I elandi System
Þjórsá-and Tungnaá River System
GUMUNDUR BJÖRNSSON
Master's Degree Proje t
September 2009
XR-EE-ES 2009:014
Royal Institute of Te hnology (KTH)
S hool of Ele tri al Engineering
This master thesis ontains my work of studies of a short term planning
model, with the time span of one week, or168 hours. The models are based
on the future hydropower system in Þjórsá- and Tungnaá- river system, lo-
ated inthe south part of I eland.
The purpose of this thesis is to formulate and develop one week operation
s hedules for this future power generation system, whi h for a given inow-
and loadfore ast returnsagoods hedulefor ea hpower stationsinthe sys-
tem.
The planning problem is formulated as a mathemati al programming prob-
lem. The models used to des ribe and implement the system under study
are a pie ewise linear models. For pie ewise linear models the breakpoints
of the model are the lo al best-e ien y points. The obje tive is to return
operation plan for ea h power station in the system, where the the volume
ofstored waterinthe endof theplanningperiodismaximizedthrough opti-
maldis harge plans. It isneeded tosupply ontra ted load, regulation- and
balan epower forea h hour duringthe planningperiodunder study.
Two test ases are made for ea h model in this thesis. The former ase
des ribe winter operation, with high onsumptions and lower naturalinow
to the reservoirs. In the latter ase the onsumptionis low and riverinow
high and is meant todes ribesummer time operation.
Obtainedresultsshowsthatpie ewiselinearmodelgivesmorerealisti results
when the load onsumption is high and the inow is low. During summer
time, with low load and high inow, the pie ewise linear models s hedule
more often dis harge not on lo al best-e ien y points. This behavior an
be de reased by inserting apenalty ost of dis harge hanges.
Keyword: Short term planning, hydropower, ele tri al generation.
This masters thesis over my work arried out at Ele tri Power System
(EPS), Department of Ele tri alEngineering,Royal Institute ofTe hnology
(KTH) inSto kholm, Sweden.
First I would like to thank my supervisor at EPS, Magnus Olsson for all
his support, patien e and guidelines during my thesis work. I also want to
thankProfessorLennartSöderatEPS forhissupportandforapprovingthis
proje t asthis master'sthesis work.
Within Landsvirkjun I would like to to thank my onta t person Eggert
Guðjónsson, head of generation planning, for hissupport and for givingmy
a ess toallthe system dataneeded for this masterthesis. Alsofor approv-
ingthis idea and givingme an opportunity todothis internalthesis.
Within Landsvirkjun Power I want to thank Guðlaugur V. Þórarinsson,
proje t manager, for giving my a ess to all the proje t planning reports
for the new hydropower stations inlowerriver of Þjórsá.
Sto kholm, September 2009
Guðmundur Björnsson
1 Introdu tion 1
1.1 Ba kground . . . 1
1.2 The aimof the thesis . . . 2
1.3 S ope of thesis . . . 3
1.4 Overview of the thesis . . . 3
2 The I elandi Hydro System 5 2.1 Ele tri energy system inI eland . . . 5
2.2 Hydropower inI eland - histori aloverview. . . 5
2.2.1 The rst period 1904-1934 . . . 6
2.2.2 The se ond period1935-1964 . . . 6
2.2.3 The third period1965 to present days. . . 7
3 The I elandi Ele tri ityMarket 9 3.1 Reformedele tri itymarket . . . 9
3.2 Parti ipants inthe ele tri ity market . . . 9
3.2.1 Transmission system operator . . . 10
3.2.2 Produ ers . . . 10
3.2.3 Balan e responsibility . . . 11
3.2.4 Grid owners . . . 11
3.2.5 Consumers. . . 12
4 The Transmission System in I eland 13 4.1 The transmissionlines . . . 13
4.2 The stru ture of the transmission system . . . 14
5 System Planning 17 5.1 Produ tionplanning . . . 17
5.1.1 Expansion planning. . . 18
5.1.2 Seasonalplanning . . . 18
