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A solar powered trigeneration system consisting of tower solar collector, Kalina cycle with the heat exchanger, and ejector-absorption refrigeration cycle is proposed to produce refrigeration below freezing, electricity, and process heat, simultaneously. Simulation through computational fluid dynamics using ansys-fluent package is conducted to examine the effect of coil diameter and inlet oil temperature on the pressure and temperature of solar heat transfer fluid. It is found that, for inlet temperature of 92 °C and direct normal irradiations of 850 W/m2, the solar heat transfer fluid outlet temperature increases by 9% when the coil diameter increased from 150 to 400 mm. Trigeneration performance is analyzed after altering hot oil outlet temperature, turbine inlet pressure, and the concentration of ammonia–water basic solution to study their effect on power produced by turbine, refrigeration load, exergy of refrigeration, and efficiencies of trigeneration system. An increase in the concentration of the ammonia–water basic solution is leading toward the significant increase in the turbine power and the elevation of trigeneration system’s energy and exergy efficiencies. Bottoming of the Kalina cycle with ejector-absorption refrigeration cycle shows the distribution of solar energy as energetic output 72.31% and energy lost to environment 27.69%. The solar exergy supplied to the trigeneration system is distributed as follows: 16.23% is the exergy produced, 1.62% is the exergy loss, and 82.15% is the exergy destroyed.

Satellite-based solar power data is becoming more and more important because of its continuous temporal and spatial availability. However, its reliability can be enhanced through quality control and calibration against ground-based measurement data. Here, a holistic methodology is employed for the adaptation of satellite-based data for estimating solar energy. For the purpose, high-quality ground-based measurement data and satellite-based datasets are assessed across 12 sites in three small islands located in the Indian Ocean. Initially, both datasets go through a rigorous quality control process. A quantitative analysis of irradiance and insolation data is then conducted. Eventually, site adaptation of satellite-based data is performed using bias removal technique and statistical analysis of datasets. A set of seven statistical performance indicators is used to support the assessment. Analysis of datasets shows that adaptation of peak values should be performed separately. Results showed that despite the small surface areas of the islands studied, a spatial variation of insolation can be depicted. A temporal variation of insolation is also noted with a peak in the summer and low insolation levels in winter. Peak irradiance values tend to exceed solar constant for all sites. Variations of peak irradiance can only be noticed in ground-based measurement data. While insolation levels are comparable in the summer season for all the sites, insolation levels in the winter season are higher in the sites with lower latitudes. Calibration factors for peak irradiance, monthly and annual average irradiance as well as yearly insolation are presented.

The present study deals with the experimental performance of a Marquise shaped channel solar flat-plate collector using Al2O3/water nanofluid and base fluid (pure water). The experimental setup comprises a special type of solar flat plate collector, closed working fluid systems, and the measurement devices. The absorber plate is made of two aluminum plates sandwiched together with Marquise-shaped flow channels. The volume fraction of 0.1% of Al2O3/water nanofluid is used for this study. The various parameters used to investigate performance of the collector energy and exergy efficiency are collector inlet and outlet fluid temperatures, mass flow rate of the fluid, solar radiation, and ambient temperature. The flow rate of nanofluid and water varies from 1 to 5 lpm. The maximum energy efficiencies attained are 83.17% and 59.72%, whereas the maximum exergy efficiencies obtained are 18.73% and 12.29% for the 20 nm—Al2O3/water nanofluids and pure water, respectively, at the flow rate of 3 lpm. These higher efficiencies may be due to the use of nanofluids and the sophisticated design of the absorber plate with the Marquise shaped channel.

A scheme to streamline the electric power generation profile of concentrating solar power (CSP) plants of the parabolic trough collector (PTC) type is suggested. The scheme seeks to even out heat transfer rates from the solar field (SF) to the power block (PB) by splitting the typical heat transfer fluid (HTF) loop into two loops using an extra vessel and an extra pump. In the first loop, cold HTF is pumped by the cold pump from the cold vessel to the SF to collect heat before accumulating in the newly introduced hot vessel. In the second loop, hot HTF is pumped by the hot pump from the hot vessel to a heat exchanger train (HXT) to supply the PB with its heat load before accumulating in the cold vessel. The new scheme moderately decouples heat supply from heat sink allowing for more control of heat delivery rates thereby evening out power generation.

Oxide particles have potential as robust heat transfer and thermal energy storage (TES) media for concentrating solar power (CSP). Particles of low-cost, inert oxides such as alumina and/or silica offer an effective, noncorrosive means of storing sensible energy at temperatures above 1000 °C. However, for TES subsystems coupled to high-efficiency, supercritical-CO2 cycles with low temperature differences for heat addition, the limited specific TES (in kJ kg−1) of inert oxides requires large mass flow rates for capture and total mass for storage. Alternatively, reactive oxides may provide higher specific energy storage (approaching 2 or more times the inert oxides) through adding endothermic reduction. Chemical energy storage through reduction can benefit from low oxygen partial pressures (PO2) sweep-gas flows that add complexity, cost, and balance of plant loads to the TES subsystem. This paper compares reactive oxides, with a focus on Sr-doped CaMnO3–δ perovskites, to low-cost alumina-silica particles for energy capture and storage media in CSP applications. For solar energy capture, an indirect particle receiver based on a narrow-channel, counterflow fluidized bed provides a framework for comparing the inert and reactive particles as a heat transfer media. Low-PO2 sweep gas flows for promoting reduction impact the techno-economic viability of TES subsystems based on reactive perovskites relative to those using inert oxide particles. This paper provides insights as to when reactive perovskites may be advantageous for TES subsystems in next-generation CSP plants.

