# Economic Evaluation of Three Available Solutions for Promotion of Wind Power Integration

Authors: Hong-Kun Chen; Yan-Juan Yu; Lei Chen; Xin Jiang; Ren-Yan Yu
Journal: International Journal of Rotating Machinery
 (2017)

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## Abstract

The limited operational flexibility of combined heat and power (CHP) units is the main cause of wind power curtailment in the thermal-electrical power system of Northern China. Pumped hydrostorage (PHS), heat storage (HS), and electric boiler (EB) are investigated as three alternative options for the promotion of wind power integration. On the basis of two linear models that determine the capacities of these three facilities required for integrating the curtailed wind power, economic evaluation in terms of investment costs and environmental benefits is presented. Analysis results show that HS requires the least investment and has a good performance of coal saving when accommodating the same amount of curtailed wind power. And EB has the greatest potential for wind power integration with the huge growth of installed capacity of wind power in the future.


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## Body

## 1. Introduction

With the rapid growth of wind power, it has been a mainstream green energy source in many countries, as well as in China [1]. But a large amount of wind power has to be wasted in the heating season due to the limited flexibility of the combined heat and power (CHP) units, especially in Northern China where the CHP units account for a large share of the generators [2]. CHP units cannot supply adequate downward regulating space for wind power since the production of electricity is strongly dependent on heat demand in the cogeneration system [3]. In view of this situation, wasted wind power is supposed to be reduced by either accumulating directly with electrical storage devices or decoupling heat and power demand with heat compensation devices.Potential options for electrical storage include electrochemical energy storage, electromagnetic energy storage, and mechanical energy storage [4, 5]. However, most of the electrical storages need vast investment and have not been in the commercial application except pumped hydrostorage (PHS) [6]. PHS is well known as the most promising energy storage technology, accounting for 99% of the available electrical storage capacity all over the world. And it has a good performance of frequency control and peak load shifting [7]. Comprehensive benefits of introducing PHS for the promotion of wind power accommodation have been analyzed in [8–11], which achieve an agreement that PHS could get cost-effective peak-shaving as well as the reduction in carbon dioxide emissions. Heat storage (HS) and electric boiler (EB) are favorable alternatives for reducing curtailed wind power in terms of releasing heat and power linkage [12]. Several studies focused on HS and EB have also been made to identify their facilitation of wind power integration. Reference [13] analyzed the possibilities of CHPs and HS balancing large scale of wind power and the optimal capacity of HS. In [14], research of optimal combination of PHS and EB in West Inner Mongolia was carried out, which claimed that PHS was less cost-effective than EB with the same reduction of surplus wind power. In [15], both environmental benefits and economic benefits were included in the objective function which was used to calculate the optimum capacity of EB when all of the curtailed wind power has to be accommodated. Reference [16] put forward several evaluation indexes to weigh the effects of HS and EB added to the cogeneration system on wind power accommodation. In [17–22], the performance of HS and EB on decoupling thermal-electrical production was further analyzed. All of the studies mentioned above have discussed the different approaches for better wind power integration, but few of them have compared the economic benefits of PHS as being the quintessential example of electrical storages with thermal devices.This paper focuses on the economic evaluation of PHS, HS, and EB for the promotion of wind power integration. The economic analysis is conducted on the basis of calculating the capacities of these three facilities. Further, two linear models are established following the principle of “ordering power by heat (OPH)” or “ordering heat by power (OHP),” respectively, to obtain the expected capacities. This paper is organized as follows. Section2 is devoted to introducing the operation characteristics of CHP units and constructing OPH and OHP models while Section 3 presents the economic analysis of the three alternatives on the foundation of Section 2. Case studies and discussion are given in Section 4. Finally, conclusions are drawn in Section 5.


## 2. Proposed OPH and OHP Models

### 2.1. Operation Characteristic of CHP Unit

Two main types of CHP units, the back-pressure units and extraction-condensing units, are used worldwide in the power system. The heat output of a back-pressure unit is proportional to the power output while the heat and power outputs of an extraction-condensing unit are not certain to a proportional relationship. We just focused on the extraction-condensing units in this study since this type of CHP units is widely installed in Northern China. For simplicity, all the CHPs mentioned below are in terms of extraction-condensing units.The feasible operation region of a CHP is characterized as an irregular quadrilateral or a polygon which is illustrated in Figure1. The operation zone of a CHP is assumed to be convex so that the electric power Pit, thermal power Qit, and operating cost Cit of a CHP can be represented as the linear convex combination of the extreme points. Several studies [23–25] related to the convexity of the CHP unit have been done, and the demonstrated results enable verifying the linear expression of the operating region as follows:(1)Qit=∑k=1Miqi,kxi,ktPit=∑k=1Mipi,kxi,ktCit=∑k=1Mici,kxi,kt∑k=1Mixi,kt=1,0≤xi,kt≤1,where pi,k, qi,k, and ci,k are the values of power, heat, and cost of the kth extreme point; Mi is the number of extreme points for the ith CHP; xi,kt is the combination coefficient. It is worth mentioning that numerous subsets of extreme points are eligible for representing a given operating status (Pit,Qit).Figure 1
The feasible operating region of CHP.


