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Sierra Leone is an electricity-poor country with one of the lowest electricity consumption per capita rates across sub-Saharan Africa. Yet, with ambitious targets to transform and stimulate its economy in the coming decades, energy demand forecasting becomes an integral component of successful energy planning. Through applying the MAED-D (version 2.0.0) demand software, this research study aims to generate Sierra Leone's electricity demand forecasts from 2023 to 2050. Three novel scenarios (baseline-, high-, and low-demand) are developed based on socio-economic and technical parameters. The baseline scenario considers the current electricity sector as business-as-usual; the high-demand scenario examines an ambitious development future with increased economic diversification and mechanisation, and the low-demand scenario examines more reserved future development. The modelled scenario results project an increase in electricity demand ranging from 7.32 PJ and 12.23 PJ to 5.53 PJ for the baseline-, high-, and low-demand scenarios, respectively, by 2050. This paper provides a base set of best-available data needed to produce an electricity demand model for Sierra Leone which can be used as a capacity-building tool for in-country energy planning alongside further integration into data modelling pipelines. [ABSTRACT FROM AUTHOR]

The increased electricity demand amidst inadequate electricity generation in South Africa has plunged the country into frequent power outages and load shedding. However, the country still has the lowest electricity transmission and distribution losses in sub-Saharan Africa. Despite low losses, there is still an opportunity to reduce losses further and reduce power outages and load shedding. This study examines the determinants of electricity transmission and distribution losses in South Africa. The results will inform policymakers on avoiding higher electricity transmission losses to alleviate the current electricity shortfall. Using the time-series data from 1971–2020 and the autoregressive distributed-lag (ARDL) bounds testing approach to cointegration, the study confirmed a long-run relationship between electricity transmission, distribution losses, and income, price, investment, political regime, and economic integration. Regression analysis from the ARDL methods revealed that investments, political administration, and economic integration positively influence electricity transmission and distribution losses. At the same time, income reduces electricity transmission and distribution losses in the long run. However, income, price, and economic integration minimize electricity transmission losses in the short run while the remaining variables maintained their positive effects. The implication is that without proper checks in place, an expansion in South Africa's economic integration, investment, and democracy may negatively affect the electricity sector of the country through an increase in electric power losses, while higher income will help the industry via lower electric power losses. The paper, among other things, recommends building a robust economy to ensure lower levels of electricity transmission and distribution losses. [ABSTRACT FROM AUTHOR]

Solar Home Systems (SHSs) have become a popular means of electrification for millions of people living in rural regions of developing countries with no access to the national grid. As the electrical demand grows, however, there are economic and technical challenges that exist in scaling-up SHSs. At present, up to 70% of the energy generated by SHSs is surplus and effectively goes to waste, due to high solar resource peaks aligning with low demand periods and restricted storage capacity. Interconnecting existing SHSs to form 'DC village' microgrids, comprised of distributed photovoltaic generation and battery storage, enables communities to unlock this surplus energy for more productive uses. This may be to service small businesses with higher energy demand than can be provided by a typical SHS (e.g. to shops or barbers), or to allow domestic consumers to connect higher powered appliances. Meanwhile, people without their own SHS can also connect to the system introducing basic lighting and phone charging for lower capital costs than those with SHSs. This paper presents the results of a field trial conducted in Murambi Village, in the Northern Province of Rwanda, which involved the interconnection of seven households with their own SHS and one with no previous access to electricity. An innovative smart controller developed by the authors to facilitate SHS interconnection was deployed across this village. Using a mix of survey and focus group methods, the paper examines how people experienced the interconnected SHS system; the opportunities and benefits (social, economic) this presented; how the system enabled the use of new (higher power) appliances and new practices by trialing a novel shared refrigeration unit; and the potential of SHS interconnection in the broader context of the 'bottom-up electrification' paradigm. • Introduction of Interconnected Solar Home Systems Networks in Sub-Saharan Africa. • Stimulating productive use of electricity in the Developing World. • Engaging highly distributed prosumers to form local energy networks. • Increasing penetration of high-power appliances in rural Sub-Saharan Africa. [ABSTRACT FROM AUTHOR]