The installation of solar power plants is currently having a notable expansion. The results presented show that the Argentinean Andes range, from the central to northern latitudes, is an excellent region for the placement of these plants, due to the sum of different positive factors: very high mean annual solar irradiation, low ambient temperature and relative humidity, low precipitable water content, normal wind speeds, and extremely low aerosol content of the atmosphere. The proposed regions are nearby San Antonio de los Cobres and El Leoncito and are compared with two important locations where large solar power plants have been (or will be) built: a site in Africa (Ouarzazate, Morocco) and one in Asia (Dubai, Arab Emirates). We present the results of the possible production of electricity, supplying a total of about 21,000 GWh, which is 15.6% of the 2015 Argentinean electric consumption and, consequently, could reduce the emission of greenhouse gases in a total mass of 11.2 × 106 tons of CO2eq. The installation of this type of renewable power plant will contribute significantly to the Argentinean population due to frequent (mainly summer) cutoff of electric power supply and, in particular, to isolated (low income) populations leaving in the Argentinean Andes range. Fil: Della Ceca, Lara Sofia. Consejo Nacional de Investigaciones Científicas y Técnicas. Centro Científico Tecnológico Conicet - Rosario. Instituto de Física de Rosario. Universidad Nacional de Rosario. Instituto de Física de Rosario; Argentina Fil: Micheletti, Maria Isabel. Consejo Nacional de Investigaciones Científicas y Técnicas. Centro Científico Tecnológico Conicet - Rosario. Instituto de Física de Rosario. Universidad Nacional de Rosario. Instituto de Física de Rosario; Argentina. Universidad Nacional de Rosario. Facultad de Ciencias Bioquímicas y Farmacéuticas; Argentina Fil: Freire, Martín Miguel. Consejo Nacional de Investigaciones Científicas y Técnicas. Centro Científico Tecnológico Conicet - Rosario. Instituto de Física de Rosario. Universidad Nacional de Rosario. Instituto de Física de Rosario; Argentina Fil: Garcia, Beatriz Elena. Consejo Nacional de Investigaciones Científicas y Técnicas. Oficina de Coordinación Administrativa Parque Centenario. Instituto de Tecnología en Detección y Astropartículas. Itedam - Subsede del Instituto de Tecnologías en Detección y Astropartículas Mendoza | Comisión Nacional de Energía Atómica. Instituto de Tecnologías en Detección y Astropartículas. Itedam - Subsede del Instituto de Tecnologías en Detección y Astropartículas Mendoza | Universidad Nacional de San Martín. Instituto de Tecnologías en Detección y Astropartículas. Itedam - Subsede del Instituto de Tecnologías en Detección y Astropartículas Mendoza; Argentina. Universidad Tecnológica Nacional. Facultad Regional de Mendoza; Argentina Fil: Mancilla, Alexis Javier. Consejo Nacional de Investigaciones Científicas y Técnicas. Oficina de Coordinación Administrativa Parque Centenario. Instituto de Tecnología en Detección y Astropartículas. Itedam - Subsede del Instituto de Tecnologías en Detección y Astropartículas Mendoza | Comisión Nacional de Energía Atómica. Instituto de Tecnologías en Detección y Astropartículas. Itedam - Subsede del Instituto de Tecnologías en Detección y Astropartículas Mendoza | Universidad Nacional de San Martín. Instituto de Tecnologías en Detección y Astropartículas. Itedam - Subsede del Instituto de Tecnologías en Detección y Astropartículas Mendoza; Argentina. Universidad Tecnológica Nacional. Facultad Regional de Mendoza; Argentina Fil: Salum, Graciela Marisa. Consejo Nacional de Investigaciones Científicas y Técnicas. Centro Científico Tecnológico Conicet - Rosario. Instituto de Física de Rosario. Universidad Nacional de Rosario. Instituto de Física de Rosario; Argentina. Yachay Tech University; Ecuador Fil: Crinó, Edgar Rafael. Universidad Nacional de San Luis. Facultad de Ciencias Físico- Matemáticas y Naturales; Argentina Fil: Piacentini, Ruben Dario Narciso. Consejo Nacional de Investigaciones Científicas y Técnicas. Centro Científico Tecnológico Conicet - Rosario. Instituto de Física de Rosario. Universidad Nacional de Rosario. Instituto de Física de Rosario; Argentina. Universidad Nacional de Rosario. Facultad de Ciencias Exactas, Ingeniería y Agrimensura. Instituto de Mecánica Aplicada y Estructuras; Argentina

A previously developed model of a concentrating solar power plant has been modified to accommodate doping the heat transfer fluid (HTF) with nanoparticles. The model with its unalloyed HTF has been validated with actual operating data beforehand. The thermo-physical properties of the HTF were modified to account for the nanoparticle doping. The nanoparticle content in the HTF was then varied to evaluate its influence on solar power generation. The model was run to simulate plant operation on four different days representing the four different seasons. As the nanoparticle concentration was increased, heat losses were slightly reduced, transient warm up heat was increased, transient cool down heat was reduced, and the overall impact on power generation was trivial. Doping HTFs with nanoparticles does not seem promising for solar thermal power generation from a performance perspective. Moreover, doping HTFs with nanoparticles involves many other operational challenges such as sedimentation and abrasion.

This paper presents the simulation and modeling of the concentrated solar power (CSP) plant for multipurpose applications at Borg El Arab in Egypt. The plant produces 1 MWe and 250 m3 of distilled water using steam turbine and electric generator. The purpose of using different applications is to improve the overall efficiency and the coefficient of performance of the plant. The trnsys simulation platform was used for simulating the thermal performance of the solar power and desalination plant covering the parabolic trough concentrator (PTC), storage tank with an integrated steam generator, a backup unit, steam turbine, electric generator, and two effects desalination unit. The temperature and energy profiles of the plant were investigated for the PTC, steam generator and the electric generator. The results prove that the simulation could be used to support the operation of the CSP plant and for improving the performance of the cogeneration plant at Borg El Arab.

The accurate prediction of the direct and diffuse solar radiation is of foremost importance for deployment of photovoltaic (PV) systems. A number of solar radiation forecasting techniques have been developed for longer and shorter forecasting times. Numerical weather prediction (NWP) models provide the best results for the longer forecasting times (4–6 h), required by utility companies. However, NWP methods are usually developed for clear-sky and open areas. These methods cannot be directly applied to urban areas with shading, trees, multisurface reflection, and other sources of solar radiation losses. To overcome these issues, improvement to the existing prediction tools are required. In this study, we develop an automated radiation forecasting tool for urban areas. This tool combines a NWP model (Weather Research and Forecasting (WRF) model) and a solar calculator (developed in the numerical toolbox OpenFOAM) to compute shading, reflection, and other losses in the urban canopy. An algorithm for extraction of building outlines and heights (if they are publicly available) is also developed as a part of the tool. Finally, the coupled solar power estimator can be applied to past, present, or future solar power predictions. Initial results obtained using the developed tool are demonstrated for an urban neighborhood in Singapore.

Baking is an energy intensive unit operation. The thermal application of solar energy is getting attention in food processes by eliminating the facts of interrupted supply and fluctuated costs of nonrenewable energy sources. This study has been carried out for the design and development of solar bakery unit which comprises of a 10 m2 Scheffler reflector focusing all the beam radiations on a secondary reflector that further concentrate the beam radiations toward the heat receiver of solar bakery unit to heat up the air circulated through baking chamber employing a photovoltaic operated fan. Computational fluid dynamic (CFD)-based three-dimensional (3D) simulation was performed to analyze the design for uniform air distribution in the baking chamber. The system designed configurations gave quite good results for airflow distribution. The receiver temperature reached between 300 and 400 °C while temperature at the inlet of baking chamber was in the range of 200–230 °C, sufficient for most of the products to be baked. The maximum available solar power at receiver was calculated to be 3.46 kW having an average efficiency of 63%. A series of experiments were conducted for the baking of cakes and total energy available in baking chamber was about 3.29 kW and cake utilized 0.201 kW energy to be baked. The average value of energy utilization ratio was found to be 45%. As a base, the study would lead to the development of an appropriate and low cost solar baking units for the maximum retention of quality parameters and energy saving.

