrease until 2050.
In this work, a 100% renewable energy (RE)-based energy system for the year 2030 for Southeast Asia and the Pacific Rim 1 , and Eurasia was prepared and evaluated and various impacts of adiabatic compressed air energy storage (A-CAES) were researched on an hourly resolution for one year. To overcome the intermittency of RE sources and guarantee regular supply of electricity, energy sources are complemented by five energy storage options: batteries, pumped hydro storage (PHS), thermal energy storage (TES), (A-CAES) and power-togas (PtG). In a region-wide scenario the energy system integration is within a sub-region of the individual large areas of Southeast Asia and Eurasia. In this scenario simulation were performed with and without A-CAES integration. For Southeast Asia and Eurasia, the integration of A-CAES has an impact on the share of a particular storage used and this depends on the seasonal variation in RE generation, the supply share of wind energy and demand in the individual areas. For the region-wide scenario for Southeast Asia (region with low seasonal variation and lower supply share of wind energy) the share of A-CAES output was 1.9% in comparison to Eurasia (region with high seasonal variation and a high supply share of wind energy) which had 28.6%. The other impact which was observed was the distribution of the storage technologies after A-CAES integration, since battery output and PtG output were decreased by 72.9% and 21.6% (Eurasia) and 5.5% and 1.6% (Southeast Asia), respectively. However, a large scale grid integration reduces the demand for A-CAES storage drastically and partly even to zero due to substitution by grids, which has been only observed for A-CAES, but not for batteries and PtG. The most valuable application for A-CAES seems to be in rather decentralized or nationwide energy system designs and as a well-adapted storage for the typical generation profiles of wind energy.
In order to define a cost optimal 100% renewable energy system, an hourly resolved model has been created based on linear optimization of energy system parameters under given constrains. The model is comprised of five scenarios for 100% renewable energy power systems in North-East Asia with different high voltage direct current transmission grid development levels, including industrial gas demand and additional energy security. Renewables can supply enough energy to cover the estimated electricity and gas demands of the area in the year 2030 and deliver more than 2000 TW hth of heat on a cost competitive level of 84 €/MW hel for electricity. Further, this can be accomplished for a synthetic natural gas price at the 2013 Japanese liquefied natural gas import price level and at no additional generation costs for the available heat. The total area system cost could reach 69.4 €/MW hel, if only the electricity sector is taken into account. In this system about 20% of the energy is exchanged between the 13 regions, reflecting a rather decentralized character which is supplied 27% by stored energy. The major storage technologies are batteries for daily storage and power-to-gas for seasonal storage. Prosumers are likely to play a significant role due to favourable economics. A highly resilient energy system with very high energy security standards would increase the electricity cost by 23% to 85.6 €/MW hel. The results clearly show that a 100% renewable energy based system is feasible and lower in cost than nuclear energy and fossil carbon capture and storage alternatives.
Presentation at the LUT Doctorial School Conference in Lappeenranta at December 10, 2015.
Increasing ecological problems provoked by human activities, including the fossil fuel based energy sector, emerge the development of a renewable energy (RE) based system as the way to stop pollution and global warming but also to reduce total energy system cost. Small population density and availability of various types of RE resources in Eurasian regions including solar, wind, hydro, biomass and geothermal energy resources enables the very promising project of building a Super Grid connecting different Eurasian regions' energy resources to reach synergy effects and make a 100% RE supply possible. For every sub-region it is defined a cost-optimal distributed and centralized mix of energy technologies and storage options, optimal capacities and hourly generation. Charge and discharge profiles of storages are computed for regions interconnected by high-voltage direct current (HVDC) power lines. System cost and levelized cost of electricity (LCOE) for each sub-region are computed. The results show that a 100% RE-based system is lower in cost than nuclear and fossil carbon capture and storage (CCS) alternatives.