The article examines the dynamics of access to electricity in two West African cities: Cotonou (Benin) and Ibadan (Nigeria). Due to poor supply from the grid, households are developing varied ways of accessing electricity, based on different socio-technical dispositifs. In this paper we first demonstrate that access to electricity is based on co-production processes that must be approached from a multi-scale perspective (from the household to the urban scale). We then argue that particular attention to the socio-technical and spatial dimension of co-production arrangements makes it possible to interpret urban electrical configurations and their evolution. We thus show that co-production processes, relying on many actors and technologies to meet a growing and diversified demand for electricity in cities, support an ongoing movement of extension-hybridisation of electricity configurations on an urban scale, thus offering an interesting perspective on power changes in sub-Saharan Africa. [ABSTRACT FROM AUTHOR]

Mini-grids are discussed as a cost-effective and sustainable solution to provide electricity to populations lacking access, of which the majority reside in sub-Saharan Africa. Projects struggle to be fiscally solvent, however, in part because electricity demand from rural households is low relative to installed mini-grid generation and distribution capacity, making it difficult to recoup investment costs. This paper explores how productive uses of electricity may increase electricity demand and evaluates impacts of increased electrical load to the technical and economic metrics of mini-grid projects. A full cashflow analysis is completed to evaluate business model efficacy for mini-grid developers and investors for a case study of a township in Sierra Leone. Productive uses of electricity are shown to have minimal improvement to the financial viability of residential mini-grid projects, and subsidies are required to reach financial metrics suitable to attract private investment. Of the productive uses investigated, year-round loads had the most positive impact to payback periods. Seasonal loads offer only small improvements to payback period and internal rate of return because they require extra generation assets to meet peak demand in the high season that are left idle or heavily under-loaded during the low season. Overall, the study finds the most effective way to improve financial outcomes through productive uses is to increase the mini-grid load factor with productive uses of electricity that operate year-round. • PUE interventions that increase mini-grid load factor improve project financials. • Higher load factors better utilized hybrid systems with generator, solar, storage. • PUE type and load profile significantly affects mini-grid design and financials. • Constant-load PUE types improved financials over seasonal loads. • Seasonal PUEs increase capital costs that go largely unused during the off-season. [ABSTRACT FROM AUTHOR]

Over 17% of the world's population lack access to electricity, the majority being in rural areas of sub-Saharan Africa and South Asia. Microgrid technologies are a promising solution towards rural and remote area electrification; however, ever-increasing electricity demand remains a big challenge leading to pronounced power outages. Demand-side management is an indispensable tool towards addressing the challenges. This paper employs a mathematical model based on incentives and time-of-use rates to simulate daily power usage pattern of residential customers using data collected from an isolated village Ngurdoto solar microgrid, Arusha, Tanzania. Customer responsiveness on the increase in price was evaluated based on the concept of price elasticity of demand. Using two demand response strategies, namely, load shifting (LS) and scheduled load reduction (SLR), the results reveal that LS can achieve up to 4.87% energy-saving, 19.23% cost-saving, and about 31% and 19% peak reduction and power factor improvement, respectively. SLR method resulted in about 19% energy-saving, 49% cost-saving, and 24% power factor improvement. Thus, the results presented in this study may lead to a more efficient and stable system than the current state in developing countries' utility. [ABSTRACT FROM AUTHOR]

Sub-Saharan Africa's low access to electricity and high vulnerability to climate change can be anticipated to constrain the region's future human and economic development prospects. The need for energy conservation, especially electricity, is of crucial importance as it is an economic solution to the problem of energy shortage and atmospheric carbon reduction. The role of Artificial intelligence (AI) has also been displayed by researchers in the promotion of energy management. Most of the past literature in the line of energy management strategies proposed various energy management models based on smart grid and smart meter technology, demand side management, home energy management schemes and management based on AI. This paper proposes an AI-based energy management for households in Nigeria. Genetic algorithm was used on smart meter-like data to optimize the energy consumption of households for 24 hours on a weekday and weekend. To achieve this aim, we determine the typical load profile of a mini-grid setting (for household and commercial load profile), develop a simulation of smart meter-like data and develop an energy management system to optimize electricity consumption during a weekday and weekend in a household. We corroborate our theoretical model with numerical results showing the energy (and consumption) saved during these periods. The algorithm will assist electricity consumers in rural communities to effectively manage their usage by avoiding wastage and the unnecessary payment for energy waste. [ABSTRACT FROM AUTHOR]