A 7.2 kW (electric input) solar simulator was designed in order to perform accelerated testing on absorber materials for concentrating solar power (CSP) technologies. computer-aided design (cad) software integrating a ray-tracing tool was used to select appropriate components and optimize their positioning in order to achieve the desired concentration. The simulator comprises four identical units, each made out of an ellipsoidal reflector, a metal halide lamp, and an adjustable holding system. A single unit was characterized and shows an experimental average irradiance of 257 kW m−2 on a 25.4 mm (1 in) diameter spot. Shape, spot size, and average irradiance are in good agreement with the model predictions, provided the emitting arc element model is realistic. The innovative four-lamp solar simulator potentially demonstrates peak irradiance of 1140 kW m−2 and average irradiance of 878 kW m−2 over a 25.4 mm diameter area. The electric-to-radiative efficiency is about 0.86. The costs per radiative and electric watt are calculated at $2.31 W−1 and $1.99 W−1, respectively. An upgraded installation including a sturdier structure, computer-controlled lamps, a more reliable lamp holding system, and safety equipment yields a cost per electric watt of about $3.60 W−1 excluding labor costs.

Quite a few computer programs have been developed to model power plant performance. These software codes are geared toward modeling steady-state operations, which are usually sufficient for conventional power plants. Solar thermal power plants undergo prolonged transient start-up and shut-down operations due to the periodic nature of solar radiation. Moreover, the large size of the solar field brings about large residence time that must be considered to accurately lag power generation. A novel scheme has been developed to fine-tune steady-state solar power generation models to accurately take account of the impact of those transient operations. The suggested new scheme is implemented by adjusting solar radiation data input to the model and has been shown to clearly improve modeling accuracy by moving modeled results closer to matching real operating data.

The additive manufacturing integrated energy (AMIE) demonstration utilized three-dimensional (3D) printing as an enabling technology in the pursuit of construction methods that use less material, create less waste, and require less energy to build and operate. Developed by Oak Ridge National Laboratory (ORNL) in collaboration with the Governor's Chair for Energy and Urbanism, a research partnership of the University of Tennessee (UT) and ORNL led by Skidmore, Owings & Merrill LLP (SOM), AMIE embodies a suite of innovations demonstrating a transformative future for designing, constructing, and operating buildings. Subsequent, independent UT College of Architecture and Design studios taught in collaboration with SOM professionals also explored forms and shapes based on biological systems that naturally integrate structure and enclosure. AMIE, a compact microdwelling developed by ORNL research scientists and SOM designers, incorporates next-generation modified atmosphere insulation (MAI), self-shading windows, and the ability to produce, store, and share solar power with a paired hybrid vehicle. It establishes for the first time, a platform for investigating solutions integrating the energy systems in buildings, vehicles, and the power grid. The project was built with broad-based support from local industry and national material suppliers. Designed and constructed in a span of only 9 months, AMIE 1.0 serves as an example of the rapid innovation that can be accomplished when research, design, academic, and industrial partners work in collaboration toward the common goal of a more sustainable and resilient built environment.

Concentrated solar power (CSP) plants have the potential to reduce the consumption of nonrenewable resources and greenhouse gas emissions in electricity production. In CSP systems, a field of heliostats focuses solar radiation on a central receiver, and energy is then transferred to a thermal power plant at high temperature. However, maximum receiver surface fluxes are low (30–100 W cm−2) with high thermal losses, which has contributed to the limited market penetration of CSP systems. Recently, small (∼4 cm2), laminated micro pin-fin devices have shown potential to achieve concentrated surface fluxes over 100 W cm−2 using supercritical CO2 as the working fluid. The present study explores the feasibility of using these microscale unit cells as building blocks for a megawatt-scale (250 MW thermal) open solar receiver through a numbering-up approach, where multiple microscale unit cell devices are connected in parallel. A multiscale model of the full-scale central receiver is developed. The model consists of interconnected unit cell and module level (i.e., multiple unit cells in parallel) submodels which predict local performance of the central receiver. Each full-scale receiver consists of 3000 micro pin-fin unit cells divided into 250 modules. The performance of three different full-scale receivers is simulated under representative operating conditions. The results show that the microscale unit cells have the potential to be numbered up to megawatt applications while providing high heat flux and thermal efficiency. At the design incident flux and surface emissivity, a global receiver efficiency of approximately 90% when heating sCO2 from 550 °C to 650 °C at an average incident flux of 110 W cm−2 can be achieved.

The performance of parabolic trough (PT) receiver tubes (RT) has a direct impact on concentrated solar power (CSP) plant production. As a result, one major need of operation and maintenance (O&M) in operating plants is to monitor the state of the receiver tube as a key element in the solar field. In order to fulfill this necessity, Abengoa Solar has developed the first existing portable device for measuring transmittance and reflectance of parabolic trough receiver tubes directly in the field. This paper offers a description of the technical features of the instrument and reviews the issues related to its usability as a workable portable device in operating solar fields. To evaluate its performance, laboratory studies have been carried out using two patterns to determine the accuracy and standard deviation of the measurements, obtaining excellent results. This information is complemented with data collected by O&M using this instrument in solar power plants. Studies have been carried out to determine the effect of both rainfall and artificial cleaning on the increase of transmittance. These values are then compared to those obtained from hand-cleaning and show important differences. The results are discussed in this paper.

The design of a solar field is one of the crucial aspects when a solar tower system is realized. In general, shading and blocking effects, which are the main causes of solar power losses, are minimized displacing the heliostats each other quite distant, with typical land coverage less than 20%, and thus, strongly limiting the construction of these plants to low value lands. A new method is proposed here to improve the collected energy for solar tower systems with high land coverage (greater than 30%), based on the chance for each heliostat to rotate about the normal passing through the center of its surface. Then, shading and blocking are minimized by optimization of the relative orientations. To this aim, a small solar field composed of 150 rectangular flat heliostats has been considered, and its performances with and without the proposed optimization have been computed and compared for a wide variety of cases. In particular, a systematic analysis is presented to study the effect of the shape of the heliostats on the solar field performance: in a series of simulations, maintaining constant the area of each heliostat, the ratio between its two sides has been varied in a range between 1 (squared heliostats) and 3 (very stretched heliostats), and optimized and nonoptimized systems have been compared. Also, the total energy collected by the solar field has been calculated for optimized and nonoptimized heliostats' orientations, considering towers of different heights. Finally, the real PS10 solar plant has been considered, demonstrating that also for an optimized, very low coverage plant (about 14%), heliostats rotation can still improve the energy collection efficiency by a non-negligible amount.

