Existing energy management strategies (EMSs) for hybrid power systems (HPSs) in hydrogen fuel cell vessels (FCVs) are not applicable to scenarios with multiple hydrogen fuel cells (FCs) and lithium batteries (LBs) in parallel, and are difficult to achieve real-time control and optimization for multiple objectives. In this paper, a bi-layer real-time energy management strategy (BLRT-EMS) is proposed. Compared with existing EMSs, the proposed BLRT-EMS implements different control/optimization objectives distributed in the execution layer EMS (EL-EMS) and the decision layer EMS (DL-EMS), which can significantly reduce bus voltage fluctuations, decrease hydrogen consumptions, improve the system efficiency, and have potential for engineering applications. In the first EL-EMS, a decentralized optimal power allocation strategy is proposed, which allows each FC system to allocate the output power ratio according to their generation costs, ensuring consistent performance of multiple FC systems (MFCS) under long-term operating conditions, and thus delaying the degradation rate of FCs. In the second EL-EMS, a distributed cooperative control strategy is proposed to achieve dynamic SoC equalization, proportional output power allocation, and accurate bus voltage restoration among multiple battery storage systems (MBSS) to extend the service life of batteries. In the DL-EMS, an energy coordination optimization strategy between MFCS and MBSS is proposed to achieve hydrogen consumption reduction and system efficiency improvement, thus enhancing the endurance performance of FCV. Finally, test results based on the StarSim experimental platform show that the proposed BLRT-EMS has faster SoC convergence speed, smaller bus voltage deviation, lower hydrogen consumption, higher system efficiency, and lower operation stress than the state-of-the-art methods.
Under complex sea conditions, the energy demand for each device of renewable-energy ships presents a random situation, which makes the complex energy demand of the ship integrated energy system (SIES) uncertain during ship navigation. To ensure the economical, stable, and efficient operation of the SIES, this paper proposes a distributed stochastic energy management method to solve the energy management problem (EMP). Firstly, a framework for the SIES including both renewable energy and traditional energy is constructed. Based on the energy efficiency operation index (EEOI) and the operation mode of energy supply devices during navigation, the EMP of the SIES is raised. Then, considering the distributed structure and limited computing resources of the SIES, a distributed stochastic energy management method is proposed. Through this method, the disturbances of load demand can be effectively suppressed, and a stable energy supply is provided for devices such as power propellers. Furthermore, it is analyzed that the proposed method can converge to the O(η) (η is the fixed step size of the proposed method) neighborhood of the optimal energy management decision in the mean-square-error sense. Finally, the simulation results verify that the mean-square-error-optimal energy management decision of the SIES can be obtained by the proposed method in different scenarios, and the proposed method can solve the EMP of SIES under complex sea conditions.
The emissions of the maritime sector caused by ship transportation and other fossil fuel sources pose a threat to the environment and human health. It drives an increasing interest in adopting electrification solutions to revolutionize the conventional maritime energy-intensive and highly polluting industry. Accordingly, this thesis is one of the pioneering attempts to implement a seaport microgrid and carbon capture shore power system of cold ironing at a port dedicated to sustainability while remaining competitive.
However, the technological and research gaps of the conventional port scheduling paradigm constitute challenges in a synergy between the two prominent maritime electrification systems of seaport microgrids and cold ironing. The incorporation of cold ironing into seaport operations introduces new challenges to handling workflow and the potential impact of such integration has not yet been quantitatively addressed. Developing strategic management to improve port performance is always an issue for the port operators. This research gap motivated this study to develop an integrated operation and energy management framework by executing forecasting and optimization techniques for coordinating these technologies toward the emission neutrality goal.
