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Dr. Lisa Branchini
Department of Industrial Engineering, University of Bologna, Viale del Risorgimento, 2, 40136, Bologna, Italy

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Research Keywords & Expertise

0 LNG
0 Smart Grids
0 District Heating and Cooling
0 Energy systems optimization
0 Renewable energy and storage

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Renewable energy and storage
District Heating and Cooling
LNG

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Research article
Published: 29 July 2021 in Journal of Engineering for Gas Turbines and Power
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The huge amount of discharged heat from industrial gas turbines could be profitably recovered in bottoming cycles, producing electric power to help satisfying the industrial process energy demand. The present work aims at systematically evaluating thermodynamic performance of ORC and supercritical CO2 energy systems as bottomer cycles of different small/medium size industrial gas turbine models, with different power rating. The Thermoflex software, providing the GT PRO gas turbine library, has been used to model the machines performance. ORC and CO2 systems specifics have been chosen in line with industrial products, experience and technological limits. In the case of pure electric production, the results highlight that the ORC configuration shows the highest plant net electric efficiency. The average increment in the overall net electric efficiency is promising for both the configurations (7 and 11 percentage points, respectively if considering supercritical CO2 or ORC as bottoming solution). Concerning the cogenerative performance, the CO2 system exhibits at the same time higher electric efficiency and thermal efficiency, if compared to ORC system, being equal the installed topper gas turbine model. The ORC scarce performance is due to the high condensing pressure, imposed by the temperature required by the thermal user. CO2 configuration presents instead very good cogenerative performance with thermal efficiency comprehended between 35 % and 46 % and the PES value range between 10 % and 22 %. Finally, analyzing the relationship between capital cost and components size, it is estimated that the ORC configuration could introduce an economical saving with respect to the CO2 configuration.

ACS Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Noemi Torricelli. A Comparison Between ORC and Supercritical CO2 Bottoming Cycles for Energy Recovery From Industrial Gas Turbines Exhaust Gas. Journal of Engineering for Gas Turbines and Power 2021, 1 .

AMA Style

Maria Alessandra Ancona, Michele Bianchi, Lisa Branchini, Andrea De Pascale, Francesco Melino, Antonio Peretto, Noemi Torricelli. A Comparison Between ORC and Supercritical CO2 Bottoming Cycles for Energy Recovery From Industrial Gas Turbines Exhaust Gas. Journal of Engineering for Gas Turbines and Power. 2021; ():1.

Chicago/Turabian Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Noemi Torricelli. 2021. "A Comparison Between ORC and Supercritical CO2 Bottoming Cycles for Energy Recovery From Industrial Gas Turbines Exhaust Gas." Journal of Engineering for Gas Turbines and Power , no. : 1.

Preprint content
Published: 16 July 2021
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ACS Style

Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Noemi Torricelli; Rainer Kurz; Daniel Sanchez; Nicola Rossetti; Tommaso Ferrari. Optimal Load Allocation of Compressors Drivers Taking Advantage of Organic Rankine Cycle As WHR Solution. 2021, 1 .

AMA Style

Michele Bianchi, Lisa Branchini, Andrea De Pascale, Francesco Melino, Antonio Peretto, Noemi Torricelli, Rainer Kurz, Daniel Sanchez, Nicola Rossetti, Tommaso Ferrari. Optimal Load Allocation of Compressors Drivers Taking Advantage of Organic Rankine Cycle As WHR Solution. . 2021; ():1.

Chicago/Turabian Style

Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Noemi Torricelli; Rainer Kurz; Daniel Sanchez; Nicola Rossetti; Tommaso Ferrari. 2021. "Optimal Load Allocation of Compressors Drivers Taking Advantage of Organic Rankine Cycle As WHR Solution." , no. : 1.

Preprint content
Published: 16 July 2021
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ACS Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Jessica Rosati. Complex Energy Networks Optimization: Part II \u2013\u2014 Software Application to a Case Study. 2021, 1 .

AMA Style

Maria Alessandra Ancona, Michele Bianchi, Lisa Branchini, Andrea De Pascale, Francesco Melino, Antonio Peretto, Jessica Rosati. Complex Energy Networks Optimization: Part II \u2013\u2014 Software Application to a Case Study. . 2021; ():1.

Chicago/Turabian Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Jessica Rosati. 2021. "Complex Energy Networks Optimization: Part II \u2013\u2014 Software Application to a Case Study." , no. : 1.

Preprint content
Published: 16 July 2021
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ACS Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Jessica Rosati. Complex Energy Networks Optimization: Part I \u2014 Development and Validation of a Software for Optimal Load Allocation. 2021, 1 .

AMA Style

Maria Alessandra Ancona, Michele Bianchi, Lisa Branchini, Andrea De Pascale, Francesco Melino, Antonio Peretto, Jessica Rosati. Complex Energy Networks Optimization: Part I \u2014 Development and Validation of a Software for Optimal Load Allocation. . 2021; ():1.

Chicago/Turabian Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Jessica Rosati. 2021. "Complex Energy Networks Optimization: Part I \u2014 Development and Validation of a Software for Optimal Load Allocation." , no. : 1.

