Machine prognostics based on health state estimation using SVM

The ability to accurately predict the remaining useful life of machine components is critical for machine continuous operation, and can also improve productivity and enhance system safety. In condition-based maintenance (CBM), maintenance is performed based on information collected through condition monitoring and an assessment of the machine health. Effective diagnostics and prognostics are important aspects of CBM for maintenance engineers to schedule a repair and to acquire replacement components before the components actually fail. All machine components are subjected to degradation processes in real environments and they have certain failure characteristics which can be related to the operating conditions. This paper describes a technique for accurate assessment of the remnant life of machines based on health state probability estimation and involving historical knowledge embedded in the closed loop diagnostics and prognostics systems. The technique uses a Support Vector Machine (SVM) classifier as a tool for estimating health state probability of machine degradation, which can affect the accuracy of prediction. To validate the feasibility of the proposed model, real life historical data from bearings of High Pressure Liquefied Natural Gas (HP-LNG) pumps were analysed and used to obtain the optimal prediction of remaining useful life. The results obtained were very encouraging and showed that the proposed prognostic system based on health state probability estimation has the potential to be used as an estimation tool for remnant life prediction in industrial machinery.

Bearing fault prognosis based on health state probability estimation

In condition-based maintenance (CBM), effective diagnostic and prognostic tools are essential for maintenance engineers to identify imminent fault and predict the remaining useful life before the components finally fail. This enables remedial actions to be taken in advance and reschedule of production if necessary. All machine components are subjected to degradation processes in real environments and they have certain failure characteristics which can be related to the operating conditions. This paper describes a technique for accurate assessment of the remnant life of bearings based on health state probability estimation and historical knowledge embedded in the closed loop diagnostics and prognostics system. The technique uses the Support Vector Machine (SVM) classifier as a tool for estimating health state probability of machine degradation process to provide long term prediction. To validate the feasibility of the proposed model, real life fault historical data from bearings of High Pressure-Liquefied Natural Gas (HP-LNG) pumps were analysed and used to obtain the optimal prediction of remaining useful life (RUL). The results obtained were very encouraging and showed that the proposed prognosis system based on health state probability estimation has the potential to be used as an estimation tool for remnant life prediction in industrial machinery.

Intelligent reliability analysis with incomplete covariates

The reliability analysis is crucial to reducing unexpected down time, severe failures and ever tightened maintenance budget of engineering assets. Hazard based reliability methods are of particular interest as hazard reflects the current health status of engineering assets and their imminent failure risks. Most existing hazard models were constructed using the statistical methods. However, these methods were established largely based on two assumptions: one is the assumption of baseline failure distributions being accurate to the population concerned and the other is the assumption of effects of covariates on hazards. These two assumptions may be difficult to achieve and therefore compromise the effectiveness of hazard models in the application. To address this issue, a non-linear hazard modelling approach is developed in this research using neural networks (NNs), resulting in neural network hazard models (NNHMs), to deal with limitations due to the two assumptions for statistical models. With the success of failure prevention effort, less failure history becomes available for reliability analysis. Involving condition data or covariates is a natural solution to this challenge. A critical issue for involving covariates in reliability analysis is that complete and consistent covariate data are often unavailable in reality due to inconsistent measuring frequencies of multiple covariates, sensor failure, and sparse intrusive measurements. This problem has not been studied adequately in current reliability applications. This research thus investigates such incomplete covariates problem in reliability analysis. Typical approaches to handling incomplete covariates have been studied to investigate their performance and effects on the reliability analysis results. Since these existing approaches could underestimate the variance in regressions and introduce extra uncertainties to reliability analysis, the developed NNHMs are extended to include handling incomplete covariates as an integral part. The extended versions of NNHMs have been validated using simulated bearing data and real data from a liquefied natural gas pump. The results demonstrate the new approach outperforms the typical incomplete covariates handling approaches. Another problem in reliability analysis is that future covariates of engineering assets are generally unavailable. In existing practices for multi-step reliability analysis, historical covariates were used to estimate the future covariates. Covariates of engineering assets, however, are often subject to substantial fluctuation due to the influence of both engineering degradation and changes in environmental settings. The commonly used covariate extrapolation methods thus would not be suitable because of the error accumulation and uncertainty propagation. To overcome this difficulty, instead of directly extrapolating covariate values, projection of covariate states is conducted in this research. The estimated covariate states and unknown covariate values in future running steps of assets constitute an incomplete covariate set which is then analysed by the extended NNHMs. A new assessment function is also proposed to evaluate risks of underestimated and overestimated reliability analysis results. A case study using field data from a paper and pulp mill has been conducted and it demonstrates that this new multi-step reliability analysis procedure is able to generate more accurate analysis results.

Integrated approach for diagnostics and prognostics of HP LNG pump based on health state probability estimation

Effective machine fault prognostic technologies can lead to elimination of unscheduled downtime and increase machine useful life and consequently lead to reduction of maintenance costs as well as prevention of human casualties in real engineering asset management. This paper presents a technique for accurate assessment of the remnant life of machines based on health state probability estimation technique and historical failure knowledge embedded in the closed loop diagnostic and prognostic system. To estimate a discrete machine degradation state which can represent the complex nature of machine degradation effectively, the proposed prognostic model employed a classification algorithm which can use a number of damage sensitive features compared to conventional time series analysis techniques for accurate long-term prediction. To validate the feasibility of the proposed model, the five different level data of typical four faults from High Pressure Liquefied Natural Gas (HP-LNG) pumps were used for the comparison of intelligent diagnostic test using five different classification algorithms. In addition, two sets of impeller-rub data were analysed and employed to predict the remnant life of pump based on estimation of health state probability using the Support Vector Machine (SVM) classifier. The results obtained were very encouraging and showed that the proposed prognostics system has the potential to be used as an estimation tool for machine remnant life prediction in real life industrial applications.

