El objetivo es determinar si la sujeción de las bases en un concurso público de subasta, incentiva o desincentiva a los empresarios generadores de energía renovable y por otra parte hacer una propuesta de mejora; El Tipo de investigación usada en esta investigación es la Teoría fundamentada cualitativa, teniendo como unidad de análisis de la de Unidad de prácticas y un tipo de triangulación de expertos. Los resultados son primero; Que el D.L n.° 1002 y el D.S. 012-2011-EM, al momento de su aplicación, desincentiva la generación de energía renovable para microempresarios. / Tesis / Tesis

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The increasing environmental threat because of unsustainable pollution levelshave forced E.U. to take further actions by enforcing directives in the electricity sector. The E.U. directives, enforced in 2002, aim to increase the level of electricity produced from renewable sources. In order to fulfill their received national target of green electricity, the E.U. members have, in most cases, either adopted a feed-in tariff or tradable green certificates. Since it is in a government’sinterest to minimize expenditure while still maximizing incentives when adopting a policy, this study has evaluated the cost-efficiency differences of a FIT and aTGC from a governmental perspective. This has been done by using two different models, one which measures total governmental expenditures in the energy sector and one which only measures the subsidies in the energy sector. The findings suggest that a TGC can be up to 159% more cost-efficient than a FIT, depending on how it is measured. The total expenditure model could establish the costefficiency differences with a significance of 5%, while the subsidy model could not establish the differences on a satisfying significance level

Thesis advisor: Frank Gollop / Thesis advisor: James Dalton / There is a push for more electricity from renewable energy sources in the United States and around the world, but debate exists over the best policy to achieve this growth. Two common policies include renewable portfolio standards and feed-in tariffs. Using two Energy Information Administration forecasts from 2005 to 2030, this study examines the impacts of possible federal renewable portfolio standards in the United States through a benefit-costs analysis. Using the same benefit-cost analysis, a feed-in tariff policy in Germany and a unique renewables obligation in the United Kingdom are also examined and the results are compared. This study finds that only one of the four examined policies has a net benefit to society, the policy being a renewable portfolio standard requiring 25% of electricity supplied in the United States to be from renewable energy sources by the year 2025. The economic theory gives support to the superiority of renewable portfolio standards, although more study in needed on the dynamic efficiencies and other possible policy options. / Thesis (BA) — Boston College, 2009. / Submitted to: Boston College. College of Arts and Sciences. / Discipline: College Honors Program. / Discipline: Economics Honors Program. / Discipline: Economics.

A paradigm shift in distribution system design and planning is being led by the deregulation of the power industry and the increasing adoption of distributed generation (DG). Technology advances have made DG investments feasible by both local distribution companies (LDCs) and small power producers (SPPs). LDCs are interested in finding optimal long term plans that best serve their customers at the lowest cost. SPPs, as private entities, are concerned about maximizing their rates of return. Also keenly interested in distribution design and planning is the government, which, through an electricity regulator, strives to meet DG penetration and emissions reduction goals through policy implementations. This thesis first examines the distribution system planning problem from the LDC's perspective. An innovative hierarchical dynamic optimization model is proposed for the planning of distribution systems and the energy scheduling of units that is also capable of reconciling uncoordinated SPP investments in DG. The first stage of the two-stage framework consists of a siting-cum-period planning model that sets element sizing and commissioning dates. The second stage consists of a capacity-cum-production planning model that finalizes element capacities and energy import/export and production schedules. The proposed framework is demonstrated on a 32-bus radial distribution system. Four case studies encompassing different policy sets are also conducted, demonstrating that this model's usefulness also extends to predicting the impact of different energy policies on distribution system operation and economics. The analysis of different policy sets is further expanded upon through the proposal of a new mathematical model that approaches the distribution design problem from the regulator's perspective. Various case studies examining policies that may be used by the regulator to meet DG penetration and emissions goals, through DG investment, are constructed. A combination of feed-in-tariffs, CO$_2$ tax, and cap-and-trade mechanisms are among the policies studied. The results, in the context of Ontario, Canada and its Standard Offer Program, are discussed, with respect to achieving objectives in DG investment, participation by SPPs, consumer costs, and uncertainty in carbon market prices. In jurisdictions such as Ontario, the LDC cannot invest in its own DG capacity but must accommodate those of SPPs. With the successful implementation of DG investment incentives by the regulator, there is a potential for significant investments in DG by SPPs, which may exceed that of the LDCs ability to absorb. This thesis proposes a novel method that can be used by the regulator or LDC to fairly assess, coordinate, and approve multiple competing investments proposals while maintaining operational feasibility of the distribution system. This method uses a feedback between the LDC and SPPs to achieve maximum investor participation while adhering to the technical operational limits of the distribution system. The proposed scheme is successfully demonstrated on a 32-bus radial distribution system, where it is shown to increase SPP-DG investments and production, improve the system's voltage profile, and reduce losses.

