Optimum Investment Planning and Operation
of Local Hybrid Energy Systems from the
End-User’s Perspective
Andreas Fleischhacker
Energy Economics Group (EEG), TU Wien
ENERDAY 2015, Session: Investment Planning
17.04.2015, Dresden (DE)
Agenda
Motivation Methodology Technical Model Investment Model Model‘s Assumptions Scenario Definition − Disaggregated − Aggregated Results Disaggregated Results − Single-Family-House − Business Aggregated Results ConclusionMotivation and Central Question
Expansion or ‘open field‘ planning of energy system in local areas requires a multiple energy carrier approach.
Consider multiple final energy carriers to determine the optimum energy strategy.
Multidimensional synergies: Co- and Trigeneration. Reduce overall CO2 footprint.
Increasing utilization of small distributed energy resources for generation of heat and electricity.
Which kind of technology or technology mix provides the most
economical energy supply of the different consumption types of
the considered project areas?
Developed within the project:
INFRA-PLAN „Planning energy-border infrastructure
Methodology
to determine economic efficiency from the end user‘s perspective. Formulated by an opimization problem consisting of:
Investment Model
objective function = „net-present-value“ (NPV) restrictions: economies of scale: maintenance costs investment costs calculation of fuel costs own consumption revenues Technical Model restrictions: supply = demand minimum/maximum power conversion coefficients and
efficiency
dependence on the weather demand,
solar thermal systems, photovoltaic systems decentralized feed-in
Technical Model
input energy storages not grid connected demand output energy storages energy conversion grid connected Optimization Problem of one coupling pointInvestment Model (1/2)
The optimization problem‘s objective function (maximum „net-present-value“): ,y,t ,y,t 8760 ,Q , 0 , , ,y,t ,y,t 1 8760 , , , , ,y,t ,y,t 1 , , max 1 (1 ) (Q , 1 , , ( )(Q , wit ) h ( ) i i i bin L y Y y i i i y i i y t i i t i i i y i i i y t i y t i i i i t i y t NPV ( p) bin I bin CF L ( r)
bin I psf(r, p l Y)bin CIF COF L
CIF l ∈Ι ∈Ι = ∈Ι ∈Ι = = = + ∆ + = − + + = − + ∆ ∆ ∆ −
∑
∑∑
∑
∑
∑
∑
,y,t ,y,t ,y, ,y,t ,y,t
, , ,y,t ,y,t ,y, ,y,t ,y,t ,y, ,y,t ,y,t
Q , (Q , (Q , (Q , (Q ) ) ) ) , ) i i i t i i i y t i i i t i i Maintenan i t i i L Revenues L COF L FuelCosts L ce L = = + Legend
bin ... binary variable
CF ... cash flow
CIF ... cash inflow
COF ... cash outflow
i ... investment possibility I ... investment costs ∆p ... price development factor r ... discount rate ∆l ... load development factor (e.g. renovation) psf ... price scenario factor
Investment Model (2/2)
including INV into the technical model:
available 2010-2020 available 2020-2030 available 2030-2040 available 2040-2050 invest in boiler 2010 1 1 0 0 invest in boiler 2020 0 1 1 0 invest in boiler 2030 0 0 1 1 invest in boiler 2040 0 0 0 1 ,
Investment Matrix: invi y = INV
, , ,y, y t i y i t i Demand inv L ∈Ι =
∑
Expand the investment possibilities by flexible investment time points and taking the lifetime into account.
Model‘s Assumptions
investment possibilities:
■ electrical grid
■ district heating system
■ heat pump (sole-water)
■ heat pump (air-water)
■ gas boiler ■ µCHP
■ photovoltaic ■ biomass boiler ■ solarthermal plant
connection to not more than two grids:
electricity and natural gas, electricity and heating etc.