Despite the importance of cost of capital and expected returns from investing on renewable electricity generation in Africa on one hand and the implications of such investments on economic, social and environmental factors on the other. These concepts are not well understood by non-finance and finance actors respectively. Studies that analyze renewable energy-growth nexus at regional and global level are lacking. Instead, existing studies emphasize on individual countries or panel of countries. The paper undertakes comparisons of costs and returns of selected renewable energy technologies in Africa and presents estimates of its impact on Africa's economic growth between 1990 and 2014. Even with abundant renewable resources and well performing technologies measured using levelized cost of electricity and expected internal rate of return, investment on renewable electricity generation is quite low. Findings from Autoregressive Distributed Lag approach and cointegration established a long run relationship among hydro power generation, carbon emissions and electricity consumption. Error Correction Model results suggest that investment in renewable generations excluding hydro power generation is boosted by economic growth, so long as development of such renewables corresponds with lesser carbon emissions. To accelerate renewable development, SSA countries will need to deploy initiatives that enhances national economic growth. [ABSTRACT FROM AUTHOR]

Off-grid photovoltaic systems have been proposed as a panacea for economies with poor electricity access, offering a lower-cost "leapfrog" over grid infrastructure used in higher-income economies. Previous research examining pathways to electricity access may understate the role of off-grid photovoltaics as it has not considered reliability and carbon pricing impacts. We perform high-resolution geospatial analysis on universal household electricity access in Sub-Saharan Africa that includes these aspects via least-cost pathways at different electricity demand levels. Under our "Tier 3" demand reference scenario, 24% of our study's 470 million people obtaining electricity access by 2030 do so via off-grid photovoltaics. Including a unit cost for unmet demand of 0.50 US dollars ($)/kWh, to penalise poor system reliability increases this share to 41%. Applying a carbon price (around $80/tonne CO2-eq) increases it to 38%. Our results indicate considerable diversity in the level of policy intervention needed between countries and suggest several regions where lower levels of policy intervention may be effective. This study investigates the role of off-grid solar in achieving SDG7 in Africa, focusing on understanding the impact of carbon pricing and supply reliability. It uses high-resolution spatial analysis and demand modelling to explore policy interventions for universal electricity access. [ABSTRACT FROM AUTHOR]

This study addresses the pressing issue of quality electricity access in remote regions, with a specific focus on Tumbatu Island in Tanzania. Most studies on quality improvement concentrate on low‐voltage distribution lines and leave high‐voltage (HV) transmission lines behind. It is essential to address quality issues in HV lines due to their critical role in electricity transmission and distribution infrastructure. The objective of the study is to improve the voltage profile on the island's HV transmission line by identifying the optimal hybrid energy system comprising solar PV, wind turbine, and battery technologies. The study begins by presenting the total power demand and consumption on Tumbatu Island, which are important factors in designing an efficient energy system. The findings reveal a power demand of 7173 kW and a consumption of 28540 kWh/day, with an average scaled value of 1507.9 and 6000 kWh/day. To achieve the desired voltage profile improvement, the research incorporates HOMER Pro software for simulating and analyzing various hybrid system configurations. Essential input parameters, such as costs, resources, technology components, and load, are considered in the simulation process. The software generates a ranked list of options based on the system's net present cost (NPC). The simulation results demonstrate that the integration of solar PV, wind turbine, and HV lines provides a substantial improvement in the voltage profile, increasing it from 29.6 to 31.23 kV during peak demand periods. This solution proves to be the most economically viable, with the lowest NPC of $4,003,851 and a relatively short payback period of 3.79 years. In addition, a sensitivity analysis is performed to identify the most influential parameter in the system's performance. Wind speed is found to have the greatest impact, emphasizing its significance in the design and operation of the hybrid energy system. The implementation of this optimal hybrid renewable energy system on Tumbatu Island will not only improve the voltage profile and meet the island's energy needs but also shall contribute to global efforts in reducing pollution and the cost of electricity to the Tumbatu Island population. Moreover, it addresses the current and future demands for clean energy, underlining its importance in achieving sustainable and accessible electricity in sub‐Saharan Africa and beyond. [ABSTRACT FROM AUTHOR]