This thesis begins with an extensive review of the significant aspects of cold ironing technology and seaport microgrids. A range of factors associated with the varying demand for cold ironing in seaport microgrids, requiring advanced forecasting techniques, are described in Chapter 2. Another challenge is that the integration of cold ironing with limited capacities increases the complexity of the existing seaside operation at port namely the berth allocation problem (BAP) and quay crane allocation problem (QCAP). It prolongs the waiting time for the ships to be served at berth. Thus, a seaside operational optimization model is developed in Chapter 3 to cooperatively schedule BAP, QCAP, and cold ironing assignment problems (CIAP). Chapter 4 integrates bilevel optimization as an energy management system (EMS) framework to coordinate the joint cold ironing with the seaport microgrid concept, providing more flexibility in energy scheduling while remaining cost-effective. Finally, Chapter 5 presents the overall conclusions of the thesis, research contribution, and future recommendations.
Shore power is an important green technology used by ports to reduce carbon emissions. This paper investigates how to design subsidy strategy for promoting the installation and utilization of shore power. However, while installation subsidies may promote the installation of SPI in ports, resulting in a reduction in ship emissions, utilization subsidies may attract more ship visits, which may increase the total emissions of a port. Therefore, subsidies for shore power utilization and installation should be optimized to minimize the cost to government (comprising the environmental costs of ship emissions, the cost of utilization or installation subsidies, and carbon taxes) and maximize the profit for ports (including profit from original and new ships, utilization and installation subsidies, and carbon taxes). Using the Stackelberg game methodology, we discuss five cases to give a comprehensive analysis of the design of different subsidy policies, including no subsidy, SPI-utilization subsidy undertaken by port, SPI-utilization subsidy undertaken by port and government, carbon emission tax policy considering SPI-utilization subsidy, and SPI-utilization and SPI-installation subsidies undertaken by port and government. Managerial insights are generated according to the theoretical analysis and numerical experiments results, which can give references to the government and port operators.
Wind propulsion systems (WPS) for commercial ships can be a key ingredient to achieving the IMO green targets. Most WPS installations will operate in conjunction with propellers and marine engines in a hybrid mode, which will affect their performance. The present paper presents the development of a generic, fast, and easy tool to predict the propeller and engine performance variation, along with the cost, as a function of the wind power installed in two operation conditions: fixed ship speed and constant shaft speed. Specific focus is directed toward showing generic trends and trade-offs that inform economic decision-making. To this end, a key feature of the presented work is the ability to assess the cost–benefit of both controllable pitch propellers and fixed pitch propellers (CPPs and FPPs). This provides advice on when, in terms of WPS installation size, it is worthwhile to install which kind of propeller. CPPs are found to be more suitable for newly built wind-powered ships (>70% wind power), while a conventional FPP is satisfactory for wind-assisted ships (<70% wind power) and retrofitted installations. The results for a 91,373 GT bulk carrier showed that a WPS unloads the propeller and the engine, which leads to an increase in the propulsive efficiency and a detrimental rise of the engine specific fuel oil consumption. However, propeller gains are found to be greater than engine losses, which result in extra savings. Thus, not only does a WPS save fuel and corresponding pollutant emissions, but it also increases the entire propulsive efficiency.
Offshore wind energy production has seen a significant expansion in the past decade and has become one of the most important maritime activities. However, the implications of offshore wind farm expansion for maritime security have, so far, received sparse attention in the literature. In this article we conduct one of the first thorough analyses of the security of offshore wind farms and related installations, such as underwater electricity cables, energy islands, and hydrogen plants.
In previous research, there have been more investigations on methanol blended with other fuels such as diesel, biodiesel, gasoline, etc., but fewer investigations on methanol with ignition additives as a mono-fuel. To better understand the methanol mono-fuel combustion characteristics and to further apply them, a combined experimental and simulation study of methanol in a Scania heavy-duty compression ignition (CI) engine was carried out in this work. The experiments consisted of four groups with variable injection timings, variable fraction of ignition additives, variable charge air temperatures, and variable overall excess air ratios/power sweeps. Heat release rate (HRR), cylinder pressure, ignition delay and indicated efficiency were analyzed for each case. The analysis showed that the combustion type was partially premixed combustion (PPC) in some cases and diesel-like combustion in the rest. By observing all cases, the shortest ignition delay was 14.1°, and the longest was 22.8°. The indicated efficiencies were in the range of 0.35 to 0.43. Simulations and validation analyses were performed for all cases by a multi-packets model. The physical and chemical ignition delays were predicted. The physical ignition delays were in the range of 4.25 to 8.10°, and the chemical ignition delays were in the range of 6.66 to 17.1°. The chemical ignition delay was always longer than the physical one. This indicates that chemical ignition delay has to be prioritized to improve the ignition performance of methanol fuel.