A paradigm shift in distribution system design and planning is being led by the deregulation of the power industry and the increasing adoption of distributed generation (DG). Technology advances have made DG investments feasible by both local distribution companies (LDCs) and small power producers (SPPs). LDCs are interested in finding optimal long term plans that best serve their customers at the lowest cost. SPPs, as private entities, are concerned about maximizing their rates of return. Also keenly interested in distribution design and planning is the government, which, through an electricity regulator, strives to meet DG penetration and emissions reduction goals through policy implementations. This thesis first examines the distribution system planning problem from the LDC's perspective. An innovative hierarchical dynamic optimization model is proposed for the planning of distribution systems and the energy scheduling of units that is also capable of reconciling uncoordinated SPP investments in DG. The first stage of the two-stage framework consists of a siting-cum-period planning model that sets element sizing and commissioning dates. The second stage consists of a capacity-cum-production planning model that finalizes element capacities and energy import/export and production schedules. The proposed framework is demonstrated on a 32-bus radial distribution system. Four case studies encompassing different policy sets are also conducted, demonstrating that this model's usefulness also extends to predicting the impact of different energy policies on distribution system operation and economics. The analysis of different policy sets is further expanded upon through the proposal of a new mathematical model that approaches the distribution design problem from the regulator's perspective. Various case studies examining policies that may be used by the regulator to meet DG penetration and emissions goals, through DG investment, are constructed. A combination of feed-in-tariffs, CO$_2$ tax, and cap-and-trade mechanisms are among the policies studied. The results, in the context of Ontario, Canada and its Standard Offer Program, are discussed, with respect to achieving objectives in DG investment, participation by SPPs, consumer costs, and uncertainty in carbon market prices. In jurisdictions such as Ontario, the LDC cannot invest in its own DG capacity but must accommodate those of SPPs. With the successful implementation of DG investment incentives by the regulator, there is a potential for significant investments in DG by SPPs, which may exceed that of the LDCs ability to absorb. This thesis proposes a novel method that can be used by the regulator or LDC to fairly assess, coordinate, and approve multiple competing investments proposals while maintaining operational feasibility of the distribution system. This method uses a feedback between the LDC and SPPs to achieve maximum investor participation while adhering to the technical operational limits of the distribution system. The proposed scheme is successfully demonstrated on a 32-bus radial distribution system, where it is shown to increase SPP-DG investments and production, improve the system's voltage profile, and reduce losses.

Determining which countries are the most financially attractive for businesses to build wind projects is a matter of serious discussion that lacks succinct commentary. To fill this void this paper employs an empirical study of the wind subsidy support systems used by Germany, France, Spain and Sweden. This paper is based on the premise that businesses prefer to build where they can find the highest overall remuneration for their production; recognizing also the need for stability in those payments and businesses’ strong preference for larger early returns on their investments. The paper also analyzes the results and gives recommendations on possible improvements to each country’s system and where businesses should invest.In order to reach their 20-20-20 E.U. goals (European Commission, 2010), countries are encouraging the creation of new green energy projects, and this encouragement is frequently in the form of subsidies. The subsidy types used by the countries reviewed are feed-in tariffs, premiums and a certificate quota system. Each country’s support history is detailed along with the criteria of their respective systems.The countries systems are then compared using actual income and production data for four criteria at three different production levels – 100 percent, 75 percent and 150 percent of actual – and at two different lengths of time, 7 and 20 years. The first criteria of the comparison is total income, the second for variability of payments, the third for timing of payments and the final is the stability of the system itself.The results of this research show that the German and French systems are superior at all levels for their low variability in payment prices and in making larger payments to businesses earlier. They are also generally superior at lower and actual production levels for total income amounts. However, the Spanish options are superior at high levels of production for income and have middling variability levels. The Swedish system generally has the highest levels of variability for the lowest levels of income. Only the Spanish system is considered to be unstable in its political support of subsidies. Based upon the preceding findings are given to each country to improve their relative weaknesses. Also recommendations are given to businesses based upon the quality of the locations wind resources.