### 2.2. Ordering Power by Heat (OPH) Model

The electric power produced by CHP units is determined by the thermal power which is the major barrier for the flexibility of CHP. This characteristic is the very foundation of the OPH model which is formulated with the objective function of minimizing the wasted wind power on the premise of meeting the daily heat demand.Objective Function
(2)
min
⁡
∑
t
∈
T
P
w
-
P
w
x
t
;Electric Power Balance Constraint
(3)
∑
i
=
1
I
∑
k
=
1
M
i
p
i
,
k
x
i
,
k
t
+
∑
j
=
1
J
P
j
x
t
+
P
w
x
t
=
P
e
t
;Thermal Power Balance Constraint
(4)
∑
i
=
1
I
∑
k
=
1
M
i
q
i
,
k
x
i
,
k
t
=
P
h
t
;Generation Output Constraint
(5)
0
≤
P
w
x
t
≤
P
w
t
(6)
∑
k
=
1
M
i
x
i
,
k
t
=
1
,
0
≤
x
i
,
k
t
≤
1
(7)
P
j
m
i
n
≤
P
j
x
t
≤
P
j
m
a
x
;Ramp Rate Constraint
(8)
-
P
i
u
p
≤
∑
k
=
1
M
i
p
i
,
k
x
i
,
k
t
-
1
-
∑
k
=
1
M
i
p
i
,
k
x
i
,
k
t
≤
P
i
d
o
w
n
(9)
-
P
j
u
p
≤
P
j
x
t
-
1
-
P
j
x
t
≤
P
j
d
o
w
n
,where I and J are the numbers of CHP and power-only units, respectively; T is the scheduling period; Pjxt is the power generated by the jth unit at period t; Pht and Pet are the power load and heat load; Pwt and Pwxt are the forecasted and integrated wind power; Pup and Pdown are the rates of ramping up and down, respectively.We can obtain the total amount of wasted wind power which would be accommodated directly by PHS and make the operating strategy of PHS by solving this linear OPH model.


### 2.3. Ordering Heat by Power (OHP) Model

Contrary to the OPH model, the OHP model is established following the principle of “ordering heat by power”; that is, the electric power is given priority to be regulated to accommodate the total wind power as far as possible and part of thermal demand which cannot be meet by CHPs would be supplied by heat compensators. A state vector,V(t), is proposed to indicate the operating mode of heat compensator at period t: V(t)=1 means the requirement of heat compensation and V(t)=0, vice versa.The minimum power output and the equivalent power load of the cogeneration system are noted as follows:Emin and Ploadt, respectively.(10)Emin=∑i=1IPimin+∑j=1jPjminPloadt=Pet-Pwt.It is obvious that whenEmin>Ploadt the wind power is bound to be curtailed and thus V(t)=1. When Emin<Ploadt, the value of V(t) has to be further defined by the difference between the maximum heat output of CHPs and heat load. The OHP model is formulated as follows:Objective Function
(11)
max
⁡
∑
i
=
1
I
∑
k
=
1
M
i
q
i
,
k
x
i
,
k
t
;Electric Power Balance Constraint
(12)
∑
i
=
1
I
∑
k
=
1
M
i
p
i
,
k
x
i
,
k
t
+
∑
j
=
1
J
P
j
x
t
=
P
l
o
a
d
t
;Other constraints contain (4) and (6)–(9). The value of V(t) is determined with the discriminant function:(13)Vt=1,ifPht>∑i=1IQi,tavail0,ifPht<∑i=1IQi,tavail,where Qi,tavail is the maximum available thermal power of the ith CHP unit solved by (11). Pht<∑i=1IQi,tavail means that the heat power produced by CHP units is sufficient for heat supply while Pht>∑i=1IQi,tavail means that the heat compensator is required for auxiliary heating.