5.1.3 Short term planning . . . 18
5.2 System operation . . . 19
5.2.1 Frequen y ontrol . . . 19
5.2.2 Primary ontrol . . . 19
5.2.3 Se ondary ontrol . . . 21
6 Modeling of Hydropower Systems 23 6.1 Hydropowergeneration . . . 23
6.2 E ien y and dis harge . . . 24
6.2.1 Hourequivalentof water . . . 25
6.2.2 Produ tionequivalent . . . 25
6.2.3 Constant produ tion equivalent . . . 26
6.2.4 Marginalprodu tionequivalent . . . 26
6.2.5 Relativee ien y . . . 26
6.3 Modelinghydropower generation . . . 27
6.3.1 The linearmodel . . . 27
6.3.2 The pie ewise linear model . . . 28
6.3.3 Totaldis harge and power generation . . . 29
6.4 River inow . . . 30
6.5 Reservoirs . . . 30
6.5.1 Seasonalreservoirs . . . 30
6.5.2 Shortterm reservoirs . . . 31
6.5.3 Reservoirs operation . . . 31
6.5.4 Reservoir onstraints . . . 31
6.6 Spillage . . . 32
6.6.1 Un ontrolled spillage . . . 32
6.6.2 Controlled spillage . . . 32
6.7 Hydrologi al ouplingbetween power stations . . . 32
6.7.1 Delay time between power stations . . . 33
6.8 Reserve requirements . . . 34
6.8.1 Primary ontrol reserve . . . 34
6.8.2 Se ondary ontrolreserve . . . 35
6.9 Penalty ost ondis harge hanges . . . 35
6.10 Short-term planningproblem . . . 37
6.10.1 Formulation ingeneral . . . 37
7 The System Under Study 39 7.1 The NationalPower Company . . . 39
7.2 The power stationsin present system . . . 40
7.2.1 Vatnsfell . . . 40
7.2.2 Sigalda. . . 41
7.2.4 Sultartangi . . . 42
7.2.5 Búrfell . . . 43
7.3 The power stations inthe future system . . . 44
7.3.1 Búðarháls . . . 44
7.3.2 Hvammur . . . 45
7.3.3 Holt . . . 46
7.3.4 Urriðafoss . . . 46
7.4 The model of the system . . . 47
7.4.1 The data used . . . 47
7.4.2 Powergeneration model . . . 48
7.4.3 Contra ted load to supply . . . 48
7.4.4 The inowdata to the system . . . 49
7.4.5 Delay time between powerstations under study . . . . 51
7.4.6 The reservoirsin the system under study . . . 51
7.5 Problemformulation . . . 52
7.5.1 The obje tive fun tions. . . 53
7.5.2 Constraints . . . 54
7.5.3 Limits . . . 55
8 Simulated Cases 57 8.1 Model 1 - Introdu tion . . . 58
8.2 Model 2 - Introdu tion . . . 59
8.3 Model 3 - Introdu tion . . . 60
8.4 Model 4 - Introdu tion . . . 61
9 Results 63 9.1 The layout of the hapter . . . 63
9.2 Generationplanning s hedules . . . 64
9.3 Surplusof powerin the system. . . 65
9.4 Penalty ost ondis harge hanges . . . 68
10 Dis ussions and Con lusions 73 10.1 Dis ussions . . . 73
10.2 Con lusions . . . 75
11 Future Work 77 11.1 Mixedintegerlinear model . . . 77
11.1.1 Spinning reserve. . . 77
11.1.2 Forbidden dis harge. . . 78
11.1.3 Start-up and shut-down osts . . . 78
11.2 Delay time between power stations . . . 78
11.3 Further developments of the proje t . . . 79
11.3.1 Shortterm planning forthe wholesystem . . . 79
11.3.2 Cost of balan epowerin hydropower systems . . . 79
Bibliography 81 A GAMS 85 A.1 General Algebrai ModelingSystem . . . 85
A.1.1 Import and export of data . . . 86
B Figures from Simulated Cases 87
C The Models Statisti s 97
2.1 Total number of hydropower stations in I eland in 2006, in-
stalled apa ity and average annual generation. . . 6
4.1 Lengthof transmission lines at spe i voltage levels. . . 13
7.1 The power stations in Þjórsá- and Tungnaá river area in the
south part of I eland, in present system and expe ted future
system.. . . 47
8.1 Introdu tion tothe dierent simulation ases for ea hmodel . 57
9.1 AveragespillinthesysteminMWh: Win=winter asestudy,
Sum = summer ase study and
Sum ρ = summer ase with
penalty ost. . . 70
C.1 Themodelsstatisti s: Numberof iteration, omputationtime
and the obje tive value for ea h ase study . . . 97
2.1 ThedevelopmentoftheI elandi ele tri itysystemfrom1960-
2007 . . . 8
4.1 The transmissionsystem inI eland 2008. . . 14