Concerns over climate change impacts, goals to increase environmental sustainability, and questions about the reliability of fuel supply have led several countries to pursue the goal of increasing the share of renewable energy sources in their electricity grid. Portugal is one of the leading countries for wind electricity generation. Wind diffusion in Portugal started in the early 2000’s and in 2013 wind electricity generation accounted for more than 24% (REN 2013b). The large share of wind in Portuguese electricity production is a consequence of European Union (E.U.) mandates and national policies, mainly feed-in tariffs. Discussions on the appropriate policy design and level of incentive to promote renewable energy adoption and meet further renewable capacity goals are ongoing in Portugal, namely in what concerns the level and duration of feed-in tariffs that should be provided to independent power producers. This, in turn, raises the question of whether the past feed-in tariff levels were well designed to achieve the goals of a larger penetration of renewables in the Portuguese grid. The policies to induce wind adoption have led to a growth in wind installed capacity and share of electricity generated by wind in Portugal from less than 1% in 2000 to approximately 24% in 2013, but questions arise on their cost-effectiveness and whether alternative policy designs would have led to the same goal. vi The Portuguese wind feed-in tariffs are a guaranteed incentive which has varied between $85- $180/MWh over the last 20 years (ERSE 2011), and remained approximately constant since 2001 at $101/MWh. They are currently guaranteed for 20 years of production or 44GWh of electricity generation per MW installed (Diário da República 2013) - the longest period among countries with high wind electricity share. They do not incorporate any digression rate besides inflation, and are guaranteed for every unit of electricity fed to the grid. There are no power plants that have already been decommissioned despite being in operation for more than 20 years, favoring from new, detailed and hard-to-follow agreements in the legislation. All wind parks that are currently in operation have received feed-in tariffs since they connected to the grid, and are expected to keep receiving them at least until December 2019, and up to December 2036 - depending on year of connection and agreement under the most recent legislation (Diário da República 2013). The 2020 renewable energy goals in Portugal include having 6.8 GW of installed wind capacity, which implies the connection of 2 GW in the next years. If no further grid investments are made and wind capacity increases up to 100 MW to the connection point that we analyze, total annual electricity spill is likely to range the 20% to 40%. If the connection grid policy is designed to allow for wind spill, already ‘occupied’ connection points will be available to new entrants, lowering the total investment costs for new wind parks and increasing their profitability. This thesis is divided in three main parts: a first introductory section, a retrospective study of wind power in Portugal and a prospective analysis of the Portuguese wind power sector. The introductory section is a brief overview of the global renewable status, described in Chapter 1. Chapter 2 and Chapter 3 compile a retrospective study of wind power and the policies that have incentivized wind diffusion. We include in the discussion some references to the future wind vii power goals, but the results and policy recommendations are directed towards the existing connected wind power capacity. Chapter 2 is a qualitative piece that describes in detail the motivation behind the Portuguese wind power diffusion, the policy changes over the last 20 years and the mechanics of the remuneration mechanism, i.e. the feed-in tariff formula variables and the actors of the wind power sector. We compare the Portuguese feed-in tariff with other European feed-in tariff designs and conclude that the incentive is one of the highest in Europe, contributing to the current Portuguese electricity system deficit of about $2 billion. If feed-in tariffs keep being fixed and do not incorporate any market variation, and renewables are prioritized to meet electricity demand, feed-in tariff net support per unit of electricity might be higher when the wind blows the most because moments with high penetration of renewable power might be correlated with low market prices. We find that wind power penetration is correlated with net exports to Spain. This might result in a net cost to Portugal and a subsidy to Spanish electricity consumers per unit of electricity traded. In total terms, the resulting subsidy is higher when the wind resource is larger as well, as the total amount of electricity that is exported increases. In Chapter 3 we estimate the profits of wind power producers connected in Portugal between 1992 and 2010, and we recommend specific policy reforms that would lower spending in the form of wind feed-in tariffs. In particular, we assess four scenarios to decrease the level and/or period of the tariffs. We find that under the 2005 legislation - in which feed-in tariffs are granted for 15 years, all existing wind parks have positive NPVs varying between $0 and $12/MWh, when considering a 20-year lifetime. In fact, most of existing wind parks can stop receiving the feed-in tariff now (July 2014), and instead participate directly in the Iberian electricity market