Team Ontario is one of twenty collegiate teams selected to design and build a solar powered, net positive home for the U.S. Department of Energy Solar Decathlon 2013. One aspect of Team Ontario’s competition design entry is a high R-value wall using vacuum insulation panels. This paper details the method used for theoretical evaluation of the high R-value wall, stating all simplifying assumptions made. Theoretical simulations were performed in THERM, a two dimensional finite element heat transfer modelling program. Following a weighted average method used by industry experts, the whole-wall thermal resistance value was calculated. To verify the modelling results, an in-situ experimental validation was conducted. An 8′ × 8′ wall test specimen was built to the specifications of Team Ontario’s wall design. Experimental heat flux and temperature readings were collected from the test specimen in Carleton University’s Vacuum Insulation Test Facility located in Ottawa, Ontario, Canada, with the test specimen exposed to exterior weather elements. The experimental and theoretical results are compared and conclusions drawn to determine the effective thermal resistance of the vacuum insulation panels installed in the wall assembly. Finally the theoretical model is refined based on the previous study and a more accurate whole-wall thermal resistance of Team Ontario’s wall design is determined.

The optical design and thermal performance of a solar power tower system using an array of high-temperature pressurized air-based solar receivers is analyzed for Brayton, recuperated, and combined Brayton–Rankine cycles. A 50 MWe power tower system comprising a cluster of 500 solar receiver modules, each attached to a hexagon-shaped secondary concentrator and arranged side-by-side in a honeycomb-type structure following a spherical fly-eye optical configuration, can yield a peak solar-to-electricity efficiency of 37%.

Fixed tilt flat-plate solar thermal collectors, popularly known as solar water heaters, still remain as one of the most interesting technologies for utilization of solar energy. The system performance deteriorates due to scaling because of the continuous use of hard water as feed water. The present study deals with the experimental and analytical approach to determine the variation of Hottel–Whillier–Bliss (H–W–B) constants (which compactly represent the efficiency characteristics of a solar water heater) due to variation in solar power input and degree of scaling in case of forced circulation system (FCS) without considering the variation of input power to the circulating pump. Indoor tests are performed with a copper tube to investigate the flow characteristics. This forms a part of conventional FCS, in place of the usual nine-fin tube array in a full-fledged collector. In indoor tests, electrical heating is favored to simulate solar radiation level. Various energy parameters are determined and compared by incorporating the developed numerical code FLATSCALE. Variation between experimental and analytical mass flow rate, overall heat loss coefficient, and H–W–B constants with simulated solar radiation level is plotted. In scaled condition, the drop in instantaneous efficiency is due to both scale thickness and reduced water flow rate. Scale thickness acts as an additional thermal conductive resistance between absorber plate and flowing water. Overall heat loss coefficient increases as absorber plate temperature is high during reduced flow rate. The maximum deviation observed is 21.68% in mass flow rate, 14.64% in absorber plate mean temperature, 7.86% in overall heat loss coefficient, and 12.04% in instantaneous efficiency. Compared to a clean tube, a highly scaled tube of 3.7 mm scale thickness indicates a drop of 4.76% in instantaneous efficiency and 40.28% in mass flow rate. It is concluded that the growth of scale in FCS does not affect the instantaneous efficiency significantly because of the margin in heat carrying capacity of water in spite of high drop in the flow rate.

Concentrating solar power (CSP) is an effective means of converting solar energy into electricity with an energy storage capability for continuous, dispatchable, renewable power generation. However, challenges with current CSP systems include high initial capital cost and electricity price, and advances are needed to increase outlet temperature to drive high-efficiency power cycles while simultaneously maintaining stability of the heat-transfer medium and thermal performance of the receiver. Solid-particle-based CSP systems are one alternative projected to have significant cost and performance advantages over current nitrate-based molten salt systems. NREL is developing a design that uses gas/solid, two-phase flow as the heat-transfer fluid (HTF) and separated solid particles as the storage medium. A critical component in the system is a novel near-blackbody (NBB) enclosed particle receiver that uses an array of absorber tubes with a granular medium flowing downward through channels between tubes. Development of the NBB enclosed particle receiver necessitates detailed investigation of the dimensions of the receiver, particle-flow conditions, and heat-transfer coefficients. This study focuses on simulation and analysis of granular flow patterns and the resulting convective and conductive heat transfer to the particulate phase using Eulerian–Eulerian two-fluid modeling techniques. Heat-transfer coefficients in regions with good particle/wall contact are predicted to exceed 1000 W/m2 K. However, simulations predict particle/wall separation in vertical flow channels and a resultant reduction in heat transfer. Particle-flow visualization experiments confirm particle/wall separation, but also exhibit complex periodic behavior and flow instability that create intermittent side-wall contact and enhance heat transfer above that predicted by the theoretical simulations.

Current heliostats cost ∼$200/m2 of reflective area and are estimated to contribute up to 50% of the total solar power tower plant costs. A drastic overall cost reduction is required in order for concentrated solar thermal power to be economically viable. The Department of Energy has set forth the SunShot initiative targeting a levelized cost of energy (LCOE) of $0.06/kWh by the year 2020. The cost of each heliostat must be brought down to an estimated $75/m2 to achieve this rigorous goal. One of the driving aspects of heliostat design and cost are the heliostat optical errors. At the moment, it is relatively unclear about the amount of error that can be present in the system while still maintaining low cost and high optical accuracy. The optical errors present on heliostat mirror surfaces directly influence the plant LCOE by causing beam spillage. This can result in an increase in the number of heliostats, an increased receiver size, and decreased thermal efficiency. Assuming a fixed heliostat cost of $75/m2, the effects of optical errors on LCOE were evaluated within the software delsol. From a probabilistic analysis, beam quality errors (i.e., slope error, alignment errors, etc.) were shown to have more importance on the LCOE than tracking errors. This determination resulted in a realization that the tracking errors and beam quality errors could be combined into a “bundled” root-sum-square (RSS) error value and produce similar results in delsol. A “bundled” error value of 2 mrad resulted in an LCOE of $0.06/kWh. This “bundled” value was the basis for a new optical error budget and is decomposed into five individual errors. These five errors can be used as design specifications for new generation heliostats.