Most sub-Saharan African electricity generation is through renewable energy sources. However, the pace of renewable expansion is slow, mirrored by the region's low per capita electric power consumption and electricity access. The study examines the determinants of renewable electricity generation adoption in sub-Saharan Africa (SSA) countries using content description and a panel ARDL analysis. Findings from this study show that hydroelectric power is the long-standing renewable electricity source in the region. The deployment of non-hydro renewable electricity sources is slow despite its vast potential. In most evaluated countries, renewable electricity targets are below actual realization. Also, policies are ineffective in driving renewable electricity adoption, as indicated by the negative relationship between renewable electricity generation and policy enactments in SSA. Foreign direct investment and financial development significantly negatively impact renewable electricity adoption, suggesting that both factors do not expand renewable electricity generation. Feasible strategies for increasing non-hydro renewable electricity use include activating renewable energy support mechanisms and their uptake. In addition, governments in SSA should strengthen their legal and institutional frameworks and encourage lessening bottlenecks and bureaucracies associated with renewable electricity investment. [ABSTRACT FROM AUTHOR]

Understanding the scale of energy poverty remains elusive. It is, however, a key metric in the global effort to eradicate poverty. The analysis presented in this paper provides insights into the true scale and impacts of unreliable electricity service provision. The paper introduces a simple and novel approach to quantifying the difference between electricity supply and demand, accounting for both met and unmet demand in Sub-Saharan Africa (SSA). To assess unmet demand, generator use, reduced utilization due to unreliable electricity service, unrealized demand from unelectrified households, and the effect of tariff reductions are considered. We find that at 2018 prices, SSA (excluding South Africa) on-grid power networks had annual unmet demand of 8.83 TWh for on-grid users and 42.9 TWh with the inclusion of the off-grid sector. With a 50% reduction in tariff by country, the on-grid power sector would face a 21.46 TWh of unmet demand in the region, rising to 55.53 TWh with the inclusion of off-grid. [ABSTRACT FROM AUTHOR]

The International Energy Agency has projected that the total energy demand for electricity in sub-Saharan Africa (SSA) is expected to rise by an average of 4% per year up to 2040. It implies that ~620 million people are living without electricity in SSA. Going with the 2030 vision of the United Nations that electricity should be accessible to all, it is important that new technology and methods are provided. In comparison to other nations worldwide, smart grid (SG) is an emerging technology in SSA. SG is an information technology-enhanced power grid, which provides a two-way communication network between energy producers and customers. Also, it includes renewable energy, smart meters, and smart devices that help to manage energy demands and reduce energy generation costs. However, SG is facing inherent difficulties, such as energy theft, lack of trust, security, and privacy issues. Therefore, this paper proposes a blockchain-based decentralized energy system (BDES) to accelerate rural and urban electrification by improving service delivery while minimizing the cost of generation and addressing historical antipathy and cybersecurity risk within SSA. Additionally, energy insufficiency and fixed pricing schemes may raise concerns in SG, such as the imbalance of order. The paper also introduces a blockchain-based energy trading system, which includes price negotiation and incentive mechanisms to address the imbalance of order. Moreover, existing models for energy planning do not consider the effect of fill rate (FR) and service level (SL). A blockchain levelized cost of energy (BLCOE) is proposed as the least-cost solution that measures the impact of energy reliability on generation cost using FR and SL. Simulation results are presented to show the performance of the proposed model and the least-cost option varies with relative energy generation cost of centralized, decentralized and BDES infrastructure. Case studies of Burkina Faso, Cote d'Ivoire, Gambia, Liberia, Mali, and Senegal illustrate situations that are more suitable for BDES. For other SSA countries, BDES can cost-effectively service a large population and regions. Additionally, BLCOE reduces energy costs by approximately 95% for battery and 75% for the solar modules. The future BLCOE varies across SSA on an average of about 0.049 $/kWh as compared to 0.15 $/kWh of an existing system in the literature. [ABSTRACT FROM AUTHOR]

Studies show the role of various electrification technologies in providing electricity access to households in Sub-Saharan Africa, with a focus on electricity demand for end-use services such as lighting, cooking, heating, cooling and other appliance use. The demand for productive use of electricity, which is important to enhance income generation opportunities and labour productivity, is usually not considered. Using the IMAGE-TIMER integrated assessment model framework, we present a methodology to project the impact of productive activities on the electricity system of the region. We show that growing productive activities increase household electricity demand by half, which has important consequences for determining the cost-optimal electrification technologies. We argue that planning of electricity systems should accommodate this increase in electricity demand for productive uses. In addition, while productive uses of electricity have a positive impact on the financial viability of electrification systems, they also increase the electricity sector investment requirements considerably. [ABSTRACT FROM AUTHOR]