preinstalled heat storage
simulation of one year with a resolution of 15min
modelled by MATLAB and YALMIP Toolbox
solver: gurobi
discount factor of 2%
only maximum power can be installed of each investment − electricity generation
− heat generation
, max( ( ))
max electricity demand electricit
P = P y,t
, max( Deman ( ))
max heat d
Scenario Definition – Disaggregated View (End User)
A1) baseline scenario:
no increase in fuel prices
reflect the consumers investment behavior A2) decrease in electricity prices:
reduction in electricity prices by 5% annually
increase in fossil fuel and district heating prices by 5% annually A3) increase in natural gas price:
no increase in the electricity and district heating prices increase in fossil fuel prices by 5% annually
Scenario Definition – Aggregated View (Spatial Distribution of
Different End Users Types)
considering only the heat supply with grid connected heat generators project region „Reininghaus“ in Graz (AT)
splitting the area in 44 zones
modelling the investment path up to 2050 B1) baseline scenario:
low renovation
moderate price increase (electricity, natural gas, district heating) of 2% B2) high renovation scenario:
high renovation
moderate price increase (electricity, natural gas, district heating) of 2%
Results – Overview
A) Disaggregated Results:
single-family house (passive house standard) - three scenarios (A1-A3)
- „Levelized Costs of Electricity/Heat“ (scenario: decrease in electricity prices), calculation by:
business customers: three scenarios (A1-A3) B) Aggregated Results:
project region „Reininghaus“ in Graz (AT) two scenarios (B1-B2) 8760 , 1 / 8760 / 1 ( , , , ) ( . ( , , ) ( ) ) norm i i t electricity heat electricity he t t i a I psf r p l Y COF t LC crf r l Y Demand t ∈ = = Ι + ∆ ∆ = ∆
∑
∑
∑
C LegendCnorm,i ... normalized trans-formation matrix
bin ... binary variable
COF ... cash outflow
crf ... capital recovery factor
I ... investment costs
∆l ... load development factor (e.g renovation)
∆p ... price development factor
∆l ... load development factor (e.g renovation)
r ... discount rate
psf ... price scenario factor
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Rank
electrical grid district heating heat pump (sole) heat pump (air) gas boiler
A) Single-Family-House (Passiv)
A1) baseline scenario
A2) decrease in electricity prices
A3) increase in
natural gas price
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Rank
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
0 50 100 150 200 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Level iz ed Co st s i n EUR/ M Wh Rank
A) Single-Family-House (Passiv) - Levelized Costs of Electricity/Heat
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Rank solarthermal plant biomass boiler photovoltaik µCHP gas boiler heat pump (air) heat pump (sole) district heating electrical grid Levelized Costs of Electricity Levelized Costs of Heat add A2) decrease in electricity prices 0 50 100 150 200 250 300 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Level iz ed Co st s i n EUR/ M Wh Rank
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Rank
electrical grid district heating heat pump (sole) heat pump (air) gas boiler
A) Business
A1) baseline scenario
A2) decrease in electricity prices
A3) increase in
natural gas price
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
Rank
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15
B) Aggregated Results
B1) baseline scenario, with parameters: - rate of renovation: 3%
- renovation effect: 10% heat energy saving of construction class D, E, F and G
district heating natural gas not defined heat pump district heating natural gas not defined heat pump district heating natural gas not defined district heating natural gas not defined heat pump 2015 - 2020 2020 - 2030 2030 - 2040 2040 - 2050
B) Aggregated Results
B2) high renovation scenario, with parameters: - rate of renovation: 3%
- renovation effect: 60% heat energy saving of construction class D, E, F and G
district heating natural gas not defined heat pump district heating natural gas not defined heat pump district heating natural gas not defined heat pump district heating natural gas not defined heat pump 2015 - 2020 2020 - 2030 2030 - 2040 2040 - 2050
Conclusion (1/2)
Small-Scale Customers
Most economic for heat generation: 1. natural gas boiler
2. district heating
3. electric heat pump (AT) / biomass (DE)
Trade-Off between renovation costs and resulting high energy prices (especially district heating) due to high fix costs.
low potential of PV surplus power in heat pumps for heating cooling small hybrid composite advantages
Conclusion (2/2)
Medium/Large-Sized Customers
Most economic for heat generation : 1. natural gas: boiler / µCHP (DE)
2. electric heat pump (AT) / biomass (DE) 3. district heating (AT/DE)
high electricity prices support distributed self-generation (benefit of economies of scale)
− µCHP
− heat storages − PV
Andreas Fleischhacker
Vienna University of Technology
Energy Economic Group, EEG
Gußhausstraße 25-29 / E370-3
1040 Vienna, Austria
[T] +43 1 58801 370 361
[F] +43 1 58801 370 397
[E] fleischhacker@eeg.tuwien.ac.at
[W] http://www.eeg.tuwien.ac.at
… hybrid?
Source: IBA (2014)
http://www.iba-hamburg.de/projekte/energiebunke r/projekt/energiebunker.html
Data
consumer energy prices (DE)
Households Business Source
Electricity 298 EUR/MWh 230 EUR/MWh eurostat (2014), BDEW (2014), own calculations
Natural Gas 68 EUR/MWh 57 EUR/MWh eurostat (2014), own calculations
District Heating 89 EUR/MWh 71 EUR/MWh Bundeskartellamt (2012), own calculations