Gas Power Plants Research Articles

Modeling of flexible AC transmission system devices and fuzzy controller for automatic generation control of electric vehicle-injected power system

The automatic generation control (AGC) is a paradigm topic of interest that is continuously evolving for adequate power generation control in the power system. In this proposed study, a fuzzy adapted PID (FPID) controller is assigned for the AGC of the hybrid power system in various electrical risks and hazards. The hybrid power system includes traditional thermal and hydroelectric facilities along with gas and nuclear power plants. Two FACTS components, the superconducting magnetic energy storage (SMES) and the interline power flow controller (IPFC), have been included in to the system to improve stability of the system. The proposed FPID controller is developed to its full potential using the newly developed teaching learning-based optimization (TLBO) method. The TLBO technique's capability has been compared against a few common evolutionary strategies in order to demonstrate its superiority. It also shows how FPID controllers outperform traditional PID controllers. Investigations are also done on how IPFC and SMES might improve system stability performance. Owing to the outcome study, it is revealed that suggested TLBO-FPID, IPFC and SMES are most effective tool to advance the AGC mechanism. It is revealed from the outcomes that anticipated FPID controller reduces the settling time of area1 frequency (ΔF1) by 135.72 %, 428.58 % and 471.42 % over TLBO;PID, DE;PID and PSO;PI respectively. Finally, the proposed mechanisms are discussed with employing in electric vehicle integrated three-area distributed energy source-based power network to justify the efficacy of the proposed approaches.

Effects of uncontrolled combustion in a power plant gas turbine on fracture surface features and microstructural evolutions of a nickel-based superalloy blades

The present work investigates the fracture surface features and microstructural evolutions of nickel-based superalloy (Udimet 500) blades after uncontrolled combustion and overheating in a power plant gas turbine. In normal operation of the turbine, flameout occurred, but fuel continued to flow to hot section of turbine. The injected fuel failed to ignite as intended, but combusted upon contact with hot surfaces, including blades and the exhaust duct. This led to an explosion and the turbine failed after 753 equivalent operating hours (EOH) in normal operation. The majority of the damage was in the second-stage blades, primarily due to their proximity to the exhaust duct. The explosion in the exhaust duct led to the dynamic fracture of the second-stage blades and an increase in temperature, which caused the microstructural degradation of the airfoil part of the blades. The microstructure of the blades was investigated by an optical microscope (OM), a field-emission scanning electron microscope (FE-SEM) and energy-dispersive X-ray spectroscopy (EDS). The results revealed that the most of microstructure deterioration of the blades occurred in the airfoil of the blades and the microstructure of the root of the blades did not deteriorated since the airfoil experienced a higher temperature in comparison with the root. The degeneration of MC carbide to M23C6 carbide was observed at the airfoil grain boundaries, where M represents Cr and Mo. Furthermore, the morphology of γ' precipitates in the airfoil changed to cauliflower-morphology by growing and splitting mechanisms. The spalling nature of the fracture surface suggested that the dynamic fracture, which is produced by interaction between shock waves, as well as occurred. The failure of gas turbine blades was a consequence of uncontrolled combustion in the turbine section, leading to dynamic fracture and deterioration of the microstructure in the airfoil parts of the blades.

Proposal and simulation of a geothermal-driven water electrolysis unit integrated with a CO2 methanation process toward a novel sustainable framework