## 2.1. Operation Characteristic of CHP Unit

Two main types of CHP units, the back-pressure units and extraction-condensing units, are used worldwide in the power system. The heat output of a back-pressure unit is proportional to the power output while the heat and power outputs of an extraction-condensing unit are not certain to a proportional relationship. We just focused on the extraction-condensing units in this study since this type of CHP units is widely installed in Northern China. For simplicity, all the CHPs mentioned below are in terms of extraction-condensing units.The feasible operation region of a CHP is characterized as an irregular quadrilateral or a polygon which is illustrated in Figure1. The operation zone of a CHP is assumed to be convex so that the electric power Pit, thermal power Qit, and operating cost Cit of a CHP can be represented as the linear convex combination of the extreme points. Several studies [23–25] related to the convexity of the CHP unit have been done, and the demonstrated results enable verifying the linear expression of the operating region as follows:(1)Qit=∑k=1Miqi,kxi,ktPit=∑k=1Mipi,kxi,ktCit=∑k=1Mici,kxi,kt∑k=1Mixi,kt=1,0≤xi,kt≤1,where pi,k, qi,k, and ci,k are the values of power, heat, and cost of the kth extreme point; Mi is the number of extreme points for the ith CHP; xi,kt is the combination coefficient. It is worth mentioning that numerous subsets of extreme points are eligible for representing a given operating status (Pit,Qit).Figure 1
The feasible operating region of CHP.


## 2.2. Ordering Power by Heat (OPH) Model

The electric power produced by CHP units is determined by the thermal power which is the major barrier for the flexibility of CHP. This characteristic is the very foundation of the OPH model which is formulated with the objective function of minimizing the wasted wind power on the premise of meeting the daily heat demand.Objective Function
(2)
min
⁡
∑
t
∈
T
P
w
-
P
w
x
t
;Electric Power Balance Constraint
(3)
∑
i
=
1
I
∑
k
=
1
M
i
p
i
,
k
x
i
,
k
t
+
∑
j
=
1
J
P
j
x
t
+
P
w
x
t
=
P
e
t
;Thermal Power Balance Constraint
(4)
∑
i
=
1
I
∑
k
=
1
M
i
q
i
,
k
x
i
,
k
t
=
P
h
t
;Generation Output Constraint
(5)
0
≤
P
w
x
t
≤
P
w
t
(6)
∑
k
=
1
M
i
x
i
,
k
t
=
1
,
0
≤
x
i
,
k
t
≤
1
(7)
P
j
m
i
n
≤
P
j
x
t
≤
P
j
m
a
x
;Ramp Rate Constraint
(8)
-
P
i
u
p
≤
∑
k
=
1
M
i
p
i
,
k
x
i
,
k
t
-
1
-
∑
k
=
1
M
i
p
i
,
k
x
i
,
k
t
≤
P
i
d
o
w
n
(9)
-
P
j
u
p
≤
P
j
x
t
-
1
-
P
j
x
t
≤
P
j
d
o
w
n
,where I and J are the numbers of CHP and power-only units, respectively; T is the scheduling period; Pjxt is the power generated by the jth unit at period t; Pht and Pet are the power load and heat load; Pwt and Pwxt are the forecasted and integrated wind power; Pup and Pdown are the rates of ramping up and down, respectively.We can obtain the total amount of wasted wind power which would be accommodated directly by PHS and make the operating strategy of PHS by solving this linear OPH model.


## 2.3. Ordering Heat by Power (OHP) Model

Contrary to the OPH model, the OHP model is established following the principle of “ordering heat by power”; that is, the electric power is given priority to be regulated to accommodate the total wind power as far as possible and part of thermal demand which cannot be meet by CHPs would be supplied by heat compensators. A state vector,V(t), is proposed to indicate the operating mode of heat compensator at period t: V(t)=1 means the requirement of heat compensation and V(t)=0, vice versa.The minimum power output and the equivalent power load of the cogeneration system are noted as follows:Emin and Ploadt, respectively.(10)Emin=∑i=1IPimin+∑j=1jPjminPloadt=Pet-Pwt.It is obvious that whenEmin>Ploadt the wind power is bound to be curtailed and thus V(t)=1. When Emin<Ploadt, the value of V(t) has to be further defined by the difference between the maximum heat output of CHPs and heat load. The OHP model is formulated as follows:Objective Function
(11)
max
⁡
∑
i
=
1
I
∑
k
=
1
M
i
q
i
,
k
x
i
,
k
t
;Electric Power Balance Constraint
(12)
∑
i
=
1
I
∑
k
=
1
M
i
p
i
,
k
x
i
,
k
t
+
∑
j
=
1
J
P
j
x
t
=
P
l
o
a
d
t
;Other constraints contain (4) and (6)–(9). The value of V(t) is determined with the discriminant function:(13)Vt=1,ifPht>∑i=1IQi,tavail0,ifPht<∑i=1IQi,tavail,where Qi,tavail is the maximum available thermal power of the ith CHP unit solved by (11). Pht<∑i=1IQi,tavail means that the heat power produced by CHP units is sufficient for heat supply while Pht>∑i=1IQi,tavail means that the heat compensator is required for auxiliary heating.