Probabilistic cost analysis determined the cost benefit for applying a protective coating to the wetted surfaces of stainless steel tank walls for concentrating solar power (CSP) thermal storage applications. The model estimated the total material cost of coated 347 or 310 stainless steel (347/310) and the cost of uncoated Inconel 625, which served as the reference tank wall cost. Model results showed that the cost of the coated 347/310 stainless steel was always statistically less than the cost of the bare Inconel 625 when these materials are used for tank walls at representative tank diameters and temperatures for CSP storage applications.

Besides continuous implementation of concentrating solar power plants (CSP) in Europe, which stipulate cost reduction by mass production effects, further R&D activities are necessary to achieve the cost competitiveness to fossil power generation. The European Concentrated Solar Thermal Roadmap (ECOSTAR) study that was conducted by European research institutes in the field of CSP intends to stipulate the direction for R&D activities in the context of cost reduction. This paper gives an overview about the methodology and the results for one of the seven different CSP system concepts that are currently under promotion worldwide and considered within ECOSTAR. The technology presented here is the parabolic trough with direct steam generation (DSG), which may be considered as an evolution of the existing parabolic systems with thermal oil as heat transfer fluid. The methodology is explained using this exemplary system, and the technical improvements are evaluated according to their cost-reduction potential using a common approach, based on an annual performance model. Research priorities are given based on the results. The simultaneous implementation of three measures is required in order to achieve the cost-reduction target: Technical improvement by R&D, upscaling of the unit size, and mass production of the equipment.

Liquid-fluoride-salt heat transfer fluids are proposed to raise the heat-to-electricity efficiencies of solar power towers to about 50%. The liquid salt would deliver heat from the solar furnace at temperatures between 700°C and 850°C to a closed multireheat Brayton power cycle using nitrogen or helium as the working fluid. During the daytime, hot salt may also be used to heat graphite, which would then be used as a heat storage medium to make night-time operations possible. Graphite is a low-cost high-heat-capacity solid that is chemically compatible with liquid fluoride salts at high temperatures. About half the cost of a solar power tower is associated with the mirrors that focus light on the receiver, and less than one-third is associated with the power cycle and heat storage. Consequently, increasing the efficiency by 20–30% has the potential for major reductions in the cost of electricity. Peak temperatures and efficiencies of current designs of power towers are restricted by (1) the use of liquid nitrate salts that decompose at high temperatures and (2) steam cycles in which corrosion limits peak temperature. The liquid-fluoride-salt technology and closed Brayton power cycles are being developed for high-temperature nuclear reactors. These developments may provide the technology and industrial basis for an advanced solar power tower.

In the framework of the EU-project SOLZINC, a 300-kW solar chemical pilot plant for the production of zinc by carbothermic reduction of ZnO was experimentally demonstrated in a beam-down solar tower concentrating facility of Cassegrain optical configuration. The solar chemical reactor, featuring two cavities, of which the upper one is functioning as the solar absorber and the lower one as the reaction chamber containing a ZnO/C packed bed, was batch-operated in the 1300–1500 K range and yielded 50 kg/h of 95%-purity Zn. The measured energy conversion efficiency, i.e., the ratio of the reaction enthalpy change to the solar power input, was 30%. Zinc finds application as a fuel for Zn/air batteries and fuel cells, and can also react with water to form high-purity hydrogen. In either case, the chemical product is ZnO, which in turn is solar-recycled to Zn. The SOLZINC process provides an efficient thermochemical route for the storage and transportation of solar energy in the form of solar fuels.

The direct steam generation (DSG) is an attractive option regarding the economic improvement of parabolic trough technology for solar thermal electricity generation in the multi megawatt range. According to Price, H., Lu¨pfert, E., Kearney, D., Zarza, E., Cohen, G., Gee, R. Mahoney, R., 2002, “Advances in Parabolic Trough Solar Power Technology,” J. Sol. Energy Eng., 124 and Zarza, E., 2002, DISS Phase II-Final Project Report, EU Project No. JOR3-CT 980277 a 10% reduction of the LEC is expected compared to conventional SEGS like parabolic trough power plants. The European DISS project has proven the feasibility of the DSG process under real solar conditions at pressures up to 100 bar and temperatures up to 400°C in more than 4000 operation hours (Eck, M., Zarza, E., Eickhoff, M., Rheinla¨nder, J., Valenzuela, L., 2003, “Applied Research Concerning the Direct Steam Generation in Parabolic Troughs,” Solar Energy 74, pp. 341–351). In a next step the detailed engineering for a precommercial DSG solar thermal power plant will be performed. This detailed engineering of the collector field requires the consideration of the occurring thermohydraulic phenomena and their influence on the stability of the absorber tubes.

In Spain, as in other Mediterranean and low-latitude countries, cooling loads of the same order of magnitude or even higher than heating loads coexist with high solar radiation resources. Cooling loads in most of these countries have, thus far, not been completely incorporated into the building sector energy demand because they arise after that DHW (domestic hot water) and heating loads have been satisfied and the living standard of the population reaches a given threshold. The increasing comfort demand in the cooling season from a population living in buildings that were developed without taking into account these considerations are bringing about a strong increase in the installation of domestic vapor compression air conditioning units, aimed to partially fulfil the thermal comfort demand in few rooms of these dwellings. This has a significant impact on the environment and the electricity distribution system, in a moment when strong environmental constraints are being imposed on the energy system to fulfil international agreements as the Kyoto protocol. Solar absorption cooling emerges as an interesting alternative to satisfy this growing energy demand for cooling applications with synergies with solar energy use for heating and DHW purposes. However, solar absorption cooling has been there already, for decades, without having a significant development, and still today presents some limitations that prevent its widespread application. Other solar cooling alternatives, such as the use of commercial vapor compression air conditioning equipment fed with electricity from centralized solar power plants could, in short, become available in these countries. In this paper, based on the experienced gained with the simulation of the most recent installations of absorption cooling installations in Spain, we perform a cost comparison between decentralized and centralized solar cooling options to give some insight into the development requirements and possibilities from both solar cooling options.