Photovoltaics (PV) is expected to become one of the cheapest forms of electricity generation during the next decades. The Levelised Cost of Electricity (LCOE) of PV has already reached grid parity with retail electricity in many markets and is approaching wholesale parity in some countries. In this paper, it is estimated that the PV LCOE in main European markets is going to decrease from 2015 to 2030 by about 45% and to 2050 by about 60%. The LCOE for utility-scale PV in Europe will be about 25-45 €/MWh in 2030 and about 15-30 €/MWh in 2050 depending on the location. The weighted average cost of capital (WACC) is the most important parameter together with the annual irradiation in the calculation of the PV LCOE. The uncertainty in capital and operational expenditure (CAPEX and OPEX) is relatively less important while the system lifetime and degradation have only a minor effect. The work for this paper has been carried out under the framework of the EU PV Technology Platform.
Further development of the North-East Asian energy system is at a crossroads due to severe limitations of the current conventional energy based system. For North-East Asia it is proposed that the excellent solar and wind resources of the Gobi desert could enable the transformation towards a 100% renewable energy system. An hourly resolved model describes an energy system for North-East Asia, subdivided into 14 regions interconnected by high voltage direct current (HVDC) transmission grids. Simulations are made for highly centralized, decentralized and countrywide grids scenarios. The results for total system levelized cost of electricity (LCOE) are 0.065 and 0.081 €/(kW&h) for the centralized and decentralized approaches for 2030 assumptions. The presented results for 100% renewable resources-based energy systems are lower in LCOE by about 30–40% than recent findings in Europe for conventional alternatives. This research clearly indicates that a 100% renewable resources based energy system is THE real policy option.
This study demonstrates – based on a dynamical simulation of a global, decentralized 100% renewable electricity supply scenario – that a global climate-neutral electricity supply based on the volatile energy sources photovoltaics (PV), wind energy (onshore) and concentrated solar power (CSP) is feasible at decent cost. A central ingredient of this study is a sophisticated model for the hourly electric load demand in >160 countries. To guarantee matching of load demand in each hour, the volatile primary energy sources are complemented by three electricity storage options: batteries, high-temperature thermal energy storage coupled with steam turbine, and renewable power methane (generated via the Power to Gas process) which is reconverted to electricity in gas turbines. The study determines – on a global grid with 1°x1° resolution – the required power plant and storage capacities as well as the hourly dispatch for a 100% renewable electricity supply under the constraint of minimized total system cost (LCOE). Aggregating the results on a national level results in an levelized cost of electricity (LCOE) range of 80-200 EUR/MWh (on a projected cost basis for the year 2020) in this very decentralized approach. As a global average, 142 EUR/MWh are found. Due to the restricted number of technologies considered here, this represents an upper limit for the electricity cost in a fully renewable electricity supply.
Clean power from deserts – the Desertec concept for energy, water and climate security. Whitebook 4th Ed
- G Knies
Knies G. (ed.). Clean power from deserts – the Desertec concept for energy, water and
climate security. Whitebook 4th Ed. DESERTEC Foundation, Hamburg; 2009.
Will solar, batteries and electric cars re-shape the electricity system? Q-Series – Global Utilities, Autos & Chemicals
UBS. Will solar, batteries and electric cars re-shape the electricity system? Q-Series –
Global Utilities, Autos & Chemicals; 2014.
ETRI 2014 -Energy technology reference indicator projections for 2010-2050
European Commission. ETRI 2014 -Energy technology reference indicator projections for
2010-2050. EC Joint Research Centre Institute for Energy and Transport, Petten; 2014.
PV LCOE in Europe 2014-30
- Pv Technology European
- Platform
European PV Technology Platform. PV LCOE in Europe 2014-30. EUPVTP, Munich,
2015; www.eupvplatform.org
Current and Future Cost of Photovoltaics -Long-term Scenarios for Market Development System Prices and LCOE of Utility-Scale PV Systems. study prepared by Fraunhofer Institute for Solar Energy Systems
- Agora Energiewende
Agora Energiewende. Current and Future Cost of Photovoltaics -Long-term Scenarios for
Market Development System Prices and LCOE of Utility-Scale PV Systems. study
prepared by Fraunhofer Institute for Solar Energy Systems; 2015.