• High-resolution map illustrates 16.8 TWh/year electricity demand for irrigation, refrigeration, incubation, and crop processing across Sub-Saharan Africa. • Irrigation pumping dominates end uses, with demand concentrated in semi-arid regions with high crop production. • Microgrid system sizing and costs compared for hundreds of off-grid sites across Kenya and Zambia, with and without inclusion of agricultural load. • Microgrid case study shows that serving agricultural end-uses along with community load has minimal impact on cost of energy. The use of advanced energy technologies for agricultural purposes—such as irrigation, refrigeration, crop processing, and egg incubation—has the potential to increase crop yield, reduce vulnerability to changing precipitation patterns, increase shelf life, strengthen income and employment opportunities in rural areas, and reduce emissions by displacing fossil fuel-based technologies. These productive uses of energy (PUE) in remote areas could potentially be powered by microgrids that additionally serve otherwise unelectrified communities, most of which are located in rural Sub-Saharan Africa. In this paper, we use high-resolution geospatial data to estimate the end-use electricity demand for a range of agricultural PUE across Sub-Saharan Africa, and we share these data in an open-access mapping tool. Next, we use REopt®, a techno-economic optimization model of energy systems, to determine the cost and system sizing implications of incorporating agricultural PUE into microgrid designs in Kenya and Zambia. We estimate the upper bound of agricultural PUE demand for irrigation, milling, shelling, refrigeration, and egg incubation across Sub-Saharan to be 16.8 TWh/yr. We find that incorporating local agricultural PUE into microgrid system designs increases the required system sizing while having minimal impact on the levelized cost of energy of these systems. Our analysis is the first to demonstrate the PUE potential in the agricultural sector at a 10x10-kilometer resolution across Sub-Saharan Africa and to show, at scale, how site-specific PUE can impact the cost and sizing of microgrids that are otherwise deployed to serve local household and community load. [ABSTRACT FROM AUTHOR]

Poverty and lack of access to electricity are highly correlated. In Sub-Saharan Africa, one of the poorest regions in the world, two in every three people have no access to electricity. This paper describes a purpose designed model to explore and project the development in the Sub-Saharan African electricity sector in Baseline and Universal access scenarios. The results provide insight into the role of different systems and technologies in providing access to electricity in the region and associated investment requirements. We project that Baseline developments do not lead to universal access to electricity, especially in Eastern Africa and the rural areas. The results show that central grid extension should be complemented with off-grid systems (mini-grid and stand-alone) to increase access in Sub-Saharan Africa. At the same time, the targeted level of consumption has large implications on the preferred electrification technology and associated investment requirements. For low levels of consumption, off-grid technologies are the most important technologies to increase access rate, while for high levels of consumption, extending the central grid is more economical. Total cumulative investment in the period 2010-2030 amount to 22 billion USD for low levels of consumption and exceed 2.5 trillion USD for high levels of consumption. [ABSTRACT FROM AUTHOR]

• Improving the performance of diesel generators gives economic and environmental benefits for hybrid microgrids planning. • Better interaction among diesel generators and renewable energy for rural electrification can be achieved using cost optimisation tools. • Including biofuel blends in a cost optimisation tool allows for assessing locally produced fuels for diesel substitution. • PM 2.5 and NO X emissions influence the biofuel selection to be used within hybrid microgrids. • Cost-benefit analysis helps to determine the best microgrid system configuration, considering financial and environmental aspects. Diesel generators (diesel gensets) are widely used within microgrid (MG) and off-grid systems for rural electrification, particularly in developing countries. The sizing and selection techniques during the MG planning stage are a key for maximising cost-effectiveness and minimising environmental impacts. This becomes more important for hybrid mini-grid systems when photovoltaic (PV) electricity generation and other renewable energies are included in the system as special attention is needed to limit the genset's output power, to keep it within the recommended operating range. This paper presents a cost optimisation model, centred on the generatoŕs performance, within diesel/PV/battery MGs, for minimising the MG's operating costs and environmental impact. The model considers fuel consumption equations adapted for castor oil-diesel (COD) blends and two major pollutant emissions (NOx and PM 2.5), which are not considered in other optimisation models. The optimisation was implemented for high, medium, and low electricity demand scenarios, with eight possible system configurations, for the Lindi Region of Tanzania as it belongs to one of the five countries with the lowest electricity access in sub-Saharan Africa (SSA). An economic assessment was done to compare the Levelized Cost of Energy (LCOE) of the system configurations. The impact of the fuel price and pollutant emission costs on the fuel selection was investigated using sensitivity analysis. The results confirmed that for specific electricity demand each scenario requires a unique set of diesel generators and the selection is affected by the PV share and the battery energy storage (BES) units included. The best LCOE for the high, medium, and low electricity demand scenarios were 0.43£/kWh, 0.42£/kWh, and 0.45£/kWh, respectively. The sensitivity analysis revealed that the pollutant emission costs have a significant impact on LCOE for the different fuel choices whereas the variation of fuel prices has a minimal effect unless the diesel price increased by 100%. [ABSTRACT FROM AUTHOR]