Sediment contaminant surveillance in Milford Haven Waterway

Sediment contaminants were monitored in Milford Haven Waterway (MHW) since 1978 (hydrocarbons) and 1982 (metals), with the aim of providing surveillance of environmental quality in one of the UK’s busiest oil and gas ports. This aim is particularly important during and after large-scale investment in liquefied natural gas (LNG) facilities. However, methods inevitably have changed over the years, compounding the difficulties of coordinating sampling and analytical programmes. After a review by the MHW Environmental Surveillance Group (MHWESG), sediment hydrocarbon chemistry was investigated in detail in 2010. Natural Resources Wales (NRW) contributed their MHW data for 2007 and 2012, collected to assess the condition of the Special Area of Conservation (SAC) designated under the European Union Habitats Directive. Datasets during 2007-2012 have thus been more comparable. The results showed conclusively that a MHW-wide peak in concentrations of sediment polycyclic aromatic hydrocarbons (PAHs), metals and other contaminants occurred in late 2007. This was corroborated by independent annual monitoring at one centrally-located station with peaks in early 2008 and 2011. The spatial and temporal patterns of recovery from the 2007 peak, shown by MHW-wide surveys in 2010 and 2012, indicate several probable causes of contaminant trends, as follows: atmospheric deposition, catchment runoff, sediment resuspension from dredging, and construction of two LNG terminals and a power station. Adverse biological effects predictable in 2007 using international sediment quality guidelines, were independently tested by data from monitoring schemes of more than a decade duration in MHW (starfish, limpets), and in the wider SAC (grey seals). Although not proving cause and effect, many of these potential biological receptors showed a simultaneous negative response to the elevated 2007 contamination following intense dredging activity in 2006. Wetland bird counts were typically at a peak in the winter of 2005-2006 previous to peak dredging. In the following winter 2006-2007, shelduck in Pembroke River showed their lowest winter count, and spring 2007 was the largest ever drop in numbers of broods across MHW between successive breeding seasons. Wigeon counts in Pembroke River were again low in late 2012 after further dredging nearby. These results are strongly supported by PAH data reported previously from invertebrate bioaccumulation studies in MHW 2007-2010, themselves closely reflecting sediment

Ruostumattoman teräksen käyttö ja käyttövaatimukset LNG:n varasto- ja kuljetusjärjestelmissä

On arvioitu, että koko maailmaa kattava energiantarve nousee 1,2 % vuosinopeudella. Asiaa ei kaunista se tosiasia, että valtaosa tänä päivänä tuotetusta energiasta (85 %) on lähtöisin fossiilisista polttoaineista. Päästöjen on arvioitu lisääntyvän 2005 – 2030 välisenä aikana noin 30 %, vaikka uusiutuvaa energiaa käytettäisiin ja prosessien hyötysuhteet paranisivat. Vuonna 2015 voimaan tuleva rikkidirektiivi on pakottanut asiantuntijat löytämään korvaavan energialähteen, joka vähentäisi päästöjen määrää, ja jota esiintyisi suurissa määrissä. Nesteytetty maakaasu, LNG, toteuttaa edellä mainitut ehdot. Tässä diplomityössä perehdytään LNG-teollisuuden arvoketjuun Suomessa sekä muualla maailmassa. Työssä pääpainona on selvittää ruostumattoman teräksen käyttömahdollisuuksia nykyisessä LNG-teollisuuden arvoketjussa sekä selvittää sen uusia sovelluskohteita LNG-alalla tulevaisuudessa. Diplomityössä on tehty laaja kirjallisuuskatsaus LNG:n arvoketjuun ja uuden EN 1.4420 ruostumattoman teräksen soveltuvuuteen kryogeenisissä lämpötiloissa. Työn aikana on myös tehty useita haastatteluja LNG-teollisuudessa toimivien henkilöiden kanssa. Menetelmäkokeita ja koehitsauksia on suoritettu näiden haastattelujen perusteella.

Analyse géographique des investissements internationaux de la China National Petroleum Corporation

Ce mémoire propose une analyse de l’expansion internationale de la China National Petroleum Corporation (CNPC) et des impacts de cette expansion sur la sécurité énergétique de la Chine. Dans le cadre de cette recherche, l’approvisionnement énergétique d’un pays est jugé sécuritaire lorsqu’une quantité suffisante de ressources nécessaires pour combler sa demande en énergie sont présentes, disponibles et accessibles et que son approvisionnement en services énergétiques demeure fiable et abordable. La recherche comporte quatre volets. Le premier volet porte sur les étapes de la restructuration de l’industrie pétrolière chinoise depuis 1949. Celle-ci est analysée au travers des changements dans les modes de gestion des compagnies pétrolières nationales et dans leurs relations avec le gouvernement chinois. Le deuxième volet traite de la diversification et des nouvelles spécialisations de CNPC. Ces aspects sont étudiés dans le cadre d’une analyse du pourcentage de ses actifs dans chaque segment industriel (aval, intermédiaire et amont) obtenus grâce à ses rapports annuels. Le troisième volet aborde la répartition géographique des activités de la compagnie que l’on étudie à l’aide d’une analyse approfondie de près de 150 investissements, acquisitions et contrats réalisés à l’étranger entre 1992 et 2014. Le quatrième volet aborde les impacts des investissements à l’étranger de la compagnie sur la sécurité énergétique de la Chine. Ces impacts sont mesurés par l’entremise d’une analyse des flux pétroliers internationaux vers la Chine que l’on compare à la production de CNPC par pays. Ce mémoire permet de déterminer que l’expansion internationale de CNPC sert d’abord et avant tout les intérêts économiques de la compagnie. Ce sont surtout ses investissements dans la construction d’infrastructures de transport (oléoducs, gazoducs ainsi que les usines et terminaux de liquéfaction de gaz naturel liquéfié) qui apportent des bénéfices directs à la sécurité énergétique de la Chine. La contribution des investissements dans les autres secteurs est beaucoup moins systématique et dépend largement de la période au cours de laquelle ils ont été effectués.

Essays on infrastructure in Brazil

A presente tese engloba cinco trabalhos sobre dois setores brasileiros de infraestrutura: setor de energia e de transportes. No primeiro trabalho, modela-se o lance dos leilões de linhas de transmissão de energia, buscando compreender porque os lances ganhadores têm se situado em níveis abaixo do que se espera. No segundo paper, estima-se a demanda de energia do Brasil e as elasticidades preço e renda que os consumidores apresentem em relação a essa demanda, usando uma técnica ainda não aplicada na literatura e incluindo o período da Crise do Racionamento – a qual pode ter mudado o padrão de consumo dos agentes. No terceiro trabalho, estuda-se a evolução do mercado de gás natural liquefeito (GNL) ao redor do mundo. O GNL pode ser o link que faltava entre os mercados de gás natural e essa hipótese é testada por meio de análises de séries de tempo e de cópulas. O quarto paper discute a entrada do GNL no sistema energético brasileiro e suas eventuais consequências. Por fim, o quinto paper analisa a experiência de leilões de rodovias no Brasil. O trabalho levanta relevantes insights a respeito do modelo de leilão utilizado e dos detalhes contratuais dessas licitações.