## 3. Economic Analysis

The economic analysis is carried out based on the optimal results of OPH and OHP models with typical daily load and wind power curves. The net benefit is used as the index to measure the performance of different solutions in facilitating wind power integration.


### 3.1. Pumped Hydrostorage (PHS)

PHS is expected to consume surplus wind power during off-peak periods by pumping water from the lower reservoir to the upper one. And during peak load periods, the potential energy is transformed into electrical energy again, reducing the power produced by CHP and power-only units. Aiming at integrating the whole generated wind power, the minimum installed capacity of PHS,OPHS, should be larger than the surplus wind power in consideration of energy efficiency.(14)OPHS=∑t∈TwPwt-PwxtΔtηPHS,where Tw is the set of the periods when the wind power was wasted. In view of the gross cost of PHS, only the construction cost and maintenance cost are taken into consideration, as well as HS and EB. Thus the annual average cost of PHS can be expressed as follows:(15)CPHSc=OPHSuPHScr1+ryPHS1+ryPHS-1CPHSm=OPHSuPHScαPHSCPHSΣ=CPHSc+CPHSm,where ηPHS is the energy efficiency; CPHSc is the converted annual construction cost; CPHSm and CPHSΣ are the maintenance cost and gross cost, respectively; uPHSc is the unit construction cost; r is the bank lending rates; yPHS is the lifetime of PHS; αPHS is the fixed annual maintenance cost ratio.The economic benefits created by PHS during the daily scheduling period include two parts: the coal saved by replacing power generation of CHP and power-only units during peak load periods and the carbon emission cost reduced by coal saving. The evaluation model is given by(16)BPHS=ucoal+ucarε∑t∈TwPwt-PwxtΔtpavcoal.The daily net benefits of PHS should be expressed as follows:(17)RPHS=BPHS-CPHSΣD,where ucoal is the cost of per ton of coal equivalent (Tce); ucar is the cost of carbon emission; ε is CO2 emission of per ton coal; Δt is the duration of each segment; pavcoal is the average coal consumption of electric power generation; D is the number of heating days per year.


### 3.2. Heat Storage (HS)

It is possible to introduce an HS using water as the energy storage media to reconcile the conflict between electric peak-shaving and heat supply [26]. The HS plays a role in thermal-load-shifting, similar to the load shifting of PHS. During the daytime, the CHPs are forced to produce extra thermal power for heat charging of HS. Then the stored thermal energy is released to ease the heat supply burden of CHPs during the nighttime. The capacity of HS is dependent on the requirement of heat compensation, which is calculated as follows:(18)OHS=∑t∈TPht-∑i∈IQi,tavailΔt1-ηHSloss,where ηHSloss is the heat accumulation loss of HS.The annual average cost of HS is expressed as follows:(19)CHSc=OHSuHScr1+ryHS1+ryHS-1CHSm=OHSuHScαHSCHSΣ=CHSc+CHSm.In fact, the gross thermal power produced by CHPs during the scheduling period increases slightly because of the heat loss of HS. But the gross electric power supplied by CHPs reduces to integrate more wind power since the HS promotes the flexibility of CHPs. Thus both the increased thermal power and the reduced electric power generated by CHP have an effect on the economic calculation, including coal cost and carbon emission cost. The economic benefits and net benefits are calculated as follows:(20)BHS=ucoal+ucarε∑t∈TwPwt-PwxtΔtpavcoal-OHSηHSlossqavcoalRHS=BHS-CHSΣD,where qavcoal is the average coal consumption of CHPs for thermal power generation.