This paper presents a novel multigeneration structure powered by geothermal energy, featuring a geothermal power plant, water electrolyzer unit, methanation reactor, fuel and utility production unit, supercritical-carbon dioxide cycle, and both high-temperature and low-temperature organic Rankine cycles. Simulated in Aspen HYSYS software and analyzed from energy, exergy, economic, and environmental (4E) perspectives, the process, under base operating conditions, is capable of producing 20,940 kW of power, 620.70 kg/h of hydrogen, 4,913 kg/h of oxygen, 12.35 kg/s of domestic hot water, 5.293 kg/s of chilled water, and 2.659 kg/s of carbon dioxide with over 99% mole purity. Efficiency assessments reveal energy, exergy, and electrical efficiencies of 10.69%, 48.53%, and 3.73%, respectively, with a total unit product cost of $3.11/GJ and a net present value of $67.40 million. The water electrolyzer unit, with an 88.94% exergy efficiency and a 10% contribution to total system irreversibility, is identified as the most efficient subsystem. The geothermal power plant accounts for the highest system irreversibility at 61%, while the combustor in the fuel and utility production unit contributes 11,250 kW of irreversibility. Environmentally, the system operates with zero emissions and significantly reduces annual CO2 emissions compared to coal, oil, biomass, and natural gas power plants by 453.14 × 106, 576.80 × 106, 111.92 × 106, and 344.10 × 106 kg, respectively.

Kajian Teknis Dan Finansial Interkoneksi Pembangkit Listrik Tenaga Biogas Dari Palm Oil Mill Effluent (POME) Pada Sistem 20 KV Di Kabupaten Musi Rawas

Using renewable energy is one way to reduce global warming. Minister of Energy and Mineral Resources Regulation No. 21 of 2016 concerning Purchase of Electricity and Biogas Power. The government has supported efforts to develop electrical energy from biogas. PT Evans Lestari is an oil palm plantation company operating in Mura with a plantation area of 9,220 ha and a mill of 60 tons/hour. In order to fulfill PLN's requirements to offer electricity supply, it is necessary to carry out a technical assessment of the connection and an economic analysis. The connection of the EBT PLT to PLN's 20 kV distribution system has been regulated in Directors' Decree No. 0357.K/DIR/2014. The benefits obtained from using DG include reducing power losses and improving the voltage profile of the distribution system. Among the types of DG that are commonly used, one of them is the Bio Gas Power Plant (PTBG) fueled by liquid palm oil waste.

Decision Analysis to Find Best Solution of Operation and Maintenance Management System in Central Processing Plant (CPP) Gundih Using The SMART Method at PT. Pertamina EP

Central Processing Plant (CPP) Gundih is a gas field owned by PT. Pertamina EP Cepu Field area which is located in Blora Regency, Central Java. The gas produced by the CPP Gundih is channelled to the Tambak Lorok Gas and Steam Power Plant (PLTGU) with a capacity of 1,469MW in the Semarang City area, Central Java. Therefore, the CPP Gundih is a vital national object that supports national energy security, especially for the Central Java area. CPP Gundih first operated in 2013 with the operation and maintenance management system being fully handled by a third party with a contract term of one decade. In the coming year, the contract system will approach the end of the collaboration so that PT. Pertamina EP needs more efficient management schemes and strategies and more agile business processes. In the past decade, there have been several evaluations that have become a concern for companies in implementing contract systems with third parties. These obstacles mean that several aspects are not managed well and result in problems that reduce the level of customer satisfaction, decrease profits, and increase operational and maintenance costs. So that PT. Pertamina EP is considering several options for better management of the CPP Gundih in the future, namely the option of detailing third party contracts in the future, the option of transferring management by PT. Pertamina EP partially, full management transfer option by PT. Pertamina EP without any third-party involvement. From several proposed options, the author will use the Simple Multi Attribute Rating Technique (SMART) method to select the best option by considering aspects of Cost, Durability and Plant Availability, Manpower Competency Management, Remuneration, Communication Flow, and Integrated Work Procedure. The research results obtained from this method will become a reference for the PT management team. Pertamina EP for decision making related to the operation and maintenance implementation system at the Central Processing Plant (CPP) Gundih gas field.