An assessment of the economic impact of climate change on the Agriculture, Energy and Health sectors in Trinidad and Tobago

This report analyses the agriculture, energy, and health sectors in Trinidad and Tobago to assess the potential economic impacts of climate change on the sectors. The fundamental aim of this report is to assist with the development of strategies to deal with the potential impact of climate change on Trinidad and Tobago. It also has the potential to provide essential input for identifying and preparing policies and strategies to help advance the Caribbean subregion closer to solving problems associated with climate change and attaining individual and regional sustainable development goals. Some of the key anticipated impacts of climate change for the Caribbean include elevated air and sea-surface temperatures, sea-level rise, possible changes in extreme events and a reduction in freshwater resources. The economic impact of climate change on the three sectors was estimated for the A2 and B2 IPCC scenarios until 2050. An exploration of various adaptation strategies was also undertaken for each sector using standard evaluation techniques. The study of the impact of climate change on the agriculture sector focused on root crops, green vegetables and fisheries. For these sectors combined, the cumulative loss under the A2 scenario is calculated as approximately B$2.24 and approximately B$1.72 under the B2 scenario by 2050. This is equivalent to 1.37% and 1.05% of the 2008 GDP under the A2 and B2 scenarios, respectively. Given the potential for significant damage to the agriculture sector a large number of potential adaptation measures were considered. Out of these a short-list of 10 potential options were selected by applying 10 evaluation criteria. All of the adaptation strategies showed positive benefits. The analysis indicate that the options with the highest net benefits are: (1) Building on-farm water storage, (2) Mainstreaming climate change issues into agricultural management and (3) Using drip irrigation. Other attractive options include water harvesting. The policy decisions by governments should include these assessments, the omitted intangible benefits, as well as the provision of other social goals such as employment. The analysis of the energy sector has shown that the economic impact of climate change during 2011-2050 is similar under the A2 (US$142.88 million) and B2 (US$134.83 million) scenarios with A2 scenario having a slightly higher cost (0.737% of 2009 GDP) than the B2 scenario (0.695% of 2009 GDP) for the period. On the supply side, analyses indicate that Trinidad and Tobago’s energy sector will be susceptible to the climate change policies of major energy-importing countries (the United States of America and China), and especially to their renewable energy strategies. Implementation of foreign oil substitution policy by the United States of America will result in a decline in Trinidad and Tobago’s Liquefied Natural Gas (LNG) export (equivalent to 2.2% reduction in 2009 GDP) unless an alternative market is secured for the lost United States of America market. China, with its rapid economic growth and the highest population in the world, offers a potential replacement market for Trinidad and Tobago’s LNG export. In this context the A2 scenario will offer the best option for Trinidad and Tobago’s energy sector. The cost-benefit analysis undertaken on selected adaptation strategies reveal that the benefit-cost ratio of replacing electric water heaters with solar water heaters is the most cost-effective. It was also found that the introduction of Compact Fluorescent Light (CFL) and Variable Refrigerant Volume (VRV) air conditioners surpasses the projected cost of increased electricity consumption due to climate change, and provides an economic rationale for the adoption of these adaptation options even in a situation of increased electricity consumption occasioned by climate change. Finally, the conversion of motor fleets to Compressed Natural Gas (CNG) is a cost-effective adaptation option for the transport sector, although it has a high initial cost of implementation and the highest per capita among the four adaptation options evaluated. To investigate the effect of climate change on the health sector dengue fever, leptospirosis, food borne illnesses, and gastroenteritis were examined. The total number of new dengue cases for the period 2008 to 2050 was 204,786 for BAU, 153,725 for A2 and 131,890 for the B2 scenario. With regard to the results for leptospirosis, A2 and B2 seem to be following a similar path with total number of new cases in the A2 scenario being 9,727 and 9,218 cases under the B2 scenario. Although incidence levels in the BAU scenario coincided with those of A2 and B2 prior to 2020, they are somewhat lower post 2020. A similar picture emerges for the scenarios as they relate to food-borne illnesses and to gastroenteritis. Specifically for food-borne illnesses, the BAU scenario recorded 27,537 cases, the A2 recorded 28,568 cases and the B2 recorded 28,679 cases. The focus on the selected sources of morbidity in the health sector has highlighted the fact that the vulnerability of the country’s health sector to climate change does not depend solely on exogenously derived impacts, but also on the behaviour and practices among the population. It is clear that the vulnerability which became evident in the analysis of the impacts on dengue fever, leptospirosis and food-borne illnesses is not restricted solely to climate or other external factors. The most important adaptation strategy being recommended targets lifestyle, behaviour and attitude changes. The population needs to be encouraged to alter their behaviours and practices so as to minimise their exposure to harmful outcomes as it relates to the incidence of these diseases.

An assessment of the economic impact of climate change on the Energy Sector in Trinidad and Tobago

The energy sector is a dominant one in Trinidad and Tobago and it plays an important role in the twin-island republic‟s economy. In 2008, the share of the energy sector in gross domestic product (GDP) amounted to approximately 48% while contributing 57% to total Government revenue. In that same year, the sector‟s share of merchandise exports was 88%, made up mainly of refined oil products including petroleum, liquefied natural gas (LNG), and natural gas liquids (Central Bank of Trinidad and Tobago, 2009). Trinidad and Tobago is the main exporter of oil in the Caribbean region and the main producer of liquefied natural gas in Latin America and the Caribbean. The role of the country‟s energy sector is, therefore, not limited to serving as the engine of growth for the national economy but also includes providing energy security for the small island developing States of the Caribbean. However, with its hydrocarbon-based economy, Trinidad and Tobago is ranked seventh in the world in terms of carbon dioxide (CO2) emissions per capita, producing an estimated 40 million tonnes of CO2 annually. Almost 90% of these CO2 emissions are attributed directly to the energy sector through petrochemical production (56%), power generation (30%) and flaring (3%). Trinidad and Tobago is a ratified signatory to the United Nations Framework Convention on Climate Change and the Kyoto Protocol. Although, as a non-Annex 1 country, Trinidad and Tobago is not required to cut its greenhouse gas emissions under the Protocol, it is currently finalizing a climate change policy document as well as a national energy policy with specific strategies to address climate change. The present study complements the climate change policy document by providing an economic analysis of the impact that climate change could have on the energy sector in Trinidad and Tobago under the Intergovernmental Panel on Climate Change alternative climate scenarios (A2 and B2) as compared to a baseline situation of no climate change. Results of analyses indicate that, in the short-run, climate change, represented by change in temperature, is not a significant determinant of domestic consumption of energy, electricity in particular, in Trinidad and Tobago. With energy prices subsidized domestically and fixed for years at a time, energy price does not play a role in determining electricity demand. Economic growth, as indicated by Gross Domestic Product (GDP), is the single major determinant of electricity consumption in the short-run. In the long-run, temperature, GDP, and patterns of electricity use, jointly determine electricity consumption. Variations in average annual temperature due to climate change for the A2 scenario are expected to lead to an increase in electricity consumption per capita, equivalent to an annual increase of 1.07% over the 2011 baseline value of electricity consumption per capita. Under the B2 scenario, the average annual increase in electricity consumption per capita over the 2011 baseline value is expected to be 1.01%. The estimated economic impact of climate change on electricity consumption for the period 2011-2050 is valued at US$ 142.88 million under the A2 scenario and US$ 134.83million under the B2 scenario. These economic impact estimates are equivalent to a loss of 0.737% of 2009 GDP under the A2 climate scenario and a loss of 0.695% of 2009 GDP under the B2 scenario. On the energy supply side, sea level rise and storm surges present significant risks to oil installations and infrastructure at the Petroleum Company of Trinidad and Tobago (PETROTRIN) Pointe-a-Pierre facilities (Singh and El Fouladi, 2006). However, data limitations do not permit the conduct of an economic analysis of the impact of projected sea level rise on oil and gas production.

