IEEE Power & Energy Magazine - Spanish - May/June 2020 - 36

costosos en las inversiones de activos de red. Caracterizar y
cuantificar estas incertidumbres en los niveles de clientes y
redes puede proporcionar oportunidades para reducir y gestionar las incertidumbres futuras. Frente a un futuro cada
vez más incierto, los usuarios de la red deben proporcionar
con certeza estimada sus necesidades futuras de acceso a la
red, lo que puede reducir el riesgo de errores de inversión
y aliviar la carga de los operadores de red, responsables de
pronosticar el estado del sistema.
Los operadores de red que comprenden el sistema reconocerían las diferencias en su uso por parte de diversos
clientes en un rango de periodos e identificarían oportunidades para compartir la capacidad de la red existente,
lo que mejoraría la utilización de la red y minimizaría las
nuevas inversiones en red. Esto beneficiaría particularmente la generación de energías renovables y la demanda
flexible, ya que no requieren una capacidad de red completa todo el tiempo. A través de un sistema de uso compartido bien diseñado, la red existente podría dar como
resultado un aumento sustancial en la utilización de la red
y, por lo tanto, abastecer a un volumen de clientes mucho
mayor que el actual. Esto, a su vez, conduciría a costos de
red significativamente reducidos.

Incertidumbres en todos los tipos de clientes
El grado de incertidumbre energética difiere entre los
clientes debido a sus diversos estilos de vida o naturaleza
de las empresas y refleja: 1) incertidumbres temporales, es
decir, el momento en que ocurre la demanda máxima, y 2)
incertidumbres de magnitud, es decir, la previsibilidad de
la demanda. Esto tendrá un impacto directo en la incertidumbre de la demanda máxima de la red, lo que afectará
directamente la inversión en capacidad de la red y, por lo
tanto, debería ser un factor clave a tener en cuenta en los
cargos de red. Las incertidumbres se pueden estudiar más a
fondo en diferentes tipos de clientes en términos de su régimen tarifario y características de la demanda neta [como los
propietarios de vehículos eléctricos (VE) o energía fotovoltaica (FV)].
La figura 1 muestra las distribuciones temporales de la
carga máxima diaria para cuatro grupos de consumidores
residenciales. Los consumidores de R1 y R2 comparten
un patrón similar, con picos vespertinos constantes de 4
a 10 p.m. Para los grupos R3 y R4, las cargas máximas
se distribuyen aleatoriamente a lo largo del día, lo que
sugiere incertidumbres asociadas con FV y VE. La incertidumbre de los consumidores de R3 podría deberse a la

0.4

0.15

Densidad

Densidad

0.3
0.2
0.1
0

0.05

0
0

2

4

6

8 10 12 14 16 18 20 22 24
(Hora)
(a)

0.3

0.25

0.25

0.2
Densidad

0.2
Densidad

0.1

0.15
0.1

0

2

4

6

8 10 12 14 16 18 20 22 24
(Hora)
(b)

0

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0.15
0.1
0.05

0.05
0

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(c)

figura 1. La distribución temporal de las demandas máximas de los consumidores residenciales. (a) R1: Clientes residenciales sin estímulo (respuesta a la demanda) o tarifas especiales. Se les factura una tarifa plana existente y son actualmente
los consumidores residenciales más representativos. (b) R2: Los consumidores reciben su factura con tarifas TOU que
reflejan diferentes precios unitarios a lo largo del día. (c) R3: Consumidores con FV. (d) R4: Consumidores con VE.
36	

ieee power & energy magazine 	

mayo/junio 2020



IEEE Power & Energy Magazine - Spanish - May/June 2020

Table of Contents for the Digital Edition of IEEE Power & Energy Magazine - Spanish - May/June 2020

Contents
IEEE Power & Energy Magazine - Spanish - May/June 2020 - Cover1
IEEE Power & Energy Magazine - Spanish - May/June 2020 - Cover2
IEEE Power & Energy Magazine - Spanish - May/June 2020 - Contents
IEEE Power & Energy Magazine - Spanish - May/June 2020 - 2
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IEEE Power & Energy Magazine - Spanish - May/June 2020 - Cover3
IEEE Power & Energy Magazine - Spanish - May/June 2020 - Cover4
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