Journal article
Published: 09 June 2021 in Energies
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Gas turbine power plants are widely employed with constrained efficiency in the industrial field, where they often work under variable load conditions caused by variations in demand, leading to fluctuating exhaust gas temperatures. Suitable energy harvesting solutions can be identified in bottoming cycles, such as the conventional Organic Rankine Cycles (ORC) or the innovative supercritical CO2 (s-CO2) systems. This paper presents a detailed comparison of the potential of ORC and s-CO2 as bottomers of industrial gas turbines in a Combined Heat and Power (CHP) configuration. Different gas turbine models, covering the typical industrial size range, are taken into account and both full- and part-load operations are considered. Performance, component dimensions, and operating costs are investigated, considering ORC and s-CO2 systems specifics in line with the current state-of-the-art products, experience, and technological limits. Results of the study show that the s-CO2 could be more appropriate for CHP applications. Both the electric and thermal efficiency of s-CO2 bottoming cycle show higher values compared with ORC, also due to the fact that in the examined s-CO2 solution, the cycle pressure ratio is not affected by the thermal user temperature. At part-load operation, the gas turbine regulation strategy affects the energy harvesting performance in a CHP arrangement. The estimated total plant investment cost results to be higher for the s-CO2, caused by the higher size of the heat recovery heat exchanger but also by the high specific investment cost still associated to this component. This point seems to make the s-CO2 not profitable as the ORC solution for industrial gas turbine heat recovery applications. Nevertheless, a crucial parameter determining the feasibility of the investment is the prospective carbon tax application.

ACS Style

Maria Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Noemi Torricelli. Systematic Comparison of ORC and s-CO2 Combined Heat and Power Plants for Energy Harvesting in Industrial Gas Turbines. Energies 2021, 14, 3402 .

AMA Style

Maria Ancona, Michele Bianchi, Lisa Branchini, Andrea De Pascale, Francesco Melino, Antonio Peretto, Noemi Torricelli. Systematic Comparison of ORC and s-CO2 Combined Heat and Power Plants for Energy Harvesting in Industrial Gas Turbines. Energies. 2021; 14 (12):3402.

Chicago/Turabian Style

Maria Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Noemi Torricelli. 2021. "Systematic Comparison of ORC and s-CO2 Combined Heat and Power Plants for Energy Harvesting in Industrial Gas Turbines." Energies 14, no. 12: 3402.

Journal article
Published: 03 April 2021 in Sustainability
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Ceramic tile production is an industrial process where energy efficiency management is crucial, given the high amount of energy (electrical and thermal) required by the production cycle. This study presents the preliminary results of a research project aimed at defining the benefits of using combined heat and power (CHP) systems in the ceramic sector. Data collected from ten CHP installations allowed us to outline the average characteristics of prime movers, and to quantify the contribution of CHP thermal energy supporting the dryer process. The electric size of the installed CHP units resulted in being between 3.4 MW and 4.9 MW, with an average value of 4 MW. Data revealed that when the goal is to maximize the generation of electricity for self-consumption, internal combustion engines are the preferred choice due to higher conversion efficiency. In contrast, gas turbines allowed us to minimize the consumption of natural gas input to the spray dryer. Indeed, the fraction of the dryer thermal demand (between 600–950 kcal/kgH2O), covered by CHP discharged heat, is strictly dependent on the type of prime mover installed: lower values, in the range of 30–45%, are characteristic of combustion engines, whereas the use of gas turbines can contribute up to 77% of the process’s total consumption.

ACS Style

Lisa Branchini; Maria Bignozzi; Benedetta Ferrari; Barbara Mazzanti; Saverio Ottaviano; Marcello Salvio; Claudia Toro; Fabrizio Martini; Andrea Canetti. Cogeneration Supporting the Energy Transition in the Italian Ceramic Tile Industry. Sustainability 2021, 13, 4006 .

AMA Style

Lisa Branchini, Maria Bignozzi, Benedetta Ferrari, Barbara Mazzanti, Saverio Ottaviano, Marcello Salvio, Claudia Toro, Fabrizio Martini, Andrea Canetti. Cogeneration Supporting the Energy Transition in the Italian Ceramic Tile Industry. Sustainability. 2021; 13 (7):4006.

Chicago/Turabian Style

Lisa Branchini; Maria Bignozzi; Benedetta Ferrari; Barbara Mazzanti; Saverio Ottaviano; Marcello Salvio; Claudia Toro; Fabrizio Martini; Andrea Canetti. 2021. "Cogeneration Supporting the Energy Transition in the Italian Ceramic Tile Industry." Sustainability 13, no. 7: 4006.