Development of advanced tools and methods for the assessment and management of risk due to atypical major accident scenarios

Proper hazard identification has become progressively more difficult to achieve, as witnessed by several major accidents that took place in Europe, such as the Ammonium Nitrate explosion at Toulouse (2001) and the vapour cloud explosion at Buncefield (2005), whose accident scenarios were not considered by their site safety case. Furthermore, the rapid renewal in the industrial technology has brought about the need to upgrade hazard identification methodologies. Accident scenarios of emerging technologies, which are not still properly identified, may remain unidentified until they take place for the first time. The consideration of atypical scenarios deviating from normal expectations of unwanted events or worst case reference scenarios is thus extremely challenging. A specific method named Dynamic Procedure for Atypical Scenarios Identification (DyPASI) was developed as a complementary tool to bow-tie identification techniques. The main aim of the methodology is to provide an easier but comprehensive hazard identification of the industrial process analysed, by systematizing information from early signals of risk related to past events, near misses and inherent studies. DyPASI was validated on the two examples of new and emerging technologies: Liquefied Natural Gas regasification and Carbon Capture and Storage. The study broadened the knowledge on the related emerging risks and, at the same time, demonstrated that DyPASI is a valuable tool to obtain a complete and updated overview of potential hazards. Moreover, in order to tackle underlying accident causes of atypical events, three methods for the development of early warning indicators were assessed: the Resilience-based Early Warning Indicator (REWI) method, the Dual Assurance method and the Emerging Risk Key Performance Indicator method. REWI was found to be the most complementary and effective of the three, demonstrating that its synergy with DyPASI would be an adequate strategy to improve hazard identification methodologies towards the capture of atypical accident scenarios.

Sistema de descarga para metaneros de hasta 145000 m3 con gasinera para buques a propulsión de GNL

Current social demand for more environmentally-friendly fuels environment has imposed stringent emissions standards infectious greenhouse affecting all means of transport, including maritime. A few free zones emissions (ECA) in waters around the world have been established. This has driven to the Liquefied Natural Gas (LNG) as the fuel of the future for ships to comply with emissions laid down by the Convention International Prevention of the Pollution from Ships (MARPOL). The present work proposes the installation of a LNG station for ships in the future regasification plant of Granadilla (Santa Cruz de Tenerife). The work has understood the design and sizing of the receiving of the regasification plant terminal pipelines, as well as pipes for the LNG station. La demanda social actual por combustibles más respetuosos con el medio ambiente ha impuesto unas estrictas normas de emisiones de gases infecto invernadero que afectan a todos los medios de transporte, incluido el marítimo. Se han establecido unas zonas libres de emisiones (ECA) en aguas de todo el mundo. Esto ha impulsado al Gas Natural Licuado (GNL) como el combustible del futuro para buques para cumplir con las emisiones fijadas por la Convención Internacional de Prevención de la Contaminación de Barcos (MARPOL). El presente trabajo propone la instalación de una gasinera para buques en la futura planta de regasificación de Granadilla (Santa Cruz de Tenerife). El trabajo ha comprendido el diseño y dimensionamiento de las tuberías de la terminal de recepción de la planta de regasificación, así como las tuberías para la gasinera.

Evaluación de las Consecuencias de la Nueva Regulación de la OMI sobre Combustibles Marinos