While recent years have seen the rapid growth of off-grid solar power, ten per cent of the world's population, the majority in sub-Saharan Africa, still lack access to electricity. Meanwhile, standalone solar home systems using pay as you go (PAYGO) mobile money have been proposed as a key solution to meeting the target of universal access to energy under Sustainable Development Goal 7. These systems are being deployed in various regions of the global South, including East Africa and to a lesser extent West Africa. I investigate how through PAYGO, off-grid solar electricity in sub-Saharan Africa is being transformed into a cash flow, a financial asset and a conduit for consumer debt. In so doing I analyse evolving relationships between some of the key actors and institutions involved in this process, including mobile banking platforms such as M-Pesa, 'next generation utilities' such as M-KOPA and BBOXX, and powerful mobile network operators such as Safaricom and MTN. Theoretically I conceptualise energy access as a new frontier of 'electricity capital', a developing field from political economy and energy geography, which is concerned with the way in which technological developments in the electricity sector are reconfiguring relationships between different institutions of the state, industry, finance, and users. [ABSTRACT FROM AUTHOR]

The focus of this paper is the design and implementation of solar PV deployment option, which is economical and easy to maintain for remote locations in less developed countries in Sub-Saharan Africa. The feasibility of stand-alone solar PV systems as a solution to the unstable electricity supply and as an alternative to the conventional resource, “diesel generators,” is presented. Moreover, a design of a system is carried out, such that the electrical demand and site meteorological data of a typical household in the capital, Banjul, is simulated. Likewise, the life cycle cost analysis to assess the economic viability of the system, along with the solar home performance, is also presented. Such system will be beneficial to the inhabitants of Gambia by ensuring savings in fuel costs and by reducing carbon emissions produced by generators. The selection of appropriate-sized components is crucial, as they affect the lifetime, reliability, and initial costs. The design presented in this study represents a solution for domestic houses to adopt the system according to the location and environment, in order to meet electricity demand. [ABSTRACT FROM AUTHOR]

Sub-Saharan Africa (SSA) ranks lowest globally in respect of energy access rates. The resulting high energy poverty impedes sustainable economic growth and aggravates the overall poverty which is prevalent in SSA countries. A better understanding of the relationship between financial development and energy consumption can contribute to enhancing sustainable development in SSA. The existing literature presents conflicting evidence regarding this relationship. Our objective is to investigate the symmetric and asymmetric relationships between financial development and energy consumption in SSA, using annual data from 1990 to 2016. The Autoregressive Distributed Lag (ARDL) panel estimator was employed to test for the linear relationship and symmetric effects of the long-run and short-run coefficients. The asymmetry was determined by decomposing financial development into positive and negative components, employing the non-linear ARDL (NARDL) method. The results reveal that a positive financial development shock is positively linked with energy consumption in the long-run implying that further financial development intensifies energy consumption. Results of the negative shock in financial development is positively linked with energy consumption in the long-run implying that the reduction in financial development could decrease energy consumption. [ABSTRACT FROM AUTHOR]