Journal article
Published: 24 February 2021 in Journal of Engineering for Gas Turbines and Power
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In order to increase the exploitation of the renewable energy sources, the diffusion of the distributed generation systems is grown, leading to an increase in the complexity of the electrical, thermal, cooling, and fuel energy distribution networks. With the main purpose of improving the overall energy conversion efficiency and reducing the greenhouse gas emissions associated with fossil fuel based production systems, the design and the management of these complex energy grids play a key role. In this context, an in-house developed software, called COMBO, presented and validated in Part I of this study, has been applied to a case study in order to define the optimal scheduling of each generation system connected to a complex energy network. The software is based on a nonheuristic technique, which considers all the possible combination of solutions, elaborating the optimal scheduling for each energy system by minimizing an objective function based on the evaluation of the total energy production cost and energy systems' environmental impact. In particular, the software COMBO is applied to a case study represented by an existing small-scale complex energy network, with the main objective of optimizing the energy production mix and the complex energy networks yearly operation depending on the energy demand of the users. The electrical, thermal, and cooling needs of the users are satisfied with a centralized energy production, by means of internal combustion engines, natural gas boilers, heat pumps, compression, and absorption chillers. The optimal energy systems' operation evaluated by the software COMBO will be compared to a reference case, representative of the current energy systems setup, in order to highlight the environmental and economic benefits achievable with the proposed strategy.

ACS Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Jessica Rosati. Complex Energy Networks Optimization: Part II—Software Application to a Case Study. Journal of Engineering for Gas Turbines and Power 2021, 143, 1 .

AMA Style

Maria Alessandra Ancona, Michele Bianchi, Lisa Branchini, Andrea De Pascale, Francesco Melino, Antonio Peretto, Jessica Rosati. Complex Energy Networks Optimization: Part II—Software Application to a Case Study. Journal of Engineering for Gas Turbines and Power. 2021; 143 (4):1.

Chicago/Turabian Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Jessica Rosati. 2021. "Complex Energy Networks Optimization: Part II—Software Application to a Case Study." Journal of Engineering for Gas Turbines and Power 143, no. 4: 1.

Journal article
Published: 22 February 2021 in Journal of Engineering for Gas Turbines and Power
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The growing diffusion of the distributed generation systems, due to the European and national legislations which impose the fossil fuel and greenhouse gas emissions reduction and the renewable sources exploitation, have led to an increase in the complexity of the existing energy networks. The main issue of the complex energy grids is their management, which consists in the resolution and optimization of the load allocation problem by minimizing the primary energy consumption and, thus, improving the overall efficiency. In this context, the aim of this paper is to develop and validate a nonlinear algorithm suitable for the resolution of the load allocation problem. In detail, the software combo, which has been developed by the University of Bologna, is based on a nonheuristic algorithm and allows to optimize a complex energy network—characterized by electrical, thermal, cooling and fuel fluxes—by evaluating all the possible combinations of solutions. The objective function of the software consists in the minimization of the total cost of energy production, including not only the variable costs, but also the costs related to the environmental impact of the energy systems. In this paper the mathematical model of the algorithm at the basis of the software combo is presented and described in detail. Furthermore, the software has been validated by its application to a case study and comparing the results with the ones obtained with a previously developed software based on a genetic algorithm (heuristic nonlinear method).

ACS Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Jessica Rosati. Complex Energy Networks Optimization: Part I—Development and Validation of a Software for Optimal Load Allocation. Journal of Engineering for Gas Turbines and Power 2021, 143, 1 .

AMA Style

Maria Alessandra Ancona, Michele Bianchi, Lisa Branchini, Andrea De Pascale, Francesco Melino, Antonio Peretto, Jessica Rosati. Complex Energy Networks Optimization: Part I—Development and Validation of a Software for Optimal Load Allocation. Journal of Engineering for Gas Turbines and Power. 2021; 143 (4):1.

Chicago/Turabian Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Antonio Peretto; Jessica Rosati. 2021. "Complex Energy Networks Optimization: Part I—Development and Validation of a Software for Optimal Load Allocation." Journal of Engineering for Gas Turbines and Power 143, no. 4: 1.

Journal article
Published: 27 June 2020 in Energy
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In this study, low-GWP fluids (R1234yf and R1234ze(E)) have been compared with R134a when used in a kW-size reciprocating piston expander. Semi-empirical models of the pump and the expander are employed to analyze how the different fluids thermodynamic characteristics could influence machines behavior into real operation of a micro-ORC. Parameters related to thermo-fluid-dynamic properties are updated compared to the original values calibrated over R134a. Results show that the use of HFOs alternative fluids leads to a loss of electric power and expander efficiency, whose detriment depends on fluids properties and on operation strategy. At a given pressure ratio the decrease of power output is close to 21% and 42%, while the loss on expander efficiency is more limited, being around 6% and 11%, for R1234yf and for R1234ze(E), respectively. Main factors of influence such as saturation pressure, viscosity, heat transfer coefficients and vapour density are discussed. The expander model has also been used to perform the optimization of the built-in volume ratio for each fluid, revealing that a significant enhancement of the expander overall performance could be obtained modifying the intake valve timing, thus reducing under-expansion losses and improving its volumetric efficiency.

ACS Style

M. Bianchi; L. Branchini; A. De Pascale; F. Melino; S. Ottaviano; A. Peretto; N. Torricelli. Replacement of R134a with low-GWP fluids in a kW-size reciprocating piston expander: Performance prediction and design optimization. Energy 2020, 206, 118174 .