### 3.3. Electric Boiler (EB)

An EB is usually installed near the CHP plant and activated during the periods,Tw. Not only can it consume wind power directly as PHS, but also it can supply thermal power as HS. To explain the impact of this specific characteristic on the operation of CHP, Figure 2 is shown for detailed illustration.Figure 2
Operating region of CHP with electric boiler.Q
i
n
e
e
d represents the essential thermal power obtained by the OPH model where the thermal demand is met primarily. Pineed represents the demanded electric power output obtained by the OHP model where the wind power integration is preferred. Neither operating point HOHP nor HOPH of CHPs is available for the system to meet thermal demand without wasting wind power. Nevertheless, the CHP unit could be adjusted to the operating point, H0, to satisfy the regulating requirement of thermal and electric power hopefully with assistance of EB.After the EB being integrated into the system, the produced thermal power of theith CHP unit is reduced by Δqi,t and the electric power is increased by Δpi,t. The coupling relationship of thermal and electric power during each Δt could be expressed as follows:(21)pi,tneed+Δpi,t=kiQi,tneed-Δqi,t+biΔqi,t=Δpi,tηEB,where ηEB is the energy efficiency of EB; ki and bi are the parameters of the line segment CB in Figure 2. As the gross increased electric power of CHPs is caused by the power consumption of EB, the minimum capacity of EB is given by(22)OEB=maxt∈Tw⁡∑i∈IΔpi,t.The annual average cost of EB is given by(23)CEBc=OEBuEBcr1+ryEB1+ryEB-1CEBm=OEBuEBcαEBCEBΣ=CEBc+CEBm.With the EB meeting part of the thermal demand and consuming more wind power, coal and carbon emission cost of the cogeneration system reduced even more. The economic benefits and net benefits are given by(24)BEB=ucoal+ucarε∑t∈TwPwt-Pwxtpavcoal+Δqi,tqavcoalΔtREB=BEB-CEBΣD.Except for the calculation ofR∗, reflecting directly the net benefits, performance of these three different facilities for wind power integration is further discussed with numerable examples in Section 4.


## 3.1. Pumped Hydrostorage (PHS)

PHS is expected to consume surplus wind power during off-peak periods by pumping water from the lower reservoir to the upper one. And during peak load periods, the potential energy is transformed into electrical energy again, reducing the power produced by CHP and power-only units. Aiming at integrating the whole generated wind power, the minimum installed capacity of PHS,OPHS, should be larger than the surplus wind power in consideration of energy efficiency.(14)OPHS=∑t∈TwPwt-PwxtΔtηPHS,where Tw is the set of the periods when the wind power was wasted. In view of the gross cost of PHS, only the construction cost and maintenance cost are taken into consideration, as well as HS and EB. Thus the annual average cost of PHS can be expressed as follows:(15)CPHSc=OPHSuPHScr1+ryPHS1+ryPHS-1CPHSm=OPHSuPHScαPHSCPHSΣ=CPHSc+CPHSm,where ηPHS is the energy efficiency; CPHSc is the converted annual construction cost; CPHSm and CPHSΣ are the maintenance cost and gross cost, respectively; uPHSc is the unit construction cost; r is the bank lending rates; yPHS is the lifetime of PHS; αPHS is the fixed annual maintenance cost ratio.The economic benefits created by PHS during the daily scheduling period include two parts: the coal saved by replacing power generation of CHP and power-only units during peak load periods and the carbon emission cost reduced by coal saving. The evaluation model is given by(16)BPHS=ucoal+ucarε∑t∈TwPwt-PwxtΔtpavcoal.The daily net benefits of PHS should be expressed as follows:(17)RPHS=BPHS-CPHSΣD,where ucoal is the cost of per ton of coal equivalent (Tce); ucar is the cost of carbon emission; ε is CO2 emission of per ton coal; Δt is the duration of each segment; pavcoal is the average coal consumption of electric power generation; D is the number of heating days per year.


## 3.2. Heat Storage (HS)

It is possible to introduce an HS using water as the energy storage media to reconcile the conflict between electric peak-shaving and heat supply [26]. The HS plays a role in thermal-load-shifting, similar to the load shifting of PHS. During the daytime, the CHPs are forced to produce extra thermal power for heat charging of HS. Then the stored thermal energy is released to ease the heat supply burden of CHPs during the nighttime. The capacity of HS is dependent on the requirement of heat compensation, which is calculated as follows:(18)OHS=∑t∈TPht-∑i∈IQi,tavailΔt1-ηHSloss,where ηHSloss is the heat accumulation loss of HS.The annual average cost of HS is expressed as follows:(19)CHSc=OHSuHScr1+ryHS1+ryHS-1CHSm=OHSuHScαHSCHSΣ=CHSc+CHSm.In fact, the gross thermal power produced by CHPs during the scheduling period increases slightly because of the heat loss of HS. But the gross electric power supplied by CHPs reduces to integrate more wind power since the HS promotes the flexibility of CHPs. Thus both the increased thermal power and the reduced electric power generated by CHP have an effect on the economic calculation, including coal cost and carbon emission cost. The economic benefits and net benefits are calculated as follows:(20)BHS=ucoal+ucarε∑t∈TwPwt-PwxtΔtpavcoal-OHSηHSlossqavcoalRHS=BHS-CHSΣD,where qavcoal is the average coal consumption of CHPs for thermal power generation.