Exploring Thermal Barrier and Sedimentation Simulation for Enhanced Performance in Grati Combined Cycle Power Plant

PLTGU is a power generation facility that concurrently utilizes both steam and gas power plant technologies. It necessitates a cooling system to operate efficiently throughout its entire lifespan. If PLTGU Grati plans to increase its power capacity, there is a concern that the water discharged from the Water Outlet channel might not cool down sufficiently before re-entering the Water Intake channel. Additionally, sedimentation in the sea water uptake is causing siltation. Hence, this study focuses on the jetty extension project to address sedimentation and hot water spreading issues in PLTGU Grati. The numerical modeling analysis, conducted using the Delft3D software, indicates that in the case of power addition, Alternative Model 1 can reduce the highest temperature compared to the existing condition by 0.655°C. Similarly, Alternative Model 2 reduces the highest temperature by 0.090°C. Moreover, with power addition, sedimentation rate in Area 1 increases by 261.43 m3/month in Alternative Model 1, while in Alternative Model 2, it decreases by 969.47 m3/month compared to the existing condition. Considering the ability of Alternative Model 2 to effectively reduce the temperature in the inlet canals by 0.090°C, it provides the best solution to contain the spread of hot water in the PLTGU Grati area. Currently, PLTGU Grati employs a Cutter Suction Dredger (CSD) to periodically dredge the water inlet channel. Therefore, Alternative Model 2 is recommended as the optimal choice among the alternatives. Henceforth, detailed studies related to current patterns and sedimentation rates are presented comprehensively in this paper.

BKV CEO: If You Have the Skills To Pay the Bills, CCS Is a ‘Tremendous Business’

Shale gas producer BKV Corp. has made the leap into the US carbon capture and storage (CCS) sector, becoming the latest upstream firm to challenge the idea that only industry giants can make significant moves in this emerging arena. Founded in 2015 as a privately held subsidiary of Thailand’s coal and energy conglomerate Banpu, BKV and its fewer than 400 employees have quickly built the company into the 17th largest gas producer in the US. In addition to its upstream operations in the Barnett and Marcellus shales, BKV’s business model borrows from its Thai energy roots and includes ownership of two natural gas power plants in Texas. But the firm is better known within upstream technical circles for its leadership in refracturing horizontal wells in the Barnett where it is the largest operator both in terms of acreage and flowing wells. No stranger to diversification, BKV is now shifting its focus to CCS—a market anticipated to balloon almost fivefold from $3 billion to over $14 billion by the end of the decade. This growth is being propelled in the US by new legislation offering $85 in tax credits for each ton of CO2 sequestered, effectively turning the greenhouse gas into a valuable commodity. The company’s inaugural CCS project, in collaboration with Dallas-based EnLink Midstream, launched this past November in Bridgeport, Texas. Called the Barnett Zero Project, BKV and its partner are targeting the sequestration of approximately 210,000 mtpa of CO2e. Hitting that target means potentially generating over $17.8 million in annual tax credits, a sum that offers a swift return on investment for those who can manage costs. BKV has also established a new business unit called dCarbon Ventures which is leading a separate CCS joint venture in the Barnett play called Cotton Cove. The $17.6-million project, $9 million of which will be put up by BKV, is expected to begin injecting up to 45,000 mtpa by the end of next year. Beyond that, BKV and its subsidiaries have secured rights for a large-scale project spanning 21,000 acres in neighboring Louisiana which would source its emissions from the industrial and petrochemical plants around the New Orleans area. Steering these ambitious projects is BKV’s CEO, Chris Kalnin, alongside Lauren Read, vice president of the gas company’s dCarbon Ventures. Under their leadership, BKV hopes to achieve net-zero Scope 1 and 2 emissions by next year—decades ahead of most industry reduction targets. The company is not stopping there and is ambitioning to do what most US-based operators have so far refrained from, which is to offset its Scope 3 emissions sometime next decade. In the following Q&A, Kalnin and Read discuss the motivations behind the Barnett Zero Project, its significance in the context of independent producers, and what it signals about BKV’s broader strategy.