Accessibility to modern energy services is imperative in resolving numerous present-day global development issues which affect people's socio-economic and physical well-being, plus, the potentiality of meeting the global goals of lessening carbon emissions. The absence of access, termed energy poverty in developing countries, has several key aspects: inaccessibility to electricity on demand, is one aspect. However, inaccessibility to modern (or clean) cooking fuels is another critical aspect. A cause and effect of households' continuous heavy reliance on traditional (or solid) fuels. Despite over a third of the global population having this issue, this aspect of energy poverty continues to be a severe, yet overlooked development issue: particularly in developing countries. A review of literature shows that there are currently no empirical studies which quantify the sole relationship between the utilization of traditional energy fuels for cooking and/or heating and economic development. Thus, in this paper, we advance existing literature in multiple-folds. Firstly, we provide a review in an absent area of literature. Secondly, using the data from 46 sub-Saharan African countries, we provide empirical evidence of the impacts of the continued utilization of traditional fuels on economic development (employing Gross Domestic Product (GDP) per Capita as variable). Following the establishment of a negative causal relationship running from traditional fuels use (solid) to GDP per capita, we provide an insight into policy implications. Finally, we comment on potential policy strategies. • Lack of access to clean cooking fuels is an overlooked issue in developing countries. • Impact of solid cooking fuels on economic growth was analysed for sub-Saharan Africa. • Results show unidirectional causality between solid cooking fuels and GDP per capita. • Use of solid cooking fuels is observed to negatively influence economic development. • Reducing use of solid cooking fuels is vital for economic growth of these countries. [ABSTRACT FROM AUTHOR]

Electricity consumption in Sub- Saharan Africa has surged over the past two decades, whereas economic fundamentals like growth in gross domestic product ( GDP) might have contributed to this trend, the impact of changing climatic conditions cannot be underestimated. This study therefore investigates the dynamics among electricity consumption, temperature variability (a proxy for climate change) and economic growth, while controlling for urbanization within a structural vector error correction model for 11 countries in Sub- Saharan Africa. Findings from the study indicate that a positive shock in temperature variability has a positive permanent effect on electricity consumption for all the countries except Togo, South Africa and Zimbabwe. In the case of Togo we find only transitory effects of positive shocks in temperature variability on electricity consumption. However, these effects are minimal, given the low penetration rate for air conditioners and heating devices in these countries. Moreover the findings further indicate that the effects of a positive shock in temperature variability on real GDP is consistent in terms of the direction of the effects, which is negative, but only vary across the sampled countries in relation to the period(s) the effects of the shocks completely diminished. [ABSTRACT FROM AUTHOR]

This study examined the current state of water demand and associated energy input for water supply against a projected increase in water demand in sub-Saharan Africa. Three plausible scenarios, namely, Current State Extends (CSE), Current State Improves (CSI) and Current State Deteriorates (CSD) were developed and applied using nine quantifiable indicators for water demand projections and the associated impact on energy input for water supply for five Water Service Providers (WSPs) in Kenya to demonstrate the feasibility of the approach based on real data in sub-Saharan Africa. Currently, the daily per capita water-use in the service area of four of the five WSPs was below minimum daily requirement of 50 L/p/d. Further, non-revenue water losses were up to three times higher than the regulated benchmark (range 26–63%). Calculations showed a leakage reduction potential of up to 70% and energy savings of up to 12 MWh/a. The projected water demand is expected to increase by at least twelve times the current demand to achieve universal coverage and an average daily per capita consumption of 120 L/p/d for the urban population by 2030. Consequently, the energy input could increase almost twelve-folds with the CSI scenario or up to fifty-folds with the CSE scenario for WSPs where desalination or additional groundwater abstraction is proposed. The approach used can be applied for other WSPs which are experiencing a similar evolution of their water supply and demand drivers in sub-Saharan Africa. WSPs in the sub-region should explore aggressive strategies to jointly address persistent water losses and associated energy input. This would reduce the current water supply-demand gap and minimize the energy input that will be associated with exploring additional water sources that are typically energy intensive. [ABSTRACT FROM AUTHOR]

When considering the electrification of a particular region in developing country, the electricity consumption in that region must be estimated. In sub-Saharan Africa, which is one of the areas with the lowest electrification rates in the world, the villages of minority groups are scattered over a vast area of land, so electrification using distributed generators is being actively studied. Specifically, constructing a microgrid or introducing a solar system to each household is being considered. In this case, the electricity consumption of each area needs to be estimated, then a system with enough capacity could be introduced. In this study, we propose a household income electricity consumption model to estimate the electricity consumption of a specific area. We first estimate the electricity consumption of each household based on income and the electricity consumption of a specific area can be derived by adding up them in that area. Through a case study in Tanzania, electricity consumption derived using this model was compared with electricity consumption published by TANESCO, and the validity of the model was verified. We forecasted the electricity consumption in each region using the household income electricity consumption model, and the average forecast accuracy was 74%. The accuracy was 87% when the electricity consumption in Tanzania mainland was forecasted by adding the predicted values. [ABSTRACT FROM AUTHOR]