## 3.3. Electric Boiler (EB)

An EB is usually installed near the CHP plant and activated during the periods,Tw. Not only can it consume wind power directly as PHS, but also it can supply thermal power as HS. To explain the impact of this specific characteristic on the operation of CHP, Figure 2 is shown for detailed illustration.Figure 2
Operating region of CHP with electric boiler.Q
i
n
e
e
d represents the essential thermal power obtained by the OPH model where the thermal demand is met primarily. Pineed represents the demanded electric power output obtained by the OHP model where the wind power integration is preferred. Neither operating point HOHP nor HOPH of CHPs is available for the system to meet thermal demand without wasting wind power. Nevertheless, the CHP unit could be adjusted to the operating point, H0, to satisfy the regulating requirement of thermal and electric power hopefully with assistance of EB.After the EB being integrated into the system, the produced thermal power of theith CHP unit is reduced by Δqi,t and the electric power is increased by Δpi,t. The coupling relationship of thermal and electric power during each Δt could be expressed as follows:(21)pi,tneed+Δpi,t=kiQi,tneed-Δqi,t+biΔqi,t=Δpi,tηEB,where ηEB is the energy efficiency of EB; ki and bi are the parameters of the line segment CB in Figure 2. As the gross increased electric power of CHPs is caused by the power consumption of EB, the minimum capacity of EB is given by(22)OEB=maxt∈Tw⁡∑i∈IΔpi,t.The annual average cost of EB is given by(23)CEBc=OEBuEBcr1+ryEB1+ryEB-1CEBm=OEBuEBcαEBCEBΣ=CEBc+CEBm.With the EB meeting part of the thermal demand and consuming more wind power, coal and carbon emission cost of the cogeneration system reduced even more. The economic benefits and net benefits are given by(24)BEB=ucoal+ucarε∑t∈TwPwt-Pwxtpavcoal+Δqi,tqavcoalΔtREB=BEB-CEBΣD.Except for the calculation ofR∗, reflecting directly the net benefits, performance of these three different facilities for wind power integration is further discussed with numerable examples in Section 4.


## 4. Case Studies

### 4.1. Case  1

In this study, the cogeneration system structure is downscaled based on the actual proportions of installed power energy sources in Northern China. Three CHP units are noted asCHP1,CHP2, andCHP3; two power-only units are noted asCON1 andCON2. The power source structure is listed in Table 1. Detailed information of the units is shown in Table 2. The scheduling period, T, is 24 hours and Δt is 1 hour. D is 180 days. Figure 3 shows the curves of typical daily thermal power load and electric power load. Parameters related to economic analysis are given in Table 3.Table 1
Power source structure.
Power Source
Installed Capacity/MW
Proportion
CHP
800
67.8%
Power-only
250
21.2%
Wind
130
11.0%Table 2
Parameters of CHP and power-only units.
CHP Units
Corner Points
CHP1
CHP2
CHP3
(q1,p1)/MW
(
0,323
)
(
0,310
)
(
0,210
)
(q2,p2)/MW
(
357,241
)
(
320,246
)
(
240,155
)
(q3,p3)/MW
(
154,150
)
(
100,150
)
(
124,100
)
(q4,p4)/MW
(
0,150
)
(
0,170
)
(
0,100
)
Power-only Units
Output Limits
CON1
CON2
Maximum/MW
150
100
Minimum/MW
75
50Table 3
Parameters related to economic analysis.
η
P
H
S
80%
η
H
S
l
o
s
s
4%
η
E
B
98%
α
P
H
S
1%
α
H
S
0.5%
α
E
B
0.5%
u
P
H
S
c
53.1k$/MWh
u
H
S
c
5.3k$/MWh
u
E
B
c
217k$/MW
p
a
v
c
o
a
l
330 kg/MWh
q
a
v
c
o
a
l
154 kg/MWh
r
6%
y
P
H
S
50a
y
H
S
20a
y
E
B
20a
u
c
o
a
l
120$/ton
u
c
a
r
4$/ton
ε
2.6Figure 3
Curves of power load and heat load.By solving the OPH and OHP models, the authors get the same result ofTw which is from 23:00 pm to the next day 4:00 am. Heat compensation is required during these periods if the thermal demand and power demand are simultaneously satisfied without wasting wind power. The curtailed wind power and necessary heat compensation of each period are listed in Table 4. Comparison of generated wind power with integrated wind power is shown in Figure 4. Figure 5 presents the curves of Qineed and Pineed. The installed capacity of PHS should be 132.02/0.8 = 165.03 MWh as the aggregated curtailed wind power is 132.02 WMh. The capacity of HS is 278.44/(1-0.04)=290.04 MWh. The capacity of EB is at least 26.84 MW by solving (21)-(22). Investment costs and economic benefits displayed with histograms in Figure 6 are easy to be calculated since the capacities of these facilities have been known. It can be seen that installing HS needs the least investment cost but gets the maximum net benefit by 4660.85$ in the case of integrating the same amount of surplus wind power. The EB solution is only second to HS with the net benefit of 4472.21$ and it creates the most economic benefit by saving coal consumed by electric and thermal power generation concurrently.Table 4
Curtailed wind power and compensated heat power.
Periods
Curtailed Wind/MW
Compensated Heat/MWh
23:00
2.31
4.87
24:00
26.36
55.60
1:00
35.21
74.25
2:00
39.31
82.91
3:00
22.26
46.95
4:00
6.57
13.85
Total
132.02
278.44Figure 4
Comparison of generated and integrated wind power.Figure 5
Curves of essential thermal and electric power.
(a)
Essential thermal powerQineed
(b)
Essential electric powerPineedFigure 6
Investment costs and economic benefits of PHS, HS and EB.