LOAD DISPATCH AND REPLACING DIESEL BY GAS POWER PLANT TO REDUCE PRODUCTION COST OF POWER GENERATION IN BALI ISLAND

Bali Island is powered from three power plants and from Jawa Island through marine cables. The power plant in Bali use diesel fuel which result in high production cost. Meanwhile the production cost at Jawa Island is lower because most of power plants use coal fuel. Supply from Jawa Island is limited 200MW but now days use as peaker and supply from diesel power plants in Bali which are mostly old machine run in full power. This condition has caused high production cost. Therefore we proposed to change the load dispatch and replace the old diesel by gas power plant. The simulation has shown a much lower production cost. The lowest cost is found for the transfer Jawa-Bali in optimum capacity.

Simulation of a small-scale electricity generation system from biomass gasification

The following work has been developed in the scope of the cooperation project called Pôle Goundi. This project, coordinated by the NGO Misión y Desarrollo para Goundi, with the collaboration of the technology transfer centre CITCEA-UPC and the support of the CCD-UPC, aims to electrify Goundi, a village located in the South of Chad. In this sense, the construction of a small-scale biomass gasification power plant is planned. Since the installation of the power plant will be done by stages, the first step is to demonstrate its viability by installing and operating the first 20kW of electrical power. For this, a complete commercial solution, mainly consisting of a multi-stage gasifier, an internal combustion engine and a synchronous generator, has been selected. Then, it has been modelled with Cycle-Tempo® and Matlab® simulation tools in order to analyze its operating parameters and performance. After a brief introduction about the aims and the scope of the project, this paper will proceed with a more detailed description of the system and the model and it will present some of the obtained results.

Poly-generation system with waste heat of low-temperature flue gas in power plants based on organic Rankine cycle

Besides fossil energy and water resources, waste heat resources have attracted more and more attention because of their wide distribution and large quantity. This paper studies a system using low-grade waste heat emitted in a coal-fired power plants as the heat source, which coupled with low-temperature organic Rankine cycle (ORC), humidification and dehumidification and desalting system (HDH) and desiccanting cooling system (DCS) with different heat recovery system strategies, aiming at using low-temperature waste heat for power generation, desalting saline wastewater/sea water and providing space cooling for residential systems. The influences of control parameters on system productivity and system performance index were studied. In addition, the effects of different ORC working media on optimal system performance were also studied and discussed. Condenser exergy loss decreased by about 33% compared to an independent ORC system. In the range of control parameters studied, the total gain output of the poly-generation system was increased by about 47% compared to that of the independent system. The system is more productive when using n-Octane and Toluene, and has the highest system performance indicators when using R245fa and R113.

Design Features and Performance Data of a New 400 kWel Biomass Gasification Power Plant of Downdraft Type

A new biomass-gasification power plant, of medium-size downdraft type, is presented and discussed in its design features and performance characteristics. Its configuration and overall dimensions, initially conceived for 800 kWel, were recently re-tuned, from a functional point of view and on the base of a parallel theoretical analysis, by decreasing to about 400 kWel the former design power level. This provision, jointly with the basic design choice of adopting a long and amply dimensioned inlet-biomass thermal pretreatment section, turned out quite effective in achieving high gasification temperatures and a low-tar content in the produced gas at fuel-to-air ratios well below the usually imposed, to the advantage of the heat value of the product-gas gas. The paper discusses the numerical analysis results which helped to properly adjust the operational parameters of the gasifier and then presents the experimental performance data of the overall power plant including biomass consumption, gasification temperatures, gas production, composition and pollutants content, cold-gas conversion efficiency and global electric efficiency. Special care is devoted to investigating the issue of a significant production of carbon-containing particulate matter in the product gas, which turns out made up of char and fixed carbon much more than of tar species.