AMA Style

M. Bianchi, L. Branchini, A. De Pascale, F. Melino, S. Ottaviano, A. Peretto, N. Torricelli. Replacement of R134a with low-GWP fluids in a kW-size reciprocating piston expander: Performance prediction and design optimization. Energy. 2020; 206 ():118174.

Chicago/Turabian Style

M. Bianchi; L. Branchini; A. De Pascale; F. Melino; S. Ottaviano; A. Peretto; N. Torricelli. 2020. "Replacement of R134a with low-GWP fluids in a kW-size reciprocating piston expander: Performance prediction and design optimization." Energy 206, no. : 118174.

Journal article
Published: 21 March 2020 in Energy Conversion and Management
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In this study, the off-design performance of a Power-to-Gas process are predicted by means of a developed calculation model, implemented in commercial tool environments. With the aim to evaluate the behaviour of the several components in off-design conditions, specific calculation models have been integrated in the whole system model. Then, starting from a real wind production profile, four configurations of the Power-to-Gas system have been analysed, evaluating the annual operating time of the integrated Power-to-Gas/wind systems. In addition, in order to assess the cost effectiveness of the technology, a preliminary economic analysis has been performed. The results highlight that the most performant configuration is the one at ambient pressure, with the co-electrolyzer and the high temperature methanation section operating at the same temperature, showing a methane production of 184 ton/year and an overall efficiency of about 75%. At the current technology readiness level, the economic competitiveness of the process is strongly affected by the synthetic natural gas sell price.

ACS Style

M.A. Ancona; M. Bianchi; L. Branchini; F. Catena; A. De Pascale; F. Melino; A. Peretto. Numerical prediction of off-design performance for a Power-to-Gas system coupled with renewables. Energy Conversion and Management 2020, 210, 112702 .

AMA Style

M.A. Ancona, M. Bianchi, L. Branchini, F. Catena, A. De Pascale, F. Melino, A. Peretto. Numerical prediction of off-design performance for a Power-to-Gas system coupled with renewables. Energy Conversion and Management. 2020; 210 ():112702.

Chicago/Turabian Style

M.A. Ancona; M. Bianchi; L. Branchini; F. Catena; A. De Pascale; F. Melino; A. Peretto. 2020. "Numerical prediction of off-design performance for a Power-to-Gas system coupled with renewables." Energy Conversion and Management 210, no. : 112702.

Journal article
Published: 12 March 2020 in Energies
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Improvement of energy conversion efficiency in prime movers has become of fundamental importance in order to respect EU 2020 targets. In this context, hybrid power plants comprising combined heat and power (CHP) prime movers integrated with the organic Rankine cycle (ORC) create interesting opportunities to additionally increase the first law efficiency and flexibility of the system. The possibility of adding supplementary electric energy production to a CHP system, by converting the prime movers’ exhaust heat with an ORC, was investigated. The inclusion of the ORC allowed operating the prime movers at full-load (thus at their maximum efficiency), regardless of the heat demand, without dissipating not required high enthalpy-heat. Indeed, discharged heat was recovered by the ORC to produce additional electric power at high efficiency. The CHP plant in its original arrangement (comprising three internal combustion engines of 8.5 MW size each) was compared to a new one, involving an ORC, assuming three different layout configurations and thus different ORC off-design working conditions at user thermal part-load operation. Results showed that the performance of the ORC, on the year basis, strongly depended on its part-load behavior and on its regulation limits. Indeed, the layout that allowed to produce the maximum amount of ORC electric energy per year (about 10 GWh/year) was the one that could operate for the greatest number of hours during the year, which was different from the one that exhibited the highest ORC design power. However, energetic analysis demonstrated that all the proposed solutions granted to reduce the global primary energy consumption of about 18%, and they all proved to be a good investment since they allowed to return on the investment in barely 5 years, by selling the electric energy at a minimum price equal to 70 EUR/MWh.

ACS Style

Lisa Branchini; Andrea De Pascale; Francesco Melino; Noemi Torricelli. Optimum Organic Rankine Cycle Design for the Application in a CHP Unit Feeding a District Heating Network. Energies 2020, 13, 1314 .

AMA Style

Lisa Branchini, Andrea De Pascale, Francesco Melino, Noemi Torricelli. Optimum Organic Rankine Cycle Design for the Application in a CHP Unit Feeding a District Heating Network. Energies. 2020; 13 (6):1314.

Chicago/Turabian Style

Lisa Branchini; Andrea De Pascale; Francesco Melino; Noemi Torricelli. 2020. "Optimum Organic Rankine Cycle Design for the Application in a CHP Unit Feeding a District Heating Network." Energies 13, no. 6: 1314.