El 10 de octubre de 2008 la Organización Marítima Internacional (OMI) firmó una modificación al Anexo VI del convenio MARPOL 73/78, por la que estableció una reducción progresiva de las emisiones de óxidos de azufre (SOx) procedentes de los buques, una reducción adicional de las emisiones de óxidos de nitrógeno (NOx), así como límites en las emisiones de dióxido de Carbono (CO2) procedentes de los motores marinos y causantes de problemas medioambientales como la lluvia ácida y efecto invernadero. Centrándonos en los límites sobre las emisiones de azufre, a partir del 1 de enero de 2015 esta normativa obliga a todos los buques que naveguen por zonas controladas, llamadas Emission Control Area (ECA), a consumir combustibles con un contenido de azufre menor al 0,1%. A partir del 1 de enero del año 2020, o bien del año 2025, si la OMI decide retrasar su inicio, los buques deberán consumir combustibles con un contenido de azufre menor al 0,5%. De igual forma que antes, el contenido deberá ser rebajado al 0,1%S, si navegan por el interior de zonas ECA. Por su parte, la Unión Europea ha ido más allá que la OMI, adelantando al año 2020 la aplicación de los límites más estrictos de la ley MARPOL sobre las aguas de su zona económica exclusiva. Para ello, el 21 de noviembre de 2013 firmó la Directiva 2012 / 33 / EU como adenda a la Directiva de 1999. Tengamos presente que la finalidad de estas nuevas leyes es la mejora de la salud pública y el medioambiente, produciendo beneficios sociales, en forma de reducción de enfermedades, sobre todo de tipo respiratorio, a la vez que se reduce la lluvia ácida y sus nefastas consecuencias. La primera pregunta que surge es ¿cuál es el combustible actual de los buques y cuál será el que tengan que consumir para cumplir con esta Regulación? Pues bien, los grandes buques de navegación internacional consumen hoy en día fuel oil con un nivel de azufre de 3,5%. ¿Existen fueles con un nivel de azufre de 0,5%S? Como hemos concluido en el capítulo 4, para las empresas petroleras, la producción de fuel oil como combustible marino es tratada como un subproducto en su cesta de productos refinados por cada barril de Brent, ya que la demanda de fuel respecto a otros productos está bajando y además, el margen de beneficio que obtienen por la venta de otros productos petrolíferos es mayor que con el fuel. Así, podemos decir que las empresas petroleras no están interesadas en invertir en sus refinerías para producir estos fueles con menor contenido de azufre. Es más, en el caso de que alguna compañía decidiese invertir en producir un fuel de 0,5%S, su precio debería ser muy similar al del gasóleo para poder recuperar las inversiones empleadas. Por lo tanto, el único combustible que actualmente cumple con los nuevos niveles impuestos por la OMI es el gasóleo, con un precio que durante el año 2014 estuvo a una media de 307 USD/ton más alto que el actual fuel oil. Este mayor precio de compra de combustible impactará directamente sobre el coste del trasporte marítimo. La entrada en vigor de las anteriores normativas está suponiendo un reto para todo el sector marítimo. Ante esta realidad, se plantean diferentes alternativas con diferentes implicaciones técnicas, operativas y financieras. En la actualidad, son tres las alternativas con mayor aceptación en el sector. La primera alternativa consiste en “no hacer nada” y simplemente cambiar el tipo de combustible de los grandes buques de fuel oil a gasóleo. Las segunda alternativa es la instalación de un equipo scrubber, que permitiría continuar con el consumo de fuel oil, limpiando sus gases de combustión antes de salir a la atmósfera. Y, por último, la tercera alternativa consiste en el uso de Gas Natural Licuado (GNL) como combustible, con un precio inferior al del gasóleo. Sin embargo, aún existen importantes incertidumbres sobre la evolución futura de precios, operación y mantenimiento de las nuevas tecnologías, inversiones necesarias, disponibilidad de infraestructura portuaria e incluso el desarrollo futuro de la propia normativa internacional. Estas dudas hacen que ninguna de estas tres alternativas sea unánime en el sector. En esta tesis, tras exponer en el capítulo 3 la regulación aplicable al sector, hemos investigado sus consecuencias. Para ello, hemos examinado en el capítulo 4 si existen en la actualidad combustibles marinos que cumplan con los nuevos límites de azufre o en su defecto, cuál sería el precio de los nuevos combustibles. Partimos en el capítulo 5 de la hipótesis de que todos los buques cambian su consumo de fuel oil a gasóleo para cumplir con dicha normativa, calculamos el incremento de demanda de gasóleo que se produciría y analizamos las consecuencias que este hecho tendría sobre la producción de gasóleos en el Mediterráneo. Adicionalmente, calculamos el impacto económico que dicho incremento de coste producirá sobre sector exterior de España. Para ello, empleamos como base de datos el sistema de control de tráfico marítimo Authomatic Identification System (AIS) para luego analizar los datos de todos los buques que han hecho escala en algún puerto español, para así calcular el extra coste anual por el consumo de gasóleo que sufrirá el transporte marítimo para mover todas las importaciones y exportaciones de España. Por último, en el capítulo 6, examinamos y comparamos las otras dos alternativas al consumo de gasóleo -scrubbers y propulsión con GNL como combustible- y, finalmente, analizamos en el capítulo 7, la viabilidad de las inversiones en estas dos tecnologías para cumplir con la regulación. En el capítulo 5 explicamos los numerosos métodos que existen para calcular la demanda de combustible de un buque. La metodología seguida para su cálculo será del tipo bottom-up, que está basada en la agregación de la actividad y las características de cada tipo de buque. El resultado está basado en la potencia instalada de cada buque, porcentaje de carga del motor y su consumo específico. Para ello, analizamos el número de buques que navegan por el Mediterráneo a lo largo de un año mediante el sistema AIS, realizando “fotos” del tráfico marítimo en el Mediterráneo y reportando todos los buques en navegación en días aleatorios a lo largo de todo el año 2014. Por último, y con los datos anteriores, calculamos la demanda potencial de gasóleo en el Mediterráneo. Si no se hace nada y los buques comienzan a consumir gasóleo como combustible principal, en vez del actual fuel oil para cumplir con la regulación, la demanda de gasoil en el Mediterráneo aumentará en 12,12 MTA (Millones de Toneladas Anuales) a partir del año 2020. Esto supone alrededor de 3.720 millones de dólares anuales por el incremento del gasto de combustible tomando como referencia el precio medio de los combustibles marinos durante el año 2014. El anterior incremento de demanda en el Mediterráneo supondría el 43% del total de la demanda de gasóleos en España en el año 2013, incluyendo gasóleos de automoción, biodiesel y gasóleos marinos y el 3,2% del consumo europeo de destilados medios durante el año 2014. ¿Podrá la oferta del mercado europeo asumir este incremento de demanda de gasóleos? Europa siempre ha sido excedentaria en gasolina y deficitaria en destilados medios. En el año 2009, Europa tuvo que importar 4,8 MTA de Norte América y 22,1 MTA de Asia. Por lo que, este aumento de demanda sobre la ya limitada capacidad de refino de destilados medios en Europa incrementará las importaciones y producirá también aumentos en los precios, sobre todo del mercado del gasóleo. El sector sobre el que más impactará el incremento de demanda de gasóleo será el de los cruceros que navegan por el Mediterráneo, pues consumirán un 30,4% de la demanda de combustible de toda flota mundial de cruceros, lo que supone un aumento en su gasto de combustible de 386 millones de USD anuales. En el caso de los RoRos, consumirían un 23,6% de la demanda de la flota mundial de este tipo de buque, con un aumento anual de 171 millones de USD sobre su gasto de combustible anterior. El mayor incremento de coste lo sufrirán los portacontenedores, con 1.168 millones de USD anuales sobre su gasto actual. Sin embargo, su consumo en el Mediterráneo representa sólo el 5,3% del consumo mundial de combustible de este tipo de buques. Estos números plantean la incertidumbre de si semejante aumento de gasto en buques RoRo hará que el transporte marítimo de corta distancia en general pierda competitividad sobre otros medios de transporte alternativos en determinadas rutas. De manera que, parte del volumen de mercancías que actualmente transportan los buques se podría trasladar a la carretera, con los inconvenientes medioambientales y operativos, que esto produciría. En el caso particular de España, el extra coste por el consumo de gasóleo de todos los buques con escala en algún puerto español en el año 2013 se cifra en 1.717 millones de EUR anuales, según demostramos en la última parte del capítulo 5. Para realizar este cálculo hemos analizado con el sistema AIS a todos los buques que han tenido escala en algún puerto español y los hemos clasificado por distancia navegada, tipo de buque y potencia. Este encarecimiento del transporte marítimo será trasladado al sector exterior español, lo cual producirá un aumento del coste de las importaciones y exportaciones por mar en un país muy expuesto, pues el 75,61% del total de las importaciones y el 53,64% del total de las exportaciones se han hecho por vía marítima. Las tres industrias que se verán más afectadas son aquellas cuyo valor de mercancía es inferior respecto a su coste de transporte. Para ellas los aumentos del coste sobre el total del valor de cada mercancía serán de un 2,94% para la madera y corcho, un 2,14% para los productos minerales y un 1,93% para las manufacturas de piedra, cemento, cerámica y vidrio. Las mercancías que entren o salgan por los dos archipiélagos españoles de Canarias y Baleares serán las que se verán más impactadas por el extra coste del transporte marítimo, ya que son los puertos más alejados de otros puertos principales y, por tanto, con más distancia de navegación. Sin embargo, esta no es la única alternativa al cumplimiento de la nueva regulación. De la lectura del capítulo 6 concluimos que las tecnologías de equipos scrubbers y de propulsión con GNL permitirán al buque consumir combustibles más baratos al gasoil, a cambio de una inversión en estas tecnologías. ¿Serán los ahorros producidos por estas nuevas tecnologías suficientes para justificar su inversión? Para contestar la anterior pregunta, en el capítulo 7 hemos comparado las tres alternativas y hemos calculado tanto los costes de inversión como los gastos