Mercury removal performance of sulfated MnCe catalyst prepared by tobacco waste combustion synthesis

MnOx-CeO2 is a promising catalyst for Hg0 removal from coal flue gas at ∼150 °C but exhibits insufficient catalytic activity. Even though sulfation enhances the catalytic activity of MnOx-CeO2, gas-phase sulfation leads to SO2 poisoning and catalyst deactivation. In this study, we developed a liquid-phase sulfation strategy involving the direct combustion of cigarette butts soaked in a solution of sulfate and metal precursors to directly synthesize sulfated MnCe catalyst (SMC). SMC was characterized via N2 adsorption–desorption isotherms, SEM-EDS, XRD, XPS, and Hg-TPD. Both the MnCe catalyst and SMC exhibited good Hg0 oxidation efficiencies (66.46 % and 88.76 %, respectively) at 150 °C. The enhanced performance of SMC was attributed to the generation of abundant chemically adsorbed oxygen species on the SMC surface during sulfation. Moreover, the synergistic effect between the Ce4+ and Mn4+ species contributed to the improved catalytic performance of SMC. This strategy not only provides a one-step synthesis of sulfated catalysts but also has potential applications in Hg0 removal from coal flue gas in coal-fired power plants.

Innovative modification process of a natural gas power plant using self-sufficient waste heat recovery and flue gas utilization for a CCHP-methanol generation application: A comprehensive multi-variable feasibility study

Waste heat recovery holds significant importance in the context of natural gas power plants, as it facilitates the utilization of energy loss, leading to enhanced overall performance and mitigating adverse environmental effects. By harnessing and employing waste heat, power plants possess the capability to modify and optimize their operation, making a substantial contribution toward sustainable power/energy generation. Therefore, this study proposes a novel and eco-friendly approach to utilizing the flue gas emitted by a natural gas power plant. In addition to recovering waste heat, this method involves harnessing the flue gas for methanol production. The proposed system consists of an organic Rankine cycle, and absorption chiller, heating provider units, an electrolyzer for hydrogen generation, and a methanol synthesis unit. The novel method is implemented through computer-aided simulation using the Aspen HYSYS software and is subjected to an extensive analysis encompassing energy, exergy, environmental, and economic viewpoints. The simulation results exhibit producing 2712 kg/h of methanol with a purity of 99.97 mol%, 395.67 kg/s of hot water, 378 kg/s of chilled water, and 12253.57 kW of power. In this process, the energy and exergy efficiencies are 94.35% and 31.74%, respectively. Parametric study results demonstrate that reducing the gas turbine pressure and increasing the working fluid temperature in the evaporator of the absorption chiller cycle leads to improved exergy efficiency. Moreover, the multigeneration scenario shows a carbon dioxide footprint of 0.1564 kg/kWh and a total unit cost of product of 0.0485 $/GJ.

Capacity Credit of Solar PV Projects – Oman’s Main Interconnected System Case Study

Due to high growth in electricity demand, it is important to add more dispatchablegeneration capacity in power systems to maintain demand-supply balance in real time. In many power systems, fossil fuel-based units such as gas or coal power plants are used to maintain high-reliability standards during peak demand hours. Although intermittent renewable energy generation facilities such as solar PV systems are used as a fuel saver, they can offset part of the load during peak hours. Capacity credit measures the contribution of a power plant to reliably meet demand. Estimating capacity credit of solar PV systems is important to ensure the adequacy and security of electricity supply. In this article, the capacity credit of solar PV power plants in the Main Interconnected System (MIS) of Oman is modelled. Oman’s MIS considered in this study has 6,372 MW gas-based generation capacity, a negligible solar PV capacity, and 5,712 MW peak load. The results revealed that the capacity credit of solar PV plants is high at low solar PV penetration levels. However, it decreases drastically as solar PV capacity increases. For example, the first 500MW plant has a capacity credit of about 120 MW. When the cumulative installed solar PV capacity is 2000MW, the next 500MW plant has a capacity credit of only 26MW.