Journal article
Published: 22 January 2020 in Applied Sciences
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The liquefied natural gas (LNG) is considered a viable solution to replace oil-based engines (common in heavy-duty truck and naval industry) reducing the environmental impact in the transport sector. Since liquefaction plants represent energy intensive processes, the best configurations/operation assessment is of primary importance. In this paper, a novel general procedure for the thermodynamic design and optimization, engineering design and off-design evaluation for small-scale LNG production systems is presented. The procedure can be used for the complete design and performance evaluation of plug & play facilities at filling stations for vehicles/boats, with the contemporary benefits of reducing pollutant emission in the city/port area and operating as electrical storage, coupled with renewable generators. Furthermore, the procedure has been applied to a case study (ferry boat operating at the main canal in the port of Ravenna, Italy), evaluating the optimal size for the integrated wind plant by minimizing the electricity introduction into the grid. The obtained results show 78 kW as optimal wind size, allowing the LNG plant to operate 187 h/year in design and 4720 h/year in off-design conditions, with electricity surplus around 33 MWh/year. A prototype will be installed to reduce pollutant emissions and test this technology as a storage option for renewable sources.

ACS Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Francesco Catena; Andrea De Pascale; Francesco Melino; Saverio Ottaviano; Antonio Peretto. Overall Performance Evaluation of Small Scale LNG Production Processes. Applied Sciences 2020, 10, 785 .

AMA Style

Maria Alessandra Ancona, Michele Bianchi, Lisa Branchini, Francesco Catena, Andrea De Pascale, Francesco Melino, Saverio Ottaviano, Antonio Peretto. Overall Performance Evaluation of Small Scale LNG Production Processes. Applied Sciences. 2020; 10 (3):785.

Chicago/Turabian Style

Maria Alessandra Ancona; Michele Bianchi; Lisa Branchini; Francesco Catena; Andrea De Pascale; Francesco Melino; Saverio Ottaviano; Antonio Peretto. 2020. "Overall Performance Evaluation of Small Scale LNG Production Processes." Applied Sciences 10, no. 3: 785.

Journal article
Published: 03 May 2019 in Applied Energy
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This work describes modeling and performance prediction of a kW-size reciprocating piston expander adopted in micro-Organic Rankine Cycle (ORC) energy systems. Two selected semi-empirical models have been opportunely adapted, calibrated and validated over a full set of experimental data to detect the best method for the simulation of a reciprocating machine. The first modelling approach is based on polynomial correlations of the expander efficiencies and it has been extended to account for the heat losses to ambient. The second one is a lumped parameters model using few key geometrical data and some physical equations to describe the process. Within the calibration range, the considered models show similar performance results of the output variables: the lowest mean relative error value is obtained on the prediction of exhaust temperature (lower than 2%). Maximum relative errors are obtained in the evaluation of rotational speed for the polynomial fitting model (equal to 10%) and in the electric power output for the lumped parameters approach (equal to 8%). The global error function value is close to 5% for both the applied approaches. Conversely, when compared outside of the calibration range, the polynomial fitting functions model proves to be less accurate overestimating the expander rotational speed while underestimating the value of the filling factor at high pressure ratios, and overestimating the isentropic efficiency at low pressure ratios.

ACS Style

M. Bianchi; L. Branchini; A. De Pascale; F. Melino; S. Ottaviano; A. Peretto; N. Torricelli. Application and comparison of semi-empirical models for performance prediction of a kW-size reciprocating piston expander. Applied Energy 2019, 249, 143 -156.

AMA Style

M. Bianchi, L. Branchini, A. De Pascale, F. Melino, S. Ottaviano, A. Peretto, N. Torricelli. Application and comparison of semi-empirical models for performance prediction of a kW-size reciprocating piston expander. Applied Energy. 2019; 249 ():143-156.

Chicago/Turabian Style

M. Bianchi; L. Branchini; A. De Pascale; F. Melino; S. Ottaviano; A. Peretto; N. Torricelli. 2019. "Application and comparison of semi-empirical models for performance prediction of a kW-size reciprocating piston expander." Applied Energy 249, no. : 143-156.

Journal article
Published: 01 March 2019 in Energy Conversion and Management
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Performance of an innovative storage system for renewable energy, based on the Power-to-Gas concept are numerically predicted. The investigated system is composed by a high temperature co-electrolyzer of Solid Oxide Electrolyte Cell technology and an experimental methanation section, based on structured catalyst, suitable for high temperature operation. With the aim to thermally integrate high temperature co-electrolysis and methanation, a parametric thermodynamic analysis of the Power-to-Gas system is carried-out with a lumped-parameters approach, including all the thermal and electric energy consumptions. In particular, in order to optimize the system thermal balance of plant, various configurations involving internal heat recovery and pressurization of components are also considered. Numerical results are provided in terms of different performance indicators, such as electric-to-fuel conversion index, first law efficiency and second law efficiency and output-fuel quality indicators. The study demonstrates the possibility to thermally integrate the co-electrolyzer and the high-temperature methanation section achieving significant energy savings. Moreover, the calculated results show that the system set-up providing higher quality of the produced synthetic natural gas do not always lead to larger values in energy conversion efficiency. Eventually, advanced configurations of the Power-to-Gas system including heat recovery allow to achieve first-law efficiency up to values around 80–85% and second-law efficiency around 70–78%; a second methanation section based on conventional low-temperature reactors is included in the system and pressurization of the methanation section, or pressurization of the co-electrolysis section, is mandatory, in order to achieve large fraction of methane (up to 95–99%) in the produced synthetic fuel.