operativos correspondientes a equipos scrubbers o propulsión con GNL para una selección de 53 categorías de buques. La inversión en equipos scrubbers es más conveniente para buques grandes, con navegación no regular. Sin embargo, para buques de tamaño menor y navegación regular por puertos con buena infraestructura de suministro de GNL, la inversión en una propulsión con GNL como combustible será la más adecuada. En el caso de un tiempo de navegación del 100% dentro de zonas ECA y bajo el escenario de precios visto durante el año 2014, los proyectos con mejor plazo de recuperación de la inversión en equipos scrubbers son para los cruceros de gran tamaño (100.000 tons. GT), para los que se recupera la inversión en 0,62 años, los grandes portacontenedores de más de 8.000 TEUs con 0,64 años de recuperación y entre 5.000-8.000 TEUs con 0,71 años de recuperación y, por último, los grandes petroleros de más de 200.000 tons. de peso muerto donde tenemos un plazo de recuperación de 0,82 años. La inversión en scrubbers para buques pequeños, por el contrario, tarda más tiempo en recuperarse llegando a más de 5 años en petroleros y quimiqueros de menos de 5.000 toneladas de peso muerto. En el caso de una posible inversión en propulsión con GNL, las categorías de buques donde la inversión en GNL es más favorable y recuperable en menor tiempo son las más pequeñas, como ferris, cruceros o RoRos. Tomamos ahora el caso particular de un buque de productos limpios de 38.500 toneladas de peso muerto ya construido y nos planteamos la viabilidad de la inversión en la instalación de un equipo scrubber o bien, el cambio a una propulsión por GNL a partir del año 2015. Se comprueba que las dos variables que más impactan sobre la conveniencia de la inversión son el tiempo de navegación del buque dentro de zonas de emisiones controladas (ECA) y el escenario futuro de precios del MGO, HSFO y GNL. Para realizar este análisis hemos estudiado cada inversión, calculando una batería de condiciones de mérito como el payback, TIR, VAN y la evolución de la tesorería del inversor. Posteriormente, hemos calculado las condiciones de contorno mínimas de este buque en concreto para asegurar una inversión no sólo aceptable, sino además conveniente para el naviero inversor. En el entorno de precios del 2014 -con un diferencial entre fuel y gasóleo de 264,35 USD/ton- si el buque pasa más de un 56% de su tiempo de navegación en zonas ECA, conseguirá una rentabilidad de la inversión para inversores (TIR) en el equipo scrubber que será igual o superior al 9,6%, valor tomado como coste de oportunidad. Para el caso de inversión en GNL, en el entorno de precios del año 2014 -con un diferencial entre GNL y gasóleo de 353,8 USD/ton FOE- si el buque pasa más de un 64,8 % de su tiempo de navegación en zonas ECA, conseguirá una rentabilidad de la inversión para inversores (TIR) que será igual o superior al 9,6%, valor del coste de oportunidad. Para un tiempo en zona ECA estimado de un 60%, la rentabilidad de la inversión (TIR) en scrubbers para los inversores será igual o superior al 9,6%, el coste de oportunidad requerido por el inversor, para valores del diferencial de precio entre los dos combustibles alternativos, gasóleo (MGO) y fuel oil (HSFO) a partir de 244,73 USD/ton. En el caso de una inversión en propulsión GNL se requeriría un diferencial de precio entre MGO y GNL de 382,3 USD/ton FOE o superior. Así, para un buque de productos limpios de 38.500 DWT, la inversión en una reconversión para instalar un equipo scrubber es más conveniente que la de GNL, pues alcanza rentabilidades de la inversión (TIR) para inversores del 12,77%, frente a un 6,81% en el caso de invertir en GNL. Para ambos cálculos se ha tomado un buque que navegue un 60% de su tiempo por zona ECA y un escenario de precios medios del año 2014 para el combustible. Po otro lado, las inversiones en estas tecnologías a partir del año 2025 para nuevas construcciones son en ambos casos convenientes. El naviero deberá prestar especial atención aquí a las características propias de su buque y tipo de navegación, así como a la infraestructura de suministros y vertidos en los puertos donde vaya a operar usualmente. Si bien, no se ha estudiado en profundidad en esta tesis, no olvidemos que el sector marítimo debe cumplir además con las otras dos limitaciones que la regulación de la OMI establece sobre las emisiones de óxidos de Nitrógeno (NOx) y Carbono (CO2) y que sin duda, requerirán adicionales inversiones en diversos equipos. De manera que, si bien las consecuencias del consumo de gasóleo como alternativa al cumplimiento de la Regulación MARPOL son ciertamente preocupantes, existen alternativas al uso del gasóleo, con un aumento sobre el coste del transporte marítimo menor y manteniendo los beneficios sociales que pretende dicha ley. En efecto, como hemos demostrado, las opciones que se plantean como más rentables desde el punto de vista financiero son el consumo de GNL en los buques pequeños y de línea regular (cruceros, ferries, RoRos), y la instalación de scrubbers para el resto de buques de grandes dimensiones. Pero, por desgracia, estas inversiones no llegan a hacerse realidad por el elevado grado de incertidumbre asociado a estos dos mercados, que aumenta el riesgo empresarial, tanto de navieros como de suministradores de estas nuevas tecnologías. Observamos así una gran reticencia del sector privado a decidirse por estas dos alternativas. Este elevado nivel de riesgo sólo puede reducirse fomentando el esfuerzo conjunto del sector público y privado para superar estas barreras de entrada del mercado de scrubbers y GNL, que lograrían reducir las externalidades medioambientales de las emisiones sin restar competitividad al transporte marítimo. Creemos así, que los mismos organismos que aprobaron dicha ley deben ayudar al sector naviero a afrontar las inversiones en dichas tecnologías, así como a impulsar su investigación y promover la creación de una infraestructura portuaria adaptada a suministros de GNL y a descargas de vertidos procedentes de los equipos scrubber. Deberían además, prestar especial atención sobre las ayudas al sector de corta distancia para evitar que pierda competitividad frente a otros medios de transporte por el cumplimiento de esta normativa. Actualmente existen varios programas europeos de incentivos, como TEN-T o Marco Polo, pero no los consideramos suficientes. Por otro lado, la Organización Marítima Internacional debe confirmar cuanto antes si retrasa o no al 2025 la nueva bajada del nivel de azufre en combustibles. De esta manera, se eliminaría la gran incertidumbre temporal que actualmente tienen tanto navieros, como empresas petroleras y puertos para iniciar sus futuras inversiones y poder estudiar la viabilidad de cada alternativa de forma individual. ABSTRACT On 10 October 2008 the International Maritime Organization (IMO) signed an amendment to Annex VI of the MARPOL 73/78 convention establishing a gradual reduction in sulphur oxide (SOx) emissions from ships, and an additional reduction in nitrogen oxide (NOx) emissions and carbon dioxide (CO2) emissions from marine engines which cause environmental problems such as acid rain and the greenhouse effect. According to this regulation, from 1 January 2015, ships travelling in an Emission Control Area (ECA) must use fuels with a sulphur content of less than 0.1%. From 1 January 2020, or alternatively from 2025 if the IMO should decide to delay its introduction, all ships must use fuels with a sulphur content of less than 0.5%. As before, this content will be 0.1%S for voyages within ECAs. Meanwhile, the European Union has gone further than the IMO, and will apply the strictest limits of the MARPOL directives in the waters of its exclusive economic zone from 2020. To this end, Directive 2012/33/EU was issued on 21 November 2013 as an addendum to the 1999 Directive. These laws are intended to improve public health and the environment, benefiting society by reducing disease, particularly respiratory problems. The first question which arises is: what fuel do ships currently use, and what fuel will they have to use to comply with the Convention? Today, large international shipping vessels consume fuel oil with a sulphur level of 3.5%. Do fuel oils exist with a sulphur level of 0.5%S? As we conclude in Chapter 4, oil companies regard marine fuel oil as a by-product of refining Brent to produce their basket of products, as the demand for fuel oil is declining in comparison to other products, and the profit margin on the sale of other petroleum products is higher. Thus, oil companies are not interested in investing in their refineries to produce low-sulphur fuel oils, and if a company should decide to invest in producing a 0.5%S fuel oil, its price would have to be very similar to that of marine gas oil in order to recoup the investment. Therefore, the only fuel which presently complies with the new levels required by the IMO is marine gas oil, which was priced on average 307 USD/tonne higher than current fuel oils during 2014. This higher purchasing price for fuel will have a direct impact on the cost of maritime transport. The entry into force of the above directive presents a challenge for the entire maritime sector. There are various alternative approaches to this situation, with different technical, operational and financial implications. At present three options are the most widespread in the sector. The first option consists of “doing nothing” and simply switching from fuel oil to marine gas oil in large ships. The second option is installing a scrubber system, which would enable ships to continue consuming fuel oil, cleaning the combustion gases before they are released to the atmosphere. And finally, the third option is using Liquefied Natural Gas (LNG), which is priced lower than marine gas oil, as a fuel. However, there is still significant uncertainty on future variations in prices, the operation and maintenance of the new technologies, the investments required, the availability of port infrastructure and even future developments in the international regulations themselves. These uncertainties mean that none of these three alternatives has been unanimously accepted by the sector. In this Thesis, after discussing all the regulations applicable to the sector in Chapter 3, we investigate their consequences. In Chapter 4 we examine whether there are currently any marine fuels on the market which meet the new sulphur limits, and if not, how much new fuels would cost. In Chapter 5, based on the hypothesis that all ships will switch from fuel oil to marine gas oil to comply with the regulations, we