Analysis of the Multiphase Flow With Condensation in the Two-Phase Ejector Condenser Using Computational Fluid Dynamics Modeling

Abstract The liquid-driven two-phase ejector condenser is the object of the numerical investigation. The spray-ejector condenser is one of the critical components of the developed gas power plant with negative CO2 emission. The task of the ejector is to entrain exhaust gas and condense steam contained in it. Computational fluid dynamics (CFD) modeling allows analyzing complex phenomena and predicting the influence of a wide range of operating parameters on the local structure of the multiphase flow with condensation. The geometrical model of the ejector was designed to provide efficient steam condensation and generate sub-pressure region at the gas inlet. The 2D, axisymmetric CFD model was created using simcenter star ccm+ software. The multiphase mixture model was used to take into account two-phase flow. Turbulent flow was computed using k–ω SST model. Direct contact condensation of steam was calculated using two different approaches: the Spalding/evaporation model and the thermally-driven boiling/condensation model. The influence of various gas inlet velocities and the presence of CO2 on the operation of the ejector condenser were investigated based on scalar fields and charts representing changes in the most important variables along the flow path. The condensation is the most intense in the suction chamber. The boiling/condensation model predicts lower suction pressure and higher condensation effectivity than Spalding/evaporation model. The CO2 considerably affects the pressure and temperature distributions and reduces the condensation rate.

Comprehensive Environmental and Economic Assessment of Low-Carbon Energy Sources

The article presents the results of a study of various low-carbon energy sources based on a multi-criteria analysis for the purpose of a comprehensive environmental and economic assessment of the effectiveness of their use. The peculiarity of the study is that it analyzed both renewable energy sources and traditional fossil fuel based ones using innovative technologies for carbon dioxide capture and storage, as well as nuclear energy. The purpose of this work is to conduct a comprehensive assessment based on three criteria: normalized cost of electricity LCOE (Levelized Cost of Energy)/LEC (Levelized Energy Cost), specific value of carbon dioxide emissions and material intensity expressed in total MI (Material Input) numbers. The hypothesis of the study is as follows: the introduction of the criterion of material intensity in MI numbers into a comprehensive assessment will allow one to identify low-carbon energy sources with the greatest ecological and economic effect. As a result, it was found that in 2023, the global energy capacity of low-carbon energy sources reached 51.8%, but the share of energy produced by them is significantly lower, amounting to only 39.4%. The multi-criteria analysis made it possible to identify low-carbon energy sources that, at the lowest cost, provide the greatest reduction in carbon dioxide emissions, and at the same time reduce the overall environmental impact by reducing the disturbance of biospheric material flows. Wind farms have high ecological and economic efficiency, while solar energy sources and bioelectric power plants – slightly less so. Geothermal and hydroelectric power plants have a low normalized cost of electricity, but they have relatively high values of material intensity. The environmental and economic efficiency of nuclear power is higher than that of gas and coal-fired power plants using carbon dioxide capture technologies; it occupies an intermediate position between renewable and traditional energy sources. An unexpected established fact is that gas and coal-fired power plants with carbon dioxide capture technologies have the same environmental and economic efficiency. The results obtained can be useful in making decisions about the possibility of prioritizing the development of individual low-carbon energy sources.

Application of Covariance Matrix Adaptation‐Evolutionary Strategy for Modified Constrained Optimal Power Flow Problem Incorporating Valve Point and Emission Effect

A prevailing problem in power and energy subsystems is the smooth operation of electric energy systems. This work presents recent, efficient, and reliable evolutionary algorithm for solving the optimal power flow (OPF) analysis. All various practical complex equality and inequality constraints, namely, bus voltages, real powers of the generator buses, tap settings of the transformers and the reactive power generations, shunt compensation, and emission, are considered for the real‐world scenario. Primary feature in a gas power plant that raises a lot of computational shortcomings with nonlinear structure in fuel cost is valve point effect. The existing research works have not factored the valve point effect and lack the accuracy in the fuel cost minimization and do not reflect the various practical complexities such as valve point and emission effects in the OPF problem formulation. This paper, for the first time, introduces modified OPF problem formulation incorporating valve point effect and applies covariance matrix adaptation‐evolution strategy (CMA‐ES) for solving the modified OPF problem. The algorithm is scrutinised and tested on a modified IEEE‐30‐bus platform for various OPF objectives such as cost minimization, transmission loss, and total voltage deviation, subjected to practical constraints. Load flow analysis has been carried out using the Newton–Raphson method. This work aims to lay the foundation in such a way that it can be applicable in a real‐world scenario for any number of buses.