ACS Style

M.A. Ancona; V. Antonucci; L. Branchini; F. Catena; A. De Pascale; Alessandra DI Blasi; M. Ferraro; C. Italiano; F. Melino; A. Vita. Thermal integration of a high-temperature co-electrolyzer and experimental methanator for Power-to-Gas energy storage system. Energy Conversion and Management 2019, 186, 140 -155.

AMA Style

M.A. Ancona, V. Antonucci, L. Branchini, F. Catena, A. De Pascale, Alessandra DI Blasi, M. Ferraro, C. Italiano, F. Melino, A. Vita. Thermal integration of a high-temperature co-electrolyzer and experimental methanator for Power-to-Gas energy storage system. Energy Conversion and Management. 2019; 186 ():140-155.

Chicago/Turabian Style

M.A. Ancona; V. Antonucci; L. Branchini; F. Catena; A. De Pascale; Alessandra DI Blasi; M. Ferraro; C. Italiano; F. Melino; A. Vita. 2019. "Thermal integration of a high-temperature co-electrolyzer and experimental methanator for Power-to-Gas energy storage system." Energy Conversion and Management 186, no. : 140-155.

Journal article
Published: 25 January 2019 in Energy
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Natural gas compressor stations represent a huge potential in terms of waste heat recovery. Typical installations consist of multiple gas turbine units, in mechanical drive arrangement, operated most of the time under part-load conditions. The paper investigates the feasibility of Organic Rankine Cycle application as bottomer recovery technology in natural gas compressor facilities. The aim of the performed analysis is to obtain a detailed techno-economic and environmental scenario of the integrated system on yearly base. Different commercial gas turbine models, in the size range from 3 to 30 MW, have been taken into account as representative of mechanical driver units. Bottomer configurations (with & without intermediate loop) are modelled and compared assuming two different organic fluids. A sensitivity analysis of the bottomer cycle is carried out aimed at maximizing ORC shaft power output for each investigated layout. Off-design part-load operation of the integrated cycles have been simulated with reference to one minute data typical GT operation on a yearly base. The goal of this work is: (i) to assess the actual performance of merging gas turbines and ORC units for efficient power generation under variable operating conditions; (ii) to analyze the real potential of state-of-the art technology in the proposed innovative application.

ACS Style

M. Bianchi; L. Branchini; A. De Pascale; F. Melino; A. Peretto; D. Archetti; F. Campana; T. Ferrari; N. Rossetti. Feasibility of ORC application in natural gas compressor stations. Energy 2019, 173, 1 -15.

AMA Style

M. Bianchi, L. Branchini, A. De Pascale, F. Melino, A. Peretto, D. Archetti, F. Campana, T. Ferrari, N. Rossetti. Feasibility of ORC application in natural gas compressor stations. Energy. 2019; 173 ():1-15.

Chicago/Turabian Style

M. Bianchi; L. Branchini; A. De Pascale; F. Melino; A. Peretto; D. Archetti; F. Campana; T. Ferrari; N. Rossetti. 2019. "Feasibility of ORC application in natural gas compressor stations." Energy 173, no. : 1-15.

Journal article
Published: 04 December 2018 in Applied Thermal Engineering
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In this paper, a full experimental characterization of a micro-scale ORC system is presented. The facility under investigation is driven by a piston expander prototype, made of three cylinders arranged radially around the drive shaft. The system is rated for a thermal input around 30 kW, being suitable for residential, tertiary sector or small industry applications. It is conceived for exploiting low temperature heat sources, such as solar collectors, biomass boilers, geothermal energy or waste heat streams. The facility was provided with an electric boiler as heat source, which warms water up to 90 °C, and cold water at ambient temperature as heat sink. A test campaign was performed varying the hot source temperature and the organic fluid feed pump velocity, in order to characterize the system behavior at different off-design working conditions. The electric consumption of the ORC feed pump was measured, in order to quantify the actual impact of the auxiliaries on the overall efficiency. Moreover, the number of electric loads connected to the generator was varied, changing the equivalent phase impedance value, for evaluating the effect on the expander rotating speed and power output. The experimental analysis demonstrated that small reciprocating expander is suitable for exploiting low enthalpy heat sources, with quite good performances compared to other architectures like scroll and screw expanders, more applied within low temperature sources. The results show that the gross electric power output varied between 250 W and 1150 W, depending on the expander speed and on the number of electric loads activated. The expander total efficiency showed a barely constant trend around 40 %. The pump total efficiency varied between 10 % and 20 %, increasing with the pump rotational speed. The maximum ORC gross and net efficiency were 4.5 % and 2.2 % respectively, confirming that the auxiliaries impact cannot be considered negligible in such type of systems.

ACS Style

Michele Bianchi; L. Branchini; N. Casari; A. De Pascale; Francesco Melino; S. Ottaviano; M. Pinelli; P.R. Spina; Alessio Suman. Experimental analysis of a micro-ORC driven by piston expander for low-grade heat recovery. Applied Thermal Engineering 2018, 148, 1278 -1291.