and still be profitable. Moreover, under the 2013 feed-in tariff reform that aims at decreasing the viii electricity system deficit, total spending will increase and wind parks will have larger profits than under the 2005 legislation. The motivation of keeping a high feed-in tariff comes from the need of liquidity that wind producers can provide immediately to the electricity system, which is required at this moment to comply with the E.U. economic agreements signed during the recession. Nevertheless, the environmental and energy dependency benefits of the Portuguese wind sector could have been achieved with as much as 25% less spending. Later on, we move to analyze future wind power additions. Chapter 4 compiles a prospective analysis of the wind power sector in Portugal. We focus on new wind parks that will connect to critical lines of the distribution grid in two regions of the country, as part of the national 2030 wind power goals. In particular, we assess the implications of a 100% guaranteed availability of grid power capacity. We find that from the investor perspective, it is more profitable to bear some risk of wind power curtailment, because of the avoided costs that would otherwise be incurred to upgrade the grid. We also find that since there is ample room in the distribution lines to connect more wind parks, very few grid upgrades can allow to highly increase the distributed wind capacity with a low risk of wind curtailment. Moreover, even in scenarios with ‘high curtailment’ of 5% to 20%, projects are profitable. Thus, the Portuguese government should consider a policy where the guaranteed feed-in would be removed, and further assess the possibility of limiting profitability of the existing and new wind projects by introducing curtailment. This work compiles two perspectives: first, a temporal perspective, in which past and future assessments of wind power diffusion are described. Second, a perspective on policy characterization, in which we present an assessment of two characteristics in the feed-in tariff design: the level/period of the tariff and the conditionality of prioritizing wind power over fossilix fuel resources with absence of risk of wind power curtailment. The level and period-related policy recommendations are considered for the existing wind parks, and are addressed mainly in Chapter 3. Considerations about grid capacity and introducing a risk of wind power curtailment are considered for subsequent wind power capacity additions, and are mainly considered in Chapter 4. In addition, notice that Chapter 3 focuses on avoiding excessive profitability of wind power parks while in Chapter 4 we analyze wind and grid capacity additions under the perspective of wind investors. Nevertheless, as we also find in Chapter 4 that profits are excessive, we do make recommendations that limit wind investor’s revenue. Portuguese decision maker should give serious consideration to revisions to the Portuguese feed-in tariff policy design. Most of the existing Portuguese wind parks to not need a feed-in tariff to be profitable. A value associated with the risk of wind power curtailment for subsequent additions should be incorporated in future policy design. We expect that this work will contribute to the Portuguese renewable policy in particular in light of Portugal’s 2020 and 2030 wind power goals.

Driven by climate change and the impending depletion of fossil fuels, the UK Government has set the great challenge to UK builders to produce zero-carbon homes as of 2016. Due to a lack of experience the merits of integrating onsite micro renewable energy systems were largely unknown. Barratt Development PLC, UK's largest builder, set out in 2006 to investigate how these new building regulations can best be tackled. The key points to be investigated are: how much CO2 can be offset using renewable energy systems in standard homes and at what cost; how reliable are these systems; and how can their performance be improved? At the EcoSmart village several systems were tested under realistic conditions, including PV, Solar Thermal, Micro Wind Turbines, GSHPs and microCHP. The systems were tested over a 12-month period, integrated into standard Barratt homes, and running under near real-life conditions. Data was recorded from the test-site, including heat and electrical energy generation and consumption, temperature data and weather data. This data was used to establish the theoretical performance of the systems at the test site, and by doing so simple methods were found and tested that can be used by builders or architects to gain a better understanding of the expected performance of a particular system. The estimated energy generation was then compared to the measured performance. Detailed modelling and analysis of observations was carried out to provide explanations for any discrepancies, and based on this general recommendations were made on how the performance of the systems could be improved. Given the commercial drivers behind carrying out this research project, a high emphasis was given to financial implications of installing the systems. For this purpose payback periods and life-time savings were estimated, based on measured performance and other influences such as feed-in tariffs. This was also done for embodied energy and embodied carbon, as this will ultimately determine how the systems can help to fulfil the purpose of Government legislation, which is to reduce the carbon footprint of the UK domestic sector.