calculate the increase in demand for marine gas oil this would lead to, and analyse the consequences this would have on marine gas oil production in the Mediterranean. We also calculate the economic impact such a cost increase would have on Spain's external sector. To do this, we also use the Automatic Identification System (AIS) system to analyse the data of every ship stopping in any Spanish port, in order to calculate the extra cost of using marine gas oil in maritime transport for all Spain's imports and exports. Finally, in Chapter 6, we examine and compare the other two alternatives to marine gas oil, scrubbers and LNG, and in Chapter 7 we analyse the viability of investing in these two technologies in order to comply with the regulations. In Chapter 5 we explain the many existing methods for calculating a ship's fuel consumption. We use a bottom-up calculation method, based on aggregating the activity and characteristics of each type of vessel. The result is based on the installed engine power of each ship, the engine load percentage and its specific consumption. To do this, we analyse the number of ships travelling in the Mediterranean in the course of one year, using the AIS, a marine traffic monitoring system, to take “snapshots” of marine traffic in the Mediterranean and report all ships at sea on random days throughout 2014. Finally, with the above data, we calculate the potential demand for marine gas oil in the Mediterranean. If nothing else is done and ships begin to use marine gas oil instead of fuel oil in order to comply with the regulation, the demand for marine gas oil in the Mediterranean will increase by 12.12 MTA (Millions Tonnes per Annum) from 2020. This means an increase of around 3.72 billion dollars a year in fuel costs, taking as reference the average price of marine fuels in 2014. Such an increase in demand in the Mediterranean would be equivalent to 43% of the total demand for diesel in Spain in 2013, including automotive diesel fuels, biodiesel and marine gas oils, and 3.2% of European consumption of middle distillates in 2014. Would the European market be able to supply enough to meet this greater demand for diesel? Europe has always had a surplus of gasoline and a deficit of middle distillates. In 2009, Europe had to import 4.8 MTA from North America and 22.1 MTA from Asia. Therefore, this increased demand on Europe's already limited capacity for refining middle distillates would lead to increased imports and higher prices, especially in the diesel market. The sector which would suffer the greatest impact of increased demand for marine gas oil would be Mediterranean cruise ships, which represent 30.4% of the fuel demand of the entire world cruise fleet, meaning their fuel costs would rise by 386 million USD per year. ROROs in the Mediterranean, which represent 23.6% of the demand of the world fleet of this type of ship, would see their fuel costs increase by 171 million USD a year. The greatest cost increase would be among container ships, with an increase on current costs of 1.168 billion USD per year. However, their consumption in the Mediterranean represents only 5.3% of worldwide fuel consumption by container ships. These figures raise the question of whether a cost increase of this size for RORO ships would lead to short-distance marine transport in general becoming less competitive compared to other transport options on certain routes. For example, some of the goods that ships now carry could switch to road transport, with the undesirable effects on the environment and on operations that this would produce. In the particular case of Spain, the extra cost of switching to marine gas oil in all ships stopping at any Spanish port in 2013 would be 1.717 billion EUR per year, as we demonstrate in the last part of Chapter 5. For this calculation, we used the AIS system to analyse all ships which stopped at any Spanish port, classifying them by distance travelled, type of ship and engine power. This rising cost of marine transport would be passed on to the Spanish external sector, increasing the cost of imports and exports by sea in a country which relies heavily on maritime transport, which accounts for 75.61% of Spain's total imports and 53.64% of its total exports. The three industries which would be worst affected are those with goods of lower value relative to transport costs. The increased costs over the total value of each good would be 2.94% for wood and cork, 2.14% for mineral products and 1.93% for manufactured stone, cement, ceramic and glass products. Goods entering via the two Spanish archipelagos, the Canary Islands and the Balearic Islands, would suffer the greatest impact from the extra cost of marine transport, as these ports are further away from other major ports and thus the distance travelled is greater. However, this is not the only option for compliance with the new regulations. From our readings in Chapter 6 we conclude that scrubbers and LNG propulsion would enable ships to use cheaper fuels than marine gas oil, in exchange for investing in these technologies. Would the savings gained by these new technologies be enough to justify the investment? To answer this question, in Chapter 7 we compare the three alternatives and calculate both the cost of investment and the operating costs associated with scrubbers or LNG propulsion for a selection of 53 categories of ships. Investing in scrubbers is more advisable for large ships with no fixed runs. However, for smaller ships with regular runs to ports with good LNG supply infrastructure, investing in LNG propulsion would be the best choice. In the case of total transit time within an ECA and the pricing scenario seen in 2014, the best payback periods on investments in scrubbers are for large cruise ships (100,000 gross tonnage), which would recoup their investment in 0.62 years; large container ships, with a 0.64 year payback period for those over 8,000 TEUs and 0.71 years for the 5,000-8,000 TEU category; and finally, large oil tankers over 200,000 deadweight tonnage, which would recoup their investment in 0.82 years. However, investing in scrubbers would have a longer payback period for smaller ships, up to 5 years or more for oil tankers and chemical tankers under 5,000 deadweight tonnage. In the case of LNG propulsion, a possible investment is more favourable and the payback period is shorter for smaller ship classes, such as ferries, cruise ships and ROROs. We now take the case of a ship transporting clean products, already built, with a deadweight tonnage of 38,500, and consider the viability of investing in installing a scrubber or changing to LNG propulsion, starting in 2015. The two variables with the greatest impact on the advisability of the investment are how long the ship is at sea within emission control areas (ECA) and the future price scenario of MGO, HSFO and LNG. For this analysis, we studied each investment, calculating a battery of merit conditions such as the payback period, IRR, NPV and variations in the investors' liquid assets. We then calculated the minimum boundary conditions to ensure the investment was not only acceptable but advisable for the investor shipowner. Thus, for the average price differential of 264.35 USD/tonne between HSFO and MGO during 2014, investors' return on investment (IRR) in scrubbers would be the same as the required opportunity cost of 9.6%, for values of over 56% ship transit time in ECAs. For the case of investing in LNG and the average price differential between MGO and LNG of 353.8 USD/tonne FOE in 2014, the ship must spend 64.8% of its time in ECAs for the investment to be advisable. For an estimated 60% of time in an ECA, the internal rate of return (IRR) for investors equals the required opportunity cost of 9.6%, based on a price difference of 244.73 USD/tonne between the two alternative fuels, marine gas oil (MGO) and fuel oil (HSFO). An investment in LNG propulsion would require a price differential between MGO and LNG of 382.3 USD/tonne FOE. Thus, for a 38,500 DWT ship carrying clean products, investing in retrofitting to install a scrubber is more advisable than converting to LNG, with an internal rate of return (IRR) for investors of 12.77%, compared to 6.81% for investing in LNG. Both calculations were based on a ship which spends 60% of its time at sea in an ECA and a scenario of average 2014 prices. However, for newly-built ships, investments in either of these technologies from 2025 would be advisable. Here, the shipowner must pay particular attention to the specific characteristics of their ship, the type of operation, and the infrastructure for supplying fuel and handling discharges in the ports where it will usually operate. Thus, while the consequences of switching to marine gas oil in order to comply with the MARPOL regulations are certainly alarming, there are alternatives to marine gas oil, with smaller increases in the costs of maritime transport, while maintaining the benefits to society this law is intended to provide. Indeed, as we have demonstrated, the options which appear most favourable from a financial viewpoint are conversion to LNG for small ships and regular runs (cruise ships, ferries, ROROs), and installing scrubbers for large ships. Unfortunately, however, these investments are not being made, due to the high uncertainty associated with these two markets, which increases business risk, both for shipowners and for the providers of these new technologies. This means we are seeing considerable reluctance regarding these two options among the private sector. This high level of risk can be lowered only by encouraging joint efforts by the public and private sectors to overcome these barriers to entry into the market for scrubbers and LNG, which could reduce the environmental externalities of emissions without affecting the competitiveness of marine transport. Our opinion is that the same bodies which approved this law must help the shipping industry invest in these technologies, drive research on them, and promote the creation of a port infrastructure which is adapted to supply LNG and handle the discharges from scrubber systems. At present there are several European incentive programmes, such as TEN-T and Marco Polo, but we do not consider these to be sufficient. For its part, the International Maritime Organization should confirm as soon as possible whether the new lower sulphur levels in fuels will be postponed until 2025. This would eliminate the great uncertainty among shipowners, oil companies and ports regarding the timeline for beginning their future investments and for studying their viability.