Abschlussbericht für das BMBF-Verbundprojekt Biogaseinspeisung. Fraunhofer UMSICHT
- W Urban
- H Lohmann
- K Girod
Urban W, Lohmann H., Girod K. Abschlussbericht für das BMBF-Verbundprojekt
Biogaseinspeisung. Fraunhofer UMSICHT; 2009 [in German].
Stromspeicher in der Energiewende Available at: www.agoraenergiewende.de/themen/optimierung/detailansicht/article/studie-die-energiewendemuss-nicht-auf-stromspeicher-warten
- Agora Energiewende
Agora Energiewende. Stromspeicher in der Energiewende. Agora Energiewende, Berlin;
2014.
Available
at:
www.agoraenergiewende.de/themen/optimierung/detailansicht/article/studie-die-energiewendemuss-nicht-auf-stromspeicher-warten/ [accessed: 30.01.2015] [in German]
Desert power -perspectives on a sustainable power system for EUMENA
- Dii
Dii, 2050 Desert power -perspectives on a sustainable power system for EUMENA. Dii,
Munich; 2012
Comparison of the Potential Role of Adiabatic Compressed Air Energy Storage (A-CAES) for a Fully Sustainable 10 th International Renewable Energy Storage Conference
- A Gulagi
- A Aghahosseini
- D Bogdanov
- Ch Breyer
Gulagi A., Aghahosseini A., Bogdanov D., Breyer Ch., 2016. Comparison of the Potential
Role of Adiabatic Compressed Air Energy Storage (A-CAES) for a Fully Sustainable
10 th International Renewable Energy Storage Conference, March 15-17, 2016, Düsseldorf
Regionale und globale räumliche Verteilung von Biomassepotenzialen
- German Biomass
- Research Centre
German Biomass Research Centre. Regionale und globale räumliche Verteilung von
Biomassepotenzialen. German Biomass Research Centre; 2009 [in German]
Intergovernmental Panel on Climate Change. Special report on RE sources and CC mitigation
Intergovernmental Panel on Climate Change. Special report on RE sources and CC
mitigation. IPCC, Geneva; 2011.
Surface meteorology and solar energy (SSE) release 6.0, NASA SSE 6.0, Earth Science Enterprise Program. National Aeronautic and Space Administration (NASA), Langley
- P W Stackhouse
- C H Whitlock
Stackhouse P.W., Whitlock C.H., (eds.). Surface meteorology and solar energy (SSE)
release 6.0, NASA SSE 6.0, Earth Science Enterprise Program. National Aeronautic and
Space
Administration
(NASA),
Langley;
2008.
Available
at:
http://eosweb.larc.nasa.gov/sse/ [accessed: 28.05.2015]
Surface meteorology and solar energy (SSE) release 6.0 Methodology, NASA SSE 6.0 Available at
- P W Stackhouse
- C H Whitlock
Stackhouse P.W., Whitlock C.H., (eds.). Surface meteorology and solar energy (SSE)
release 6.0 Methodology, NASA SSE 6.0. Earth Science Enterprise Program, National
Aeronautic and Space Administration (NASA), Langley; 2009. Available at:
http://eosweb.larc.nasa.gov/sse/documents/SSE6Methodology.pdf [accessed: 28.05.2015]
Gobitec and Asian super grid for renewable energies in Northeast Asia
- S Mano
- B Ovgor
- Z Samadov
- M Pudlik
- V Jülich
- D Sokolov
Mano S., Ovgor B., Samadov Z., Pudlik M., Jülich V., Sokolov D et al. Gobitec and Asian
super grid for renewable energies in Northeast Asia, report prepared by Energy Charter
Secretariat, Energy Economics Institute of the Republic of Korea, Energy Systems Institute
of the Russian Federation, Ministry of Energy of Mongolia, Japan Renewable Energy
Foundation; 2014.
Regionale und globale räumliche Verteilung von Biomassepotenzialen. German Biomass Research Centre
- German Biomass Research Centre
German Biomass Research Centre. Regionale und globale räumliche Verteilung von
Biomassepotenzialen. German Biomass Research Centre; 2009 [in German]
Technology roadmap -bioenergy for heat and power
International Energy Agency. Technology roadmap -bioenergy for heat and power. IEA
Publications, Paris; 2012.