6.1 Anexample of ageneration hara teristi s. Power generation asa fun tion of dis harge through astation. . . 27
6.2 Anexampleofarelativee ien yforhydropowerstationwith two units. Samestation as ingure 6.1. . . 27
6.3 A pie ewise linear model of one of the station under study . . 28
7.1 Þjórsá-and Tungnaá- river area insouth part of I eland. . . . 41
7.2 The layout before and after Hvammurpowerstation and Ha- galón reservoir have been built. . . 45
7.3 The layout beforeand after Holtpower station and Árneslón reservoir havebeen built. . . 46
7.4 ThelayoutbeforeandafterUrriðafosspowerstationandHeiðar- lónreservoirhave been built.. . . 47
7.5 Thetotal loadprolesinthe system,the generation ontribu- tion from other stations outside the area and the load under study during the planningperiod. . . 50
8.1 Model 1 - Hydrosystem layout . . . 58
8.2 Model 2 - Hydrosystem layout . . . 59
8.3 Model 3 - Hydrosystem layout . . . 60
8.4 Model 4 - Hydrosystem layout . . . 61
9.1 Winter Case study: Model 1, model 2 and model 4 - Load urvesand generationplans s hedules. . . 66
9.2 Winter Case study - Model 1, model 2 and model 4: Surplus of power inthe system. . . 67
9.3 Model 4 - Summer ase: Generation ontribution with and withoutpenalty ost . . . 69
9.4 Model 4 -Summer ase: Surplusof powerin the system with
and withoutpenalty ost . . . 71
B.1 Model 1 - Winter: Load urve and generation ontribution,
reservoir ontents, dis harge- and generation plan, reserved
power and surplusof power inthe powerstations . . . 88
B.2 Model 2 - Winter: Load urve and generation ontribution,
reservoir ontents, dis harge- and generation plan, reserved
power and surplusof power inthe powerstations . . . 89
B.3 Model 3 - Winter: Load urve and generation ontribution,
reservoir ontents, dis harge- and generation plan, reserved
power and surplusof power inthe powerstations . . . 90
B.4 Model 4 - Winter: Load urve and generation ontribution,
reservoir ontents, dis harge- and generation plan, reserved
power and surplusof power inthe powerstations . . . 91
B.5 Model 3 - Summer: Load urve and generation ontribution,
reservoir ontents, dis harge- and generation plan, reserved
power and surplusof power inthe powerstations . . . 92
B.6 Model 3 - Summer, with penalty ost on dis harge hanges:
Load urve and generation ontribution, reservoir ontents,
dis harge-and generation plan,reserved powerandsurplus of
power inthe power stations . . . 93
B.7 Model 4 - Summer: Load urve and generation ontribution,
reservoir ontents, dis harge- and generation plan, reserved
power and surplusof power inthe powerstations . . . 94
B.8 Model 4 - Summer, with penalty ost on dis harge hanges:
Load urve and generation ontribution, reservoir ontents,
dis harge-and generation plan,reserved powerandsurplus of
power inthe power stations . . . 95
D.1 Layout gures of lower river of Þjórsá. The lo ation of the
Variables: Explanation:
P i (k)
powerprodu tion inpowerstationi
, hourk x i (k)
ontents of reservoiri
atthe end of hourk s i (k)
spillage past powerstationi
duringhourk u i (k)
dis harge in power stationi
during hourk
u i,j (k)
dis harge in power stationi
, segmentj
, duringhourk
Z
obje tive fun tionParameters: Explanation:
u i maximal dis
harge through power stationi x i maximal reservoir
ontents of reservoir i
i
x i,pre preferableupper reservoir
ontents of reservoir i x i,pre preferablelowerreservoir
ontents of reservoiri x i,start start
ontents of reservoir i
i x i,start start
ontents of reservoir i
s i (k)
maximal spillageby power stationi s i (k)
minimalspillage by powerstationi w i (k)
water inow toreservoiri during hour kγ i produ
tionequivalent, power stationi
µ i,j marginal produ
tion equivalent, power station i
, seg-
ment
j
η i relative e
ien
y,power stationi λ f expe
ted future ele