Improving the power density of solid oxide fuel cell stacks would significantly enhance this technology for transportation. Using a monolithic structure to downsize the stack dimension offers a key to elevate the power density of solid oxide fuel cell stacks. This innovative design is promising but manufacturing is a challenge. The monolith is co-sintered in one firing step, and the gas channels are formed by burning off sacrificial organic materials. Structure distortion or fracture was observed in post-mortem investigations. In this work a multiscale, multiphysics modelling approach is proposed to describe and resolve this challenge in the debinding process occurring in a monolithic stack, i.e. the burning of organics and transportation of gases through the gradually opening microstructure, as well as the pressure build-up in the microstructure due to gas development. Simulation results show that a prominent pressure peak is experienced in the stack when a plasticiser (polyethylene glycol) and a pore-former (polymethyl methacrylate) are decomposed simultaneously. To reduce the high pressures, we investigate two possible strategies: (i) changing the mixture of organic additives; (ii) modifying the debinding temperature profile. Three tapes with different pore-formers are prepared, and the generated pressures during debinding of the three stacks are compared. The corresponding stack shapes after debinding are recorded. Numerical investigations show a good agreement with the post-mortem observations. By changing the composition of organics the distortion or fracturing of the stack can be avoided. Furthermore, to facilitate stack manufacturing, the high pressures can also be reduced by adjusting the heating rates and dwell temperatures of debinding. By using the new temperature profile suggested by the simulation study, the duration of debinding can also be reduced.
Hydrogen can be key in the energy system transition. We investigate the role of offshore hydrogen generation in a future integrated energy system. By performing energy system optimisation in a model application of the Northern-central European energy system and the North Sea offshore grid towards 2050, we find that offshore hydrogen generation may likely only play a limited role, and that offshore wind energy has higher value when sent to shore in the form of electricity. Forcing all hydrogen generation offshore would lead to increased energy system costs. Under the assumed scenario conditions, which result in deep decarbonisatiton of the energy system towards 2050, hydrogen generation – both onshore and offshore – follows solar PV generation patterns. Combined with hydrogen storage, this is the most cost-effective solution to satisfy future hydrogen demand. Overall, we find that the role of future offshore hydrogen generation should not simply be derived from minimising costs for the offshore sub-system, but by also considering the economic value that such generation would create for the whole integrated energy system. We find as a no-regret option to enable and promote the integration of offshore wind in onshore energy markets via electrical connections.
Formålet med denne anden version af dette notat er stadig at få de vigtigste fakta om atomkraft i Danmark på bordet. I første version af notatet lagde vi op til en åben debat og inviterede til kommentarer og input. Dem har vi modtaget mange af. Det vil vi gerne takke for. Vi har brugt de mange kommentarer til at rette, forbedre, tilføje og uddybe, hvorfor vi nu kan fremlægge anden forbedrede og udbyggede udgave af notatet. Vi er selvfølgelig stadig åbne for at modtage kommentarer og inputs frem mod en version 3.
Nogle af de væsentligste ændringer i forhold til version 1 er:
Der er blevet spurgt til detaljerne i vores analyser og modelberegninger, da det for mange kan være svært at forstå, hvordan en fremtidig elforsyning baseret på vedvarende energi kan være stabil. Derfor har vi uddybet modelberegninger fra version 1 af notatet i to appendikser og tilføjet nye modelberegninger, som uddyber analyserne i forhold til det danske energisystems rolle i Europa. Desuden har vi tilføjet et helt afsnit om stabilitet, som forklarer, hvordan stabilitet og forsyningssikkerhed sikres i et vedvarende energisystem såvel som i et atomkraftsystem.