Concentrating solar power (CSP) technologies use large mirrors to collect sunlight to convert thermal energy to electricity. The viability of CSP systems requires the development of advanced reflector materials that are low in cost and maintain high specular reflectance for extended lifetimes under severe outdoor environments. The long-standing goals for a solar reflector are specular reflectance above 90% into a 4-mrad half-cone angle for at least 10 years outdoors with a cost of less than $13.8/m2 (the 1992 $10.8/m2 goal corrected for inflation to 2002 dollars) when manufactured in large volumes. Durability testing of a variety of candidate solar reflector materials at outdoor test sites and in laboratory accelerated weathering chambers is the main activity within the Advanced Materials task of the CSP Program at the National Renewable Energy Laboratory (NREL) in Golden, Colorado. Test results to date for several candidate solar reflector materials will be presented. These include the optical durability of thin glass, thick glass, aluminized reflectors, frontsurface mirrors, and silvered polymer mirrors. The development, performance, and durability of these materials will be discussed. Based on accelerated exposure testing the glass, silvered polymer, and front-surface mirrors may meet the 10-year lifetime goals, but at this time because of significant process changes none of the commercially available solar reflectors and advanced solar reflectors have demonstrated the 10-year or more aggressive 20-year lifetime goal.Copyright © 2004 by ASME

Dish-Stirling systems have demonstrated the highest efficiency of any solar power generation system by converting nearly 30% of direct-normal incident solar radiation into electricity after accounting for parasitic power losses[1]. These high-performance, solar power systems have been in development for two decades with the primary focus in recent years on reducing the capital and operating costs of systems. Even though the systems currently cost about $10,000 US/kW installed, major cost reduction will occur with mass production and further development of the systems. Substantial progress has been made to improve reliability thereby reducing the operating and maintenance costs of the systems. As capital costs drop to about $3000 US/kW, promising market opportunities appear to be developing in green power and distributed generation markets in the southwestern United States and in Europe. In this paper, we review the current status of four Dish-Stirling systems that are being developed for commercial markets and present system specifications and review system performance and cost data. We also review the economics, capital cost, operating and maintenance costs, and the emerging markets for Dish-Stirling systems.

A laptop by its virtue is a mobile apparatus therefore a power outlet may not necessarily be available to charge its batteries. Typical laptops have a range of up to two and a half hours of battery life under normal operation and some have as little as one and a half hours. Therefore for the computer user on the move it is important to have enough power available for more extended periods of time. Today’s technology provides a large number of other mobile appliances, instruments and tools that will also greatly benefit from extended power. Existing solar panels operate under direct sunlight conditions and are deployed only when the equipment is in use or stationary. The solar powered module developed at the Department of Mechanical Engineering, University of Puerto Rico – Mayaguez has the advantage that it recharges the laptop in transit even when it is not in operation. By charging the battery when it is stored it allows the battery to be recharged during a larger period of time therefore increasing the amount of energy stored. Different types of solar cells were tested under “real world” lighting situations in order to assess their potential for the intended application. The solar array was optimized for use under a larger range of illumination conditions such that it may operate when direct sunlight is not available. The ergonomic design is integrated into the laptop’s carrying case but it may also be detached and/or repositioned if desired. The solar panel is based on the latest technology of triple junction spectrum-splitting amorphous silicon solar cells. The equipment allows the use of a laptop or other portable equipment in situations when power is not available, therefore providing a needed service in remote locations to professionals in the field and provides a backup power source in the event of an emergency or lack of adequate infrastructure. The paper describes the design process in the selection of the solar cell technology used in the module.Copyright © 2002 by ASME

A literature review was carried out to critically evaluate the state of the art of thermal energy storage applied to parabolic trough power plants. This survey briefly describes the work done before 1990 followed by a more detailed discussion of later efforts. The most advanced system is a 2-tank-storage system where the heat transfer fluid (HTF) also serves as storage medium. This concept was successfully demonstrated in a commercial trough plant (13.8MWe SEGS I plant; 120MWht storage capacity) and a demonstration tower plant (10MWe Solar Two; 105MWht storage capacity). However, the HTF used in state-of-the-art parabolic trough power plants 30-80MWe is expensive, dramatically increasing the cost of larger HTF storage systems. Other promising storage concepts are under development, such as concrete storage, phase change material storage, and chemical storage. These concepts promise a considerable cost reduction compared to the direct 2-tank system, but some additional R&D is required before those systems can be used in commercial solar power plants. An interesting and likely cost-effective near-term option for thermal energy storage for parabolic trough power plants is the use of an indirect 2-tank-storage, where another (less expensive) liquid medium such as molten salt is utilized rather than the HTF itself.

Parabolic trough solar technology is the most proven and lowest cost large-scale solar power technology available today, primarily because of the nine large commercial-scale solar power plants that are operating in the California Mojave Desert. These plants, developed by Luz International Limited and referred to as Solar Electric Generating Systems (SEGS), range in size from 14–80 MW and represent 354 MW of installed electric generating capacity. More than 2,000,000m2 of parabolic trough collector technology has been operating daily for up to 18 years, and as the year 2001 ended, these plants had accumulated 127 years of operational experience. The Luz collector technology has demonstrated its ability to operate in a commercial power plant environment like no other solar technology in the world. Although no new plants have been built since 1990, significant advancements in collector and plant design have been made possible by the efforts of the SEGS plants operators, the parabolic trough industry, and solar research laboratories around the world. This paper reviews the current state of the art of parabolic trough solar power technology and describes the R&D efforts that are in progress to enhance this technology. The paper also shows how the economics of future parabolic trough solar power plants are expected to improve.

A thermo-economic simulation model of a hybrid solar gas-turbine (HSGT) power plant with an integrated storage unit has been developed, allowing determination of the thermodynamic and economic performance. Designs were based around two representative industrial gas-turbines: a high efficiency machine and a low temperature machine. In order to examine the trade-offs that must be made, multi-objective thermo-economic analysis was performed, with two conflicting objectives: minimum investment costs and minimum specific carbon dioxide (CO2) emissions. It was shown that with the integration of storage, annual solar shares above 85% can be achieved by HSGT systems. The levelized electricity cost (LEC) for the gas-turbine system as this level of solar integration was similar to that of parabolic trough plants, allowing them to compete directly in the solar power market. At the same time, the water consumption of the gas-turbine system is significantly lower than contemporary steam-cycle based solar thermal power plants.

The operation of steam turbine units in solar thermal power plants is very different than in conventional base-load plants. Due to the variability of the solar resource, much higher frequencies of plant start-ups are encountered. This study provides an insight to the influence of thermal energy storage (TES) integration on the typical cycling operation of solar thermal power plants. It is demonstrated that the integration of storage leads to significant reductions in the annual number of turbine starts and is thus beneficial to the turbine lifetime. At the same time, the effects of storage integration on the electricity costs are analyzed to ensure that the designs remain economically competitive. Large storage capacities, can allow the plant to be shifted from a daily starting regime to one where less than 20 plant starts occur annually. Additionally, the concept of equivalent operating hours (EOHs) is used to further analyze the direct impact of storage integration on the maintenance planning of the turbine units.