High-Pressure Methane Storage in Porous Materials: Are Carbon Materials in the Pole Position?

Natural gas storage on porous materials (ANG) is a promising alternative to conventional on-board compressed (CNG) or liquefied natural gas (LNG). To date, Metal–organic framework (MOF) materials have apparently been the only system published in the literature that is able to reach the new Department of Energy (DOE) value of 263 cm3 (STP: 273.15 K, 1 atm)/cm3; however, this value was obtained by using the ideal single-crystal density to calculate the volumetric capacity. Here, we prove experimentally, and for the first time, that properly designed activated carbon materials can really achieve the new DOE value while avoiding the additional drawback usually associated with MOF materials (i.e., the low mechanical stability under pressure (conforming), which is required for any practical application).

Retrofit of heat exchanger networks with pressure recovery of process streams at sub-ambient conditions

This paper presents a new mathematical programming model for the retrofit of heat exchanger networks (HENs), wherein the pressure recovery of process streams is conducted to enhance heat integration. Particularly applied to cryogenic processes, HENs retrofit with combined heat and work integration is mainly aimed at reducing the use of expensive cold services. The proposed multi-stage superstructure allows the increment of the existing heat transfer area, as well as the use of new equipment for both heat exchange and pressure manipulation. The pressure recovery of streams is carried out simultaneously with the HEN design, such that the process conditions (streams pressure and temperature) are variables of optimization. The mathematical model is formulated using generalized disjunctive programming (GDP) and is optimized via mixed-integer nonlinear programming (MINLP), through the minimization of the retrofit total annualized cost, considering the turbine and compressor coupling with a helper motor. Three case studies are performed to assess the accuracy of the developed approach, including a real industrial example related to liquefied natural gas (LNG) production. The results show that the pressure recovery of streams is efficient for energy savings and, consequently, for decreasing the HEN retrofit total cost especially in sub-ambient processes.