scholarly journals Mongolia’s potential in international cooperation in the Asian energy space

2018 ◽  
Vol 27 ◽  
pp. 01006 ◽  
Author(s):  
Sereeter Batmunkh ◽  
Valery Stennikov ◽  
Bayar Bat-Erdene ◽  
Altay Erdenebaatar

The paper is concerned with the issues of interstate electric power interconnections to be created in the countries of Northeast Asia. The conditions are formulated, the problems are stated, and solutions for Mongolia’s entry into the Asian energy space are proposed. The electricity consumption rates are growing, however, the Northeast Asia countries differ considerably in available energy resources to cope with this growth. Therefore, the need to build international electric power interconnections that take into account climatic features, seasonal peak load differences and other factors in order to rationally match power demand and supply is getting increasingly more obvious. Mongolia can take an active part in this process, as the country is rich in energy resources and interested in their development to meet their domestic needs and exchange with neighboring countries. The establishment of interstate power interconnections in the Northeast Asia countries represents a topical task whose solution will make it possible to meet the demand of this region for electricity on mutually beneficial terms. Mongolia has a good spatial position, energy resources and is interested in ensuring domestic energy balance. Therefore, the country can be an active participant in such an integration process.

Author(s):  
José Alfonso Sánchez-Cortez ◽  
Carlos Eduardo Castillo-Ramírez ◽  
Amparo González-Morales ◽  
Luis Guillermo Vázquez-Baldazo

The increase in costs for electricity consumption has gone up, significantly affecting the economy of users, within the tariffs of residential users is the “DAC” rate (that means high consumption domestic rate). An economic analysis of electricity consumption rates indicates that, as of January 1st, 2019, the cost per kWh used in the “DAC” tariff corresponds to $ 5.121 MXN, which means that a “DAC” user pays more than 200% than a user 1C rate for each kWh consumed. For this purpose, a photovoltaic system has been designed for interconnection to the network, this system allows users to change from “DAC” rate to tariff 1C, and consequently will allow the reduction of these costs about the electric power service, this system can be installed in any yard, besides generating electricity, the photovoltaic products will be 2: a swing and a gazebo, with an installed capacity of 1.1 kWh, which will provide a rest and relaxation service.


1974 ◽  
Vol 77 (666) ◽  
pp. 554-558
Author(s):  
Masafumi ONO ◽  
Hirotoshi INABA

Energies ◽  
2021 ◽  
Vol 14 (1) ◽  
pp. 226
Author(s):  
Milana Treshcheva ◽  
Irina Anikina ◽  
Vitaly Sergeev ◽  
Sergey Skulkin ◽  
Dmitry Treshchev

The percentage of heat pumps used in thermal power plants (TPPs) in the fuel and energy balance is extremely low in in most countries. One of the reasons for this is the lack of a systematic approach to selecting and justifying the circuit solutions and equipment capacity. This article aims to develop a new method of calculating the maximum capacity of heat pumps. The method proposed in the article has elements of marginal analysis. It takes into account the limitation of heat pump capacity by break-even operation at electric power market (compensation of fuel expenses, connected with electric power production). In this case, the heat pump’s maximum allowable capacity depends on the electric capacity of TPP, electricity consumption for own needs, specific consumption of conditional fuel for electricity production, a ratio of prices for energy resources, and a conversion factor of heat pump. For TPP based on combined cycle gas turbine (CCGT) CCGT-450 with prices at the Russian energy resources markets at the level of 2019, when operating with the maximum heat load, the allowable heat pump capacity will be about 50 MW, and when operating with the minimum heat load—about 200 MW.


Author(s):  
QiheLou ◽  
QiLyu ◽  
Zhixiong Na ◽  
Dayan Ma ◽  
Xiaoguang Ma

Energies ◽  
2021 ◽  
Vol 14 (6) ◽  
pp. 1688 ◽  
Author(s):  
C. Birk Jones ◽  
Matthew Lave ◽  
William Vining ◽  
Brooke Marshall Garcia

An increase in Electric Vehicles (EV) will result in higher demands on the distribution electric power systems (EPS) which may result in thermal line overloading and low voltage violations. To understand the impact, this work simulates two EV charging scenarios (home- and work-dominant) under potential 2030 EV adoption levels on 10 actual distribution feeders that support residential, commercial, and industrial loads. The simulations include actual driving patterns of existing (non-EV) vehicles taken from global positioning system (GPS) data. The GPS driving behaviors, which explain the spatial and temporal EV charging demands, provide information on each vehicles travel distance, dwell locations, and dwell durations. Then, the EPS simulations incorporate the EV charging demands to calculate the power flow across the feeder. Simulation results show that voltage impacts are modest (less than 0.01 p.u.), likely due to robust feeder designs and the models only represent the high-voltage (“primary”) system components. Line loading impacts are more noticeable, with a maximum increase of about 15%. Additionally, the feeder peak load times experience a slight shift for residential and mixed feeders (≈1 h), not at all for the industrial, and 8 h for the commercial feeder.


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