### 4.2. Case  2

The net benefits of different solutions are closely associated with the amount of generated wind power and curtailed wind power. Taking the results in Case  1 as the reference, Figures7 and 8 show the changes of capacities along with the changes of wind power by moving the curve of generated wind power up and down with the step size of 10%.Figure 7
Percentage changes of wind power.Figure 8
Capacity changes of PHS, HS, and EB.As shown in Figure8, the required capacity of PHS is consistent with the variation of wind power. But the capacity of HS tends to decrease when the wind power is increased by more than 50%, which is because the available extra thermal power produced by CHPs for heat accumulation starts to decrease with such high wind power generation during the peak load periods. Moreover, the capacity of EB remains unchanged when the wind power increases by more than 20%, verifying the excellent flexibility of EB in adjusting power output with the amount of surplus wind power.As can be seen from Figure9, the net benefits of installing PHS, HS or EB for accommodating surplus wind power show a significant growth trend. Thus it is definitely profitable to reduce surplus wind power by integrating PHS, HS, or EB into the cogeneration system. In addition, solutions of utilizing HS and EB for heat compensation have distinct advantages of economic benefits in comparison with PHS. And the net benefit created by installing EB comes to be the best when the generated wind power reaches a high level.Figure 9
Net benefit changes of PHS, HS, and EB.


## 4.1. Case  1

In this study, the cogeneration system structure is downscaled based on the actual proportions of installed power energy sources in Northern China. Three CHP units are noted asCHP1,CHP2, andCHP3; two power-only units are noted asCON1 andCON2. The power source structure is listed in Table 1. Detailed information of the units is shown in Table 2. The scheduling period, T, is 24 hours and Δt is 1 hour. D is 180 days. Figure 3 shows the curves of typical daily thermal power load and electric power load. Parameters related to economic analysis are given in Table 3.Table 1
Power source structure.
Power Source
Installed Capacity/MW
Proportion
CHP
800
67.8%
Power-only
250
21.2%
Wind
130
11.0%Table 2
Parameters of CHP and power-only units.
CHP Units
Corner Points
CHP1
CHP2
CHP3
(q1,p1)/MW
(
0,323
)
(
0,310
)
(
0,210
)
(q2,p2)/MW
(
357,241
)
(
320,246
)
(
240,155
)
(q3,p3)/MW
(
154,150
)
(
100,150
)
(
124,100
)
(q4,p4)/MW
(
0,150
)
(
0,170
)
(
0,100
)
Power-only Units
Output Limits
CON1
CON2
Maximum/MW
150
100
Minimum/MW
75
50Table 3
Parameters related to economic analysis.
η
P
H
S
80%
η
H
S
l
o
s
s
4%
η
E
B
98%
α
P
H
S
1%
α
H
S
0.5%
α
E
B
0.5%
u
P
H
S
c
53.1k$/MWh
u
H
S
c
5.3k$/MWh
u
E
B
c
217k$/MW
p
a
v
c
o
a
l
330 kg/MWh
q
a
v
c
o
a
l
154 kg/MWh
r
6%
y
P
H
S
50a
y
H
S
20a
y
E
B
20a
u
c
o
a
l
120$/ton
u
c
a
r
4$/ton
ε
2.6Figure 3
Curves of power load and heat load.By solving the OPH and OHP models, the authors get the same result ofTw which is from 23:00 pm to the next day 4:00 am. Heat compensation is required during these periods if the thermal demand and power demand are simultaneously satisfied without wasting wind power. The curtailed wind power and necessary heat compensation of each period are listed in Table 4. Comparison of generated wind power with integrated wind power is shown in Figure 4. Figure 5 presents the curves of Qineed and Pineed. The installed capacity of PHS should be 132.02/0.8 = 165.03 MWh as the aggregated curtailed wind power is 132.02 WMh. The capacity of HS is 278.44/(1-0.04)=290.04 MWh. The capacity of EB is at least 26.84 MW by solving (21)-(22). Investment costs and economic benefits displayed with histograms in Figure 6 are easy to be calculated since the capacities of these facilities have been known. It can be seen that installing HS needs the least investment cost but gets the maximum net benefit by 4660.85$ in the case of integrating the same amount of surplus wind power. The EB solution is only second to HS with the net benefit of 4472.21$ and it creates the most economic benefit by saving coal consumed by electric and thermal power generation concurrently.Table 4
Curtailed wind power and compensated heat power.
Periods
Curtailed Wind/MW
Compensated Heat/MWh
23:00
2.31
4.87
24:00
26.36
55.60
1:00
35.21
74.25
2:00
39.31
82.91
3:00
22.26
46.95
4:00
6.57
13.85
Total
132.02
278.44Figure 4
Comparison of generated and integrated wind power.Figure 5
Curves of essential thermal and electric power.
(a)
Essential thermal powerQineed
(b)
Essential electric powerPineedFigure 6
Investment costs and economic benefits of PHS, HS and EB.