Turning toward a smart region by implementing a hybrid power system

Distributed generation (DG) especially energy acquired from renewable energy sources (RES) plays a significant role in modern power sector due to high carbon emissions around the globe. Its emerging potential is feasible by implementing microgrids as they are beneficial for networks in terms of increasing flexibility and stability, providing frequency and voltage support, power factor compensation etc. This makes the investment into microgrid incorporating RESs attractive, while at the same time reducing overall investment in the grid. Higher cost and stochastic nature of intermittent RES are complications for the implementation and operation of such solutions. This paper will analyse economic feasibility of hybrid power system (HPS) implementation consisting of a wind generator (WG), a photovoltaic system (PVS), gas combined heat and power plant (CHP) and storage batteries. Each of the elements is optimized according to power demand and RES’s potential. Technical analysis of the grid integration, parallel operation of the system and the grid is analysed with an example of a real medium-voltage distribution network operating in Bosnia and Herzegovina by using quasi-dynamic load flow simulation of one-week time-period. Finally, different operating mechanisms and strategies will be proposed, following the minimal power form the grid premise to satisfy maximum usability of RES’s potential. It is shown that implementing such HPS would be beneficial in terms of both economy and, ecology, as well as in reducing energy losses. Besides, it will reduce power supplying costs and energy losses, as well as and secure better exploitation and utilization of natural renewable energy sources. These technologies positively affect power network by decreasing the risk of network-components overloading, better exploiting the power-generation facilities based on renewable resources and positively impacting voltage profiles. Similar places, situated on remote locations, may use this analysis as an example to follow, to reduce their costs of electricity, acquire more reliable and sustainable power supply, and embrace green future.

Business Model Innovation of Off Grid Public Electric Vehicles Battery Swap Station with Solar Powered

Energy transition is Indonesia's national agenda to maintain energy security and realize the use of green energy. The use of electric vehicles (EVs) is one strategy to maintain primary energy security and support the reduction of carbon emissions. To support the growth of the EV ecosystem, Public Electric Vehicle Battery Swap Stations (Stasiun Penukaran Baterai Kendaraan Listrik Umum, SPBKLU) have been developed and installed in several locations. Currently, SPBKLU still uses electricity sources from the PLN (Perusahaan Listrik Negara, Indonesia’s electricity state-owned company) grid, where the majority of the PLN grid itself still relies on gas and coal power plants. Hence, this work proposed a PV-powered battery swap station and presented the Business Model Canvas and financial and SWOT analysis. Two business model schemes are proposed, the BPCOSP (Battery Provider, Cabinet Owner, Solar PV Provider) and BPCOSL (Battery Provider, Cabinet Owner, Solar PV Lease) schemes. From these two business schemes, the results of the financial feasibility analysis for the SPBKLU swap rate were obtained at IDR 18,241 for the BPCOSP scheme and IDR 21,500 for the BPCOSL scheme. From a SWOT analysis perspective, the BPCOSP and BPCOSL business schemes have the opportunity to increase the Solar PV business value chain and support government programs in achieving Net Zero Emissions. However, there are still weaknesses in terms of tariffs which are still not economical compared to the fuel costs of conventional two-wheeled vehicles and the current SPBKLU swap tariff which still uses electricity from the PLN grid.

Development of Heat Exchanger for Syngas Purification in a Smart Mini-Grid Gasification Power Plant

The shell and tube heat exchanger was designed using a stainless pipe with a diameter of 203.2 mm (8 inches) and 3 mm thick. The design calculation results indicates that heat transfer rate was about and a tube length of 0.7 m was used and the number of tubes Nt is 17, this is required to cool the syngas from 350℃ to 80°C theoretically. Results obtained from CFD ANSYS software 2022 version showed that the verification of the model was achieved by comparing the theoretical temperatures of the syngas with the temperatures predicted from the simulation.