AMA Style

Michele Bianchi, L. Branchini, N. Casari, A. De Pascale, Francesco Melino, S. Ottaviano, M. Pinelli, P.R. Spina, Alessio Suman. Experimental analysis of a micro-ORC driven by piston expander for low-grade heat recovery. Applied Thermal Engineering. 2018; 148 ():1278-1291.

Chicago/Turabian Style

Michele Bianchi; L. Branchini; N. Casari; A. De Pascale; Francesco Melino; S. Ottaviano; M. Pinelli; P.R. Spina; Alessio Suman. 2018. "Experimental analysis of a micro-ORC driven by piston expander for low-grade heat recovery." Applied Thermal Engineering 148, no. : 1278-1291.

Journal article
Published: 24 July 2017 in International Journal of Hydrogen Energy
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Issues of exhaustible natural resources, fluctuating fossil fuel prices and improvements in electric power systems motivated governments to behave positively toward the development of distributed generation. In addition, progresses in small size generation technologies and storage systems give rise to a significant diffusion in microgrids, working together with conventional power grid. Indeed, in the next future, domestic microgrids are expected to play a fundamental role in electric power networks, driving both the academic and industrial research interests in developing high efficient and reliable conversion and storage technologies. In this context, this study presents a feasible configuration of a solar-hydrogen integrated microgrid and documents the procedure to characterize the overall efficiency of a laboratory scale test facility. Experimental results highlight that the most significant inefficiencies in the solar to hydrogen conversion process are mainly attributed to the solar to electrical energy conversion process, being responsible for about 89% of losses. The overall laboratory scale solar to hydrogen chain can reach conversion efficiency up to 5.3%.

ACS Style

M.A. Ancona; M. Bianchi; L. Branchini; A. De Pascale; F. Melino; A. Peretto; J. Rosati; L.B. Scarponi. From solar to hydrogen: Preliminary experimental investigation on a small scale facility. International Journal of Hydrogen Energy 2017, 42, 20979 -20993.

AMA Style

M.A. Ancona, M. Bianchi, L. Branchini, A. De Pascale, F. Melino, A. Peretto, J. Rosati, L.B. Scarponi. From solar to hydrogen: Preliminary experimental investigation on a small scale facility. International Journal of Hydrogen Energy. 2017; 42 (33):20979-20993.

Chicago/Turabian Style

M.A. Ancona; M. Bianchi; L. Branchini; A. De Pascale; F. Melino; A. Peretto; J. Rosati; L.B. Scarponi. 2017. "From solar to hydrogen: Preliminary experimental investigation on a small scale facility." International Journal of Hydrogen Energy 42, no. 33: 20979-20993.

Proceedings article
Published: 13 June 2016 in Volume 5C: Heat Transfer
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Gas Turbines (GT) are widely used for power generation in offshore oil and gas facilities, due to their high reliability, compactness and dynamic response capabilities. Small heavy duty and aeroderivative units in multiple arrangements are typically used to offer larger load flexibility, but limited efficiency of such machines is the main drawback. A solution to enhance the system performance, also in Combined Heat and Power (CHP) arrangement, is the implementation of Organic Rankine Cycle (ORC) systems at the bottom of the gas turbines. Moreover, the resulting GT-ORC combined cycle could be further integrated with additional renewable sources. Offshore wind technology is rapidly developing and floating wind turbines could be combined with offshore GT-ORC based power plants to satisfy the platform load. The pioneering stand alone power system, for an oil and gas platform, examined in this paper comprises a 10MW offshore wind farm and three gas turbines rated for 16.5MW, each one coupled with an 4.5MW ORC module. The ORC main parameters are observed under different wind power fluctuations. Due to the non-programmable availability of wind and power demand, the part-load and dynamic characteristics of the system should be investigated. A dynamic model of the power system based on first principles is used, developed in the Modelica language. The model is integrated with a time series-based model of two offshore wind mills. Various thermodynamic indexes, available in the literature, are identified and evaluated to compare the actual combined heat and power performances of single components and of the overall integrated system in the considered wind scenarios.

ACS Style

Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Valentina Orlandini; Antonio Peretto; Fredrik Haglind; Leonardo Pierobon. Cogenerative Performance of a Wind–Gas Turbine–Organic Rankine Cycle Integrated System for Offshore Applications. Volume 5C: Heat Transfer 2016, 1 .

AMA Style

Michele Bianchi, Lisa Branchini, Andrea De Pascale, Francesco Melino, Valentina Orlandini, Antonio Peretto, Fredrik Haglind, Leonardo Pierobon. Cogenerative Performance of a Wind–Gas Turbine–Organic Rankine Cycle Integrated System for Offshore Applications. Volume 5C: Heat Transfer. 2016; ():1.

Chicago/Turabian Style

Michele Bianchi; Lisa Branchini; Andrea De Pascale; Francesco Melino; Valentina Orlandini; Antonio Peretto; Fredrik Haglind; Leonardo Pierobon. 2016. "Cogenerative Performance of a Wind–Gas Turbine–Organic Rankine Cycle Integrated System for Offshore Applications." Volume 5C: Heat Transfer , no. : 1.