A generalized modeling method is introduced and used to evaluate thermal energy storage (TES) performance. The method describes TES performance metrics in terms of three efficiencies: first-law efficiency, second-law efficiency, and storage effectiveness. By capturing all efficiencies in a systematic way, various TES technologies can be compared on an equal footing before more detailed simulations of the components and concentrating solar power (CSP) system are performed. The generalized performance metrics are applied to the particle-TES concept in a novel CSP thermal system design. The CSP thermal system has an integrated particle receiver and fluidized-bed heat exchanger, which uses gas/solid two-phase flow as the heat-transfer fluid, and solid particles as the heat carrier and storage medium. The TES method can potentially achieve high temperatures (>800 °C) and high thermal efficiency economically.

In this paper, a solar powered home lighting system in the Electrical Engineering Department of Visvesvaraya National Institute of Technology (VNIT), Nagpur is analyzed for energy using a personal computer simulation program with integrated circuit emphasis (circuit simulation software, PSpice 9.1). The home lighting system consists of a solar panel of 37 Wp, a 45 Ah battery, a solar charge controller, dc loads of two 9 W compact fluorescent lamps (CFLs), and a dc fan of 14 W. Through the solar panel, the battery is charged during day time. In the night, when solar power is not available, the battery provides power as a backup to the dc load consisting of two CFLs and a dc fan. The aim of the paper is to analyze the solar home lighting system for energy gain/loss with a microcontroller-based charge controller. From the analysis, it is concluded that the solar home lighting system is not designed for continuous energy gain as per manufacturer's specifications. The design needs to be modified to have energy gain in the system for Nagpur, India. A designed microcontroller-based charge controller is also analyzed. The advantages of a microcontroller 89C2051-based charge controller are its simple design, low cost, logic change facility with change of programming of microcontroller, presence of liquid crystal display (LCD) with battery charge status, and display of different messages. Ride software is used as an assembler for generating the required hex file of program and it is used for burning in the microcontroller IC with the help of Vegarobokit (a microcontroller programmer developer) to make a microcontroller programmer.

The solar thermal reduction of ZnO, using solar process heat and CH4 or C as reducing agent, is investigated for CH4:ZnO or C:ZnO molar ratios ranging from 0 (thermal decomposition at above about 2000°C) to 1 (stoichiometric reduction at above about 1000°C). At 1400°C, in thermodynamic equilibrium ZnO can be completely reduced using a CH4:ZnO molar ratio of 0.3 and produces one fuel (Zn-metal) rather than two for the stoichiometric case (Zn and syngas). The maximal reactor thermal efficiency without heat recovery from the offgas, defined as the ratio of the heating-value of the zinc produced to the total thermal energy input, is 55%. CO2-emissions are reduced by a factor of 10–15 compared to fossil-fuel-based zinc-production technologies. For a closed materials cycle, in which power is extracted from the solar zinc using a fuel cell and the ZnO formed is recycled to the solar reactor, the total exergy efficiency, defined as the work output of the fuel cell to the thermal energy input, varies between 30 to 40% when based on the absorbed solar power in the reactor. These efficiency values are very encouraging, especially since the solar ZnO/Zn cycle allows—in contrast to other regenerative power plants—to store and transport solar energy.

A number of studies have been performed to assess the potential of using supercritical carbon dioxide (S-CO2) in closed-loop Brayton cycles for power generation. Different configurations have been examined among which recompression and partial cooling configurations have been found very promising, especially for concentrating solar power (CSP) applications. It has been demonstrated that the S-CO2 Brayton cycle using these configurations is capable of achieving more than 50% efficiency at operating conditions that could be achieved in central receiver tower type CSP systems. Although this efficiency is high, it might be further improved by considering an appropriate bottoming cycle utilizing waste heat from the top S-CO2 Brayton cycle. The organic Rankine cycle (ORC) is one alternative proposed for this purpose, however, its performance is substantially affected by the selection of the working fluid. In this paper, a simple S-CO2 Brayton cycle, a recompression S-CO2 Brayton cycle, and a partial cooling S-CO2 Brayton cycle are first simulated and compared with the available data in the literature. Then, an ORC is added to each configuration for utilizing the waste heat. Different working fluids are examined for the bottoming cycles and the operating conditions are optimized. The combined cycle efficiencies and turbine expansion ratios are compared to find the appropriate working fluids for each configuration. It is also shown that combined recompression-ORC cycle achieves higher efficiency compared with other configurations.Copyright © 2013 by ASME

In this paper a second level mathematical model for the computational simulation of the working process of a 1-kW Stirling engine has been used and the results obtained are presented. The internal circuit of the engine in the calculation scheme was divided into five chambers, namely, the expansion space, heater, regenerator, cooler and the compression space, and the governing system of ordinary differential equations for the energy and mass conservation were solved in each chamber by Euler’s method. In additional, mechanical losses in the construction of the engine have been determined and the computational results show that the mechanical losses for this particular design of the Stirling engine may be up to 50% of the indicated power of the engine.

Space-based inflatable technology is of current interest to NASA and DOD, and in particular to the Air Force and Phillips Laboratory. Potentially large gains in lowering launch costs, through reductions in structure mass and volume, are driving this activity. Diverse groups are researching and developing this technology for radio and radar antennae, optical telescopes, and solar power and propulsion applications. Regardless of the use, one common requirement for successful application is the accuracy of the inflated surface shape. The work reported here concerns the shape control of an inflated thin circular disk through use of a nonlinear finite element analysis. First, a review of the important associated Hencky problem is given. Then we discuss a shape modification, achieved through enforced boundary displacements, which resulted in moving the inflated shape towards a desired parabolic profile. Minimization of the figure error is discussed and conclusions are drawn.

A thermo-economic optimization model of an integrated solar combined-cycle (ISCC) has been developed to evaluate the performance of an existing combined-cycle gas turbine (CCGT) plant when retrofitted with solar trough collectors. The model employs evolutionary algorithms to assess the optimal performance and cost of the power plant. To define the trade-offs required for maximizing gains and minimizing costs (and to identify 'optimal' hybridization schemes), two conflicting objectives were considered, namely, minimum required investment and maximum net present value (NPV). Optimization was performed for various feed-in tariff (FIT) regimes, with tariff levels that were either fixed or that varied with electricity pool prices. It was found that for the given combined-cycle power plant design, only small annual solar shares (similar to 1.2% annual share, 4% of installed capacity) could be achieved by retrofitting. The integrated solar combined-cycle design has optimal thermal storage capacities that are several times smaller than those of the corresponding solar-only design. Even with strong incentives to shift the load to periods in which the prices are higher, investment in storage capacity was not promoted. Nevertheless, the levelized costs of the additional solar-generated electricity are as low as 10 c(sic)/kWh, compared to the 17-19 c(sic)/kWh achieved for a reference, nonhybridized, "solar-only" concentrating solar power plant optimized with the same tools and cost dataset. The main reasons for the lower cost of the integrated solar combined-cycle power plant are improved solar-to-electric efficiency and the lower level of required investment in the steam cycle. The retrofitting of combined-cycle gas turbine plants to integrated solar combined-cycle plants with parabolic troughs represents a viable option to achieve relatively low-cost capacity expansion and strong knowledge building regarding concentrating solar power.