## 4.2. Case  2

The net benefits of different solutions are closely associated with the amount of generated wind power and curtailed wind power. Taking the results in Case  1 as the reference, Figures7 and 8 show the changes of capacities along with the changes of wind power by moving the curve of generated wind power up and down with the step size of 10%.Figure 7
Percentage changes of wind power.Figure 8
Capacity changes of PHS, HS, and EB.As shown in Figure8, the required capacity of PHS is consistent with the variation of wind power. But the capacity of HS tends to decrease when the wind power is increased by more than 50%, which is because the available extra thermal power produced by CHPs for heat accumulation starts to decrease with such high wind power generation during the peak load periods. Moreover, the capacity of EB remains unchanged when the wind power increases by more than 20%, verifying the excellent flexibility of EB in adjusting power output with the amount of surplus wind power.As can be seen from Figure9, the net benefits of installing PHS, HS or EB for accommodating surplus wind power show a significant growth trend. Thus it is definitely profitable to reduce surplus wind power by integrating PHS, HS, or EB into the cogeneration system. In addition, solutions of utilizing HS and EB for heat compensation have distinct advantages of economic benefits in comparison with PHS. And the net benefit created by installing EB comes to be the best when the generated wind power reaches a high level.Figure 9
Net benefit changes of PHS, HS, and EB.


## 5. Conclusion

This paper presents an evaluation of the economic value of pumped hydrostorage (PHS), heat storage (HS), and electric boiler (EB) in facilitating wind power integration in the cogeneration power system. This evaluation is accomplished by analyzing the investment costs and economic benefits introduced by installing PHS, HS, or EB. Two models denoted as “ordering power by heat (OPH)” model and “ordering heat by power (OHP)” model for obtaining the essential electric power and thermal power required by satisfying the load demand without wind power curtailment are proposed in this study. The minimum capacities of PHS, HS, and EB needed for integrating the same amount of wind power and the subsequent economic analysis are performed on the foundation of the results of these two models.The cases demonstrated the feasibility of accommodating wasted wind power by these auxiliaries. The capacity of PHS which plays the role of electrical storage is determined by the aggregated surplus wind power and it costs much more than HS and EB. It is economical to utilize the HS to alleviate the conflict between wind power and thermal demand. But the capacity of HS is limited by the heating ability of CHPs since the accumulated thermal power is supplied by CHPs. Instead, the EB shows better performance for promotion of wind power integration with superior economic advantage when the proportion of wind power is very high in the system. Therefore, the HS is preferred if the curtailed wind power is not too much while the EB should be given priority if the wind power develops to an even higher level in the future.Although the data is simplified in the cases, the conclusion would not be affected by the accuracy of the calculation. More details involved in the practical projects will be considered in the future research.



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*Source: 1618681-2017-04-05.xml*