Journal article
Published: 19 December 2015 in Energy Procedia
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Load and wind energy profiles are totally uncorrelated, therein lies the problem of variable energy sources. Managing load with increasing wind penetration may call for operational ranges that conventional systems cannot readily access. Storage technologies could allow tolerating the unsteadiness of renewable sources with smaller fossil fuel plants capacity. Pumped Hydro Storage (PHS) is a crucial technology for balancing large steam power plants and may become increasingly important for storing renewable energies. Hence capacity ranges of PHS as well as its dynamic response to renewable power variability, will become progressively relevant. An integrated system made of a wind farm, a PHS plant and a set of gas turbines (GTs), as programmable fossil fuel devices, to handle renewable variability and maximize renewable energy exploitation, is studied in this paper. A specific case study is analyzed: a wind farm with a nameplate capacity equal to that installed in Sardinia is considered. To match the power output requested by the region with the integrated systems different configurations of PHS plant will be investigated. The impact of reversible or separate Francis machines with constant or variable speed will be analyzed in order to minimize electric power output overproduction and GTs fuel consumptions. Minimum and maximum capacity range for reversible or separate machines will be considered. The aim of the study is the optimum sizing and design of a PHS unit in a hybrid wind-hydro-gas turbine power plant to match the load request. Results in terms of PHS operation, water height behavior in upper and lower reservoirs, GT units power output, natural gas consumed and electric power output overproduction will be presented for each analyzed case.

ACS Style

M. Bianchi; Lisa Branchini; A. De Pascale; A. Peretto; F. Melino; V. Orlandini. Pump Hydro Storage and Gas Turbines Technologies Combined to Handle Wind Variability: Optimal Hydro Solution for an Italian Case Study. Energy Procedia 2015, 82, 570 -576.

AMA Style

M. Bianchi, Lisa Branchini, A. De Pascale, A. Peretto, F. Melino, V. Orlandini. Pump Hydro Storage and Gas Turbines Technologies Combined to Handle Wind Variability: Optimal Hydro Solution for an Italian Case Study. Energy Procedia. 2015; 82 ():570-576.

Chicago/Turabian Style

M. Bianchi; Lisa Branchini; A. De Pascale; A. Peretto; F. Melino; V. Orlandini. 2015. "Pump Hydro Storage and Gas Turbines Technologies Combined to Handle Wind Variability: Optimal Hydro Solution for an Italian Case Study." Energy Procedia 82, no. : 570-576.

Journal article
Published: 19 December 2015 in Energy Procedia
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The increasing penetration of low-carbon technologies and enhancements in fossil-fuelled power plants efficiency are some of the most important and up to date research topics. Renewable energy, in particular solar, has the potential of meeting the world energy needs while addressing environmental concerns, but technological advances in renewable energy electricity production are necessary to become competitive with conventional technologies. New opportunities to increase the penetration of renewables energies, smoothing out renewables variability and intermittency problems, come out from the hybridization concept. Hybrid renewable-fossil fuel systems join the advantages of both renewable energies and programmable devices. Among all the renewable technologies available for hybridization, Concentrating Solar Power (CSP) with parabolic trough is the most diffused because of its relatively conventional technology and ease of scale-up. CSP hybrids are well established worldwide, predominantly with natural gas: the hybridization options for CSP ranging from feed water heating, reheat steam, live steam to steam superheating. Based on a detailed thermodynamic cycle model of a reference small-size one pressure level Combined Cycle (CC) plant, the impact of CSP addition is thoroughly evaluated. Different hybrid schemes are evaluated and compared considering CC off-design operation. The goal of this study is to evaluate, from a thermodynamic point of view, three repowering options of a small-size CC with a CSP system in a hybrid system configuration and to quantify their potential benefits in terms of system's performance increase. In particular, the optimal size of CSP plant is shown for each investigated hybrid repowering options. The changes in CC steam cycle operating parameters are presented together with CC performance increase. It is shown that solar hybridization into an existing CC plant may give rise to a substantial benefit from a thermodynamic point of view.

ACS Style

M.A. Ancona; M. Bianchi; L. Branchini; A. De Pascale; F. Melino; A. Peretto. Thermodynamic Evaluation of Repowering Options for a Small-size Combined Cycle with Concentrating Solar Power Technology. Energy Procedia 2015, 82, 584 -590.

AMA Style

M.A. Ancona, M. Bianchi, L. Branchini, A. De Pascale, F. Melino, A. Peretto. Thermodynamic Evaluation of Repowering Options for a Small-size Combined Cycle with Concentrating Solar Power Technology. Energy Procedia. 2015; 82 ():584-590.

Chicago/Turabian Style

M.A. Ancona; M. Bianchi; L. Branchini; A. De Pascale; F. Melino; A. Peretto. 2015. "Thermodynamic Evaluation of Repowering Options for a Small-size Combined Cycle with Concentrating Solar Power Technology." Energy Procedia 82, no. : 584-590.