Der har været kritik af vores valg af eksempler på atomkraftværker, når vi har identificeret anlægsomkostninger og byggetider. Derfor har vi tilføjet flere til listen og uddybet diskussionen af hvilke omkostninger og byggetider, der er
relevante og aktuelle i en dansk sammenhæng. Et særskilt kritikpunkt har været valg af ’kapacitetsfaktor’. Kapacitetsfaktoren udtrykker, hvor meget et værk producerer igennem en periode sammenlignet med, hvor meget det maksimalt vil kunne producere, hvis det kørte ved fuld belastning (fuldlast) i hele perioden. Ved en kapacitetsfaktor på 100% vil værket køre fuldlast i hele perioden og ikke have ’udetider’, hvor værket ikke kan benyttes f.eks. ved direkte nedbrud, vedligehold eller regulering af driften for at følge behovsprofiler. Vi er her blevet kritiseret for at vælge 75% for atomkraftværker, og i stedet er der blevet peget på 85% som mere retvisende. Vi er også blevet kritiseret for ikke at indregne en eventuel udnyttelse af overskudsvarmen fra et atomkraftværk til fjernvarme, og der er blevet spurgt til, om vi har alle omkostninger til elnettet med. Som svar på disse kritikpunkter har vi foretaget flere beregninger med forskellige kapacitetsfaktorer for atomkraftværker samt analyser med og uden fjernvarmeudnyttelse. Hermed kan man klart se betydningen af disse valg af forudsætninger.
Kilden for vores valg af 75% er Det Internationale Energiagenturs World Energy Outlook, hvor de forudser, at atomkraft i 2050 i det Europæiske energisystem vil have en kapacitetsfaktor mellem 70% og 80%. 85% er teknisk muligt, men vælges typisk når atomkraft ikke indgår i sammenhæng med et energisystem med vedvarende energi.
For at styrke gyldigheden af vores beregninger har vi desuden tilføjet nye analyser af Danmark i en Europæisk sammenhæng, hvor vores beregningsmodeller både optimerer på investeringer i produktionskapacitet og på transmissionsledninger.
Disse ekstraanalyser ændrer dog ikke på den centrale hovedkonklusion: At et dansk energisystem med atomkraft er dyrere end et med vind og sol, og at atomkraft tager længere tid at opføre end vind- og solanlæg.
Endelig har der blandt nogle været en forvirring om, hvem vi er, og hvad vores faglighed er i forhold til atomkraftdebatten sammenlignet med forskere, som har en mere specialiseret baggrund i kernefysik eller lignende. Vi er en bred sammensætning af ingeniører, fysikere og økonomer. Vores fælles faglighed er koncentreret om energisystemanalyse, og vores forskningsområde er at analysere, hvordan vi på energiområdet bedst og billigst kan gennemføre den grønne omstilling og hurtigst muligt opnå et CO2-neutralt samfund. Vi er således ikke kun specialister i en enkelt teknologi. Vi er først og fremmest specialister i, hvordan teknologierne spiller sammen, så vi kan finde de bedste løsninger og
optimere det samlede energisystem.
Det er vores vurdering, at det netop er den faglighed og de forskningskompetencer, der er brug for, når konsekvenserne af at investere i atomkraft i Danmark skal sammenlignes med ikke at gøre det. Når trafikforhold skal udvikles og optimeres, er det også trafikforskerens kompetence, der efterspørges, og ikke ekspertise i f.eks. forbrændingsmotorteknologien.
Samlet set er rapporten inddelt i fire kapitler, der fokuserer på forskellige pointer. I kapitel 1 sammenlignes omkostningerne ved at producere en enhed (MWh) el fra henholdsvis atomkraft, sol og vind uafhængigt af resten af energisystemet;
Kapitel 2 har et fokus på de samme teknologier, men hvor de er i drift i energisystemet, og dermed kan betydningen af forskelle i produktionsmønstre fra vedvarende energi og atomkraft kvantificeres. Kapitel 3 fokuserer på den del af energisystemanalyserne, der omhandler forsyningssikkerhed og stabilitet. I kapitel 4 diskuterer vi bygge- og planlægningstider på atomkraft.