Supercritical CO2 (s-CO2) operated in a closed-loop Brayton cycle offers the potential of higher cycle efficiency versus superheated or supercritical steam cycles at temperatures relevant for concentrating solar power (CSP) applications. Brayton-cycle systems using s-CO2 have a smaller weight and volume, lower thermal mass, and less complex power blocks versus Rankine cycles due to the higher density of the fluid and simpler cycle design. The simpler machinery and compact size of the s-CO2 process may also reduce the installation, maintenance, and operation cost of the system. In this work we explore s-CO2 Brayton cycle configurations that have attributes that are desirable from the perspective of a CSP application, such as the ability to accommodate dry cooling and achieve greater than 50% efficiency, as specified for the U.S. Department of Energy SunShot goal. Recompression cycles combined with intercooling and/or turbine reheat appear able to hit this efficiency target, even when combined with dry cooling. In addition, the intercooled cycles expand the temperature differential across the primary heat exchanger, which is favorable for CSP systems featuring sensible-heat thermal energy storage.

Due to forward scattering of direct sunlight in the atmosphere, the circumsolar region closely surrounding the solar disk looks very bright. The radiation coming from this region, the circumsolar radiation, is in large part included in common direct normal irradiance (DNI) measurements, but only partially intercepted by the receivers of focusing collectors. This effect has to be considered in the performance analysis of concentrating collectors in order to avoid overestimation of the intercepted irradiance. At times, the overestimation reaches more than 10% for highly concentrating systems even for sky conditions with relevant DNI above 200 W/m2. The amount of circumsolar radiation varies strongly with time, location and sky conditions. However, no representative sunshape measurements exist for locations that are now of particular interest for concentrating solar power (CSP) or concentrating photovoltaics (CPV). A new sunshape measurement system is developed and analyzed in this study. The system consists of the sun and aureole measurement instrument (SAM), an AERONET sun photometer and postprocessing software. A measurement network is being created with the presented system. The uncertainty of this system is significantly lower than what was obtained with previous devices. In addition, the spectral optical properties of circumsolar radiation are determined. As a result, the necessary information for CSP and CPV systems, and a basis for the development of modeling methods for circumsolar radiation, can now be achieved.

The present work demonstrates the feasibility of a t-C{sub 4}F{sub 9}I iodine gas laser pumped by concentrated terrestrial solar radiation. Iodine gas lasers have advantages when compared to solid-state systems. They pump at low concentration ({approximately}100 suns, as compared to 45,000 suns for the most efficient solid-state lasers; Cooke, 1992), and thus do not require expensive, optical-grade concentration systems. The lasant medium (iodine gas) is easily cooled by flowing the lasant medium, while solid-state lasers require complicated cooling apparatus to avoid crystal fracture from thermal gradients. Finally, a gas laser is easily upsized, as the iodine gas will expand to fill any oscillation cavity. Solid-state lasers are limited by the size of the crystal that can be grown and cooled, and the higher efficiency comes at the cost of the very high solar concentration requirements. The iodine gas under consideration has a smaller overlap with the terrestrial solar spectrum than solid state lasers, and therefore has a lower efficiency. However, comparison of relative efficiencies should also include cost estimates of highly specialized optical equipment (such as sapphire CPC`s), cooling requirements (liquid nitrogen baths), and losses due to blockage of the chopper wheel. Such simplistic comparisons as ratio of power outmore » to solar power in are misleading, as they contain the implicit assumption that solar energy must be purchased, as are fossil fuels. In reality, the solar energy is free, and the true expense is the manufacture and degree of sophistication required of the solar radiation reflection system, and the cooling system.« less

Direct steam generation (DSG) in parabolic troughs was first studied in the early 1980s by Murphy (1982) and Pederson (1982). Intensive research on DSG then started in 1988, when Luz identified this technology as the desired system for a future generation of its power plants. These R and D activities were not terminated by Luz`s demise in 1991, but have been continued by several institutes and companies in Europe as well as in Israel (Dagan et al., 1991, Mueller et al., 1992a, b, 1993, 1994). This paper concerns the dynamic reaction of the water-steam flow. In order to investigate this, a numerical simulation program of the water-steam flow. In order to investigate this, a numerical simulation program was developed at the ZSW. The numerical approach, its verification, and results of an extended study concerning the reaction and the control (ability) of a once-through DSG system at different weather conditions are presented.

The operational conditions of the solar-thermal receiver for a Brayton cycle engine are challenging, and lack a large body of operational data unlike steam plants. We explore the receiver's fundamental element, a pressurized tube in time varying solar flux for a series of 30 yr service missions based on hypothetical power plant designs. We developed and compared two estimation methods to predict the receiver tube lifetime based on available creep life and fatigue data for alloy 617. We show that the choice of inelastic strain model and the level of conservatism applied through design rules will vary the lifetime predictions by orders of magnitude. Based on current data and methods, a turbine inlet temperature of 1120 K is a necessary 30-yr-life-design condition for our receiver. We also showed that even though the time at operating temperature is about three times longer for fossil fuel powered (steady) operation, the damage is always lower than cyclic operation using solar power.

The molten salt pump and valve (P&V) test loops at Sandia National Laboratories (SNL) National Solar Thermal Test Facility (NSTTF) operated between Jan. 1988 and Oct. 1990. The purpose of the P&V test was to demonstrate the performance, reliability, and service life of full-scale hot and cold salt pumps and valves for use in commercial central receiver solar power plants. The P&V test hardware consists of two pumped loops; the “Hot Loop” to simulate the hot (565°C) side of the receiver and the “Cold Loop” to simulate the receiver’s cold (285°C) side. Each loop contains a pump and five valves sized to be representative of a conceptual 60-MWe commercial solar power plant design. The hot loop accumulated over 6700 hours of operation and the cold loop over 2500 hours of operation. This project has demonstrated that standard commercial scale pump and valve designs will work in molten salt. The test also exposed some pitfalls that must be avoided in specifying such equipment. Although certainly not all of the pitfalls were discovered, careful design and specification should result in reliable or at least workable equipment.