En mai 2009, l’Ontario a adopté la Loi sur l’énergie verte et devint ainsi la première juridiction en Amérique du Nord à promouvoir l’énergie renouvelable par le biais de tarifs de rachat garantis. En novembre 2010, dans son Plan énergétique à long terme, la province s’est engagée à déployer 10,700 MW en capacité de production d’énergie renouvelable non-hydroélectrique par 2018. Il s’agit de la cible de déploiement la plus élevée dans ce secteur au Canada. Les infrastructures de production et de distribution d’électricité comprennent des coûts d’installation élevés, une faible rotation des investissements et de longs cycles de vie, facteurs qui servent habituellement à ancrer les politiques énergétiques dans une dynamique de dépendance au sentier. Depuis le début des années 2000, cependant, l’Ontario a commencé à diverger de sa traditionnelle dépendance aux grandes centrales hydroélectriques, aux centrales à charbon et aux centrales nucléaires par une série de petits changements graduels qui feront grimper la part d’énergie renouvelable dans le mix énergétique provincial à 15% par 2018. Le but de ce mémoire est d’élucider le mécanisme de causalité qui a sous-tendu l’évolution graduelle de l’Ontario vers la promotion de l’énergie renouvelable par le biais de tarifs de rachat garantis et d’une cible de déploiement élevée. Ce mémoire applique la théorie du changement institutionnel graduel de Mahoney et Thelen au cas du développement de politiques d’énergie renouvelable en Ontario afin de mieux comprendre les causes, les modes et les effets du changement institutionnel. Nous découvrons que le contexte canadien de la politique énergétique favorise la sédimentation institutionnelle, c’est-à-dire un mode changement caractérisé par de petits gains favorisant l’énergie renouvelable. Ces gains s’accumulent pourtant en transformation politique importante. En Ontario, la mise sur pied d’une vaste coalition pour l’énergie renouvelable fut à l’origine du changement. Les premiers revendicateurs de politiques favorisant l’énergie renouvelable – les environnementalistes et les premières entreprises d’approvisionnement et de service en technologies d’énergie renouvelable – ont dû mettre sur pied un vaste réseau d’appui, représentant la quasi-totalité de la société ontarienne, pour faire avancer leur cause. Ce réseau a fait pression sur le gouvernement provincial et, en tant que front commun, a revendiqué l’énergie renouvelable non seulement comme solution aux changements climatiques, mais aussi comme solution à maints autres défis pressants de santé publique et de développement économique. La convergence favorable d’un nombre de facteurs contextuels a certes contribué à la réussite du réseau ontarien pour l’énergie renouvelable. Cependant, le fait que ce réseau ait trouvé des alliés au sein de l’exécutif du gouvernement provincial s’est révélé d’importance cruciale quant à l’obtention de politiques favorisant l’énergie renouvelable. Au Canada, les gouvernements provinciaux détiennent l’ultime droit de veto sur la politique énergétique. Ce n’est qu’en trouvant des alliés aux plus hauts échelons du gouvernement que le réseau ontarien pour l’énergie renouvelable a pu réussir. / In May 2009, Ontario adopted the Green Energy and Green Economy Act and became the first jurisdiction in North America to promote renewable energy through advanced feed-in tariffs. In November 2010, in its Long-Term Energy Plan, the province pledged to deploy 10,700 MW of non-hydroelectric renewable energy capacity by 2018, the highest such target in Canada. Electricity production and distribution infrastructure is characterized by high setup costs, low capital stock turnover and long life spans, factors that traditionally entrench energy policy in path-dependent trajectories. Since the early 2000’s, however, Ontario has diverged from its historic reliance on large hydro, coal and nuclear through a series of gradual policy shifts set to expand renewable energy’s share in the overall supply mix to 15% by 2018. The purpose of this thesis is to uncover the causal mechanism behind Ontario`s gradual shift toward the promotion of renewable energy through advanced feed-in tariffs, accompanied by high deployment targets. The thesis applies Mahoney & Thelen’s theory of gradual institutional change to the case of renewable energy policy development in Ontario, providing new insight into the causes, modes and effects of institutional change. The thesis finds that the Canadian energy policy context favors a layering pattern of change, characterized by small, yet cumulative, renewable energy policy gains. The driving force of this process involves coalition building. To achieve renewable energy policy gains, Ontario`s first renewable energy proponents, mostly environmental groups and early renewable energy supply and service firms, had to build a wide-ranging, multi-stakeholder network of allies and lobby government from a unified front, presenting renewable energy as a solution not only to climate change but a combination of other immediately pressing public health and economic challenges. Elements of timing greatly aided the renewable energy network’s campaign. Ultimately, however, the thesis finds that, given provincial governments` ultimate veto power over energy policy, finding allies in the top echelons of government was most crucial to the renewable energy network`s success.