tri
ity pri
e
τ j,i delaytime forthe water between stationj
andthe
los-
est downstream station
i
n i total segments inpower stationi P i installed
apa
ity inpowerstation i P b
ontra
tedbalan
e power
i P b ontra tedbalan e power
P p ontra tedprimary power/ spinningreserve
P R total reserved power
ρ i penalty
ost of dis
harge
hanges, power stationi
Sets: Explanation:
K i set of neighboring power stations dire
tly upstream of
power stationi
N i setofindi esforallpowerstationsdownstreamofreser-
voir
i
,in luding stationi
itselfI
set of allpower stationsin the systemK
time durationinthe planningperiodExplanation:
AGC Automati Generation Control
GAMS General Algebrai Modeling System
GDX GAMS Data Ex hange
GL Gigaliter
LN Landsnet
LP Linear Problem
LV Landsvirkjun
TSO Transmission System Operator
Power stations:
VAF Vatnsfell power station
SIG Sigalda powerstation
HRA Hrauneyjafoss power station
BUD Búðarháls powerstation
SUL Sultartangi powerstation
BUR Búrfell power station
HVA Hvammurpowerstation
HOL Holt powerstation
URR Urriðafoss power station
STE Steingrímsstöð power station
LJO Ljósifoss power station
IRA Írafoss power station
BLA Blanda power station
LAX Laxá powerstation
KRA Kraa powerstation
BJA Bjarnarag power station
KAR Kárahnjúkar powerstation
I elandi letters in the thesis:
Þ /þ Dened asTh / th inenglish
/ ð Dened asD / d inenglish
Introdu tion
1.1 Ba kground
Renewable energy sour es are be oming more and more importantat same
time as the threats of limate hanges are in reasing due to pollution. An
importantbenetofrenewableenergysour eslikewind-,hydro-andgeother-
malpoweris that it is lean and does not ontributeto pollution.
I eland is small ountry ompared to other nations, where the population
isin ex ess of threehundred thousand and due tothat the publi ele tri ity
onsumption is very low. The I elandi power system is not onne ted to
othergridsinother ountriesandhas noopportunitytotransport ele tri ity
ross borders likemany other ountries.
I elandhavelargepotentialinhydro- andgeothermalpowerand onlyapart
of the apa ity, whi h te hni ally an be harnessed, have been harnessed
today. Due to this large potential in environmental friendly power sour es,
manyprodu tion ompanies haveshown theirinterests toinvest inenergyin
I eland. Su h ompaniesare forexamplealuminiumsmeltersand ompanies
inthe eld of data banks enters and a produ ersof solar ells.
Be ause of in reased energy requests, many power ompanies in the oun-
try have started their preparation pro ess for planning new power stations,
who might be build in nearest future, both in the eld of geothermal and
hydropower.
The national power ompany of I eland - Landsvirkjun has re ently started
operation of a 690 MW power station, at Kárahnjúkar in the eastern part
of I eland, mainly build to over ele tri al onsumption in new aluminium
smelter. To be able to meet in reased energy request during oming years,
Landsvirkjunisplanningtoexpanditsgeneration apa itywithinhydropower
insouth part of I eland.
1.2 The aim of the thesis
Thepurposewiththisproje tistoobtaineknowledgeoftheupgradedpower-
and river system in the south part of I eland. In the area, named after the
twomainrivers, ÞjórsáandTungnaá, totalfournewhydropowerstationsare
planned tobebuild in the future.
Three of these new hydropower stations will be lo ated in the lower part
ofÞjórsáriverand thesethree stationswillallbeinseries mostdownstream
in the river. The fourth station is planned to be built in the middle of the
river system. That station would harness water from Tungnaá riverand its
lo ation isthe fourth most downstream inthe present system.
The aimof the thesis istoformulateand develop one week operations hed-
ules for the future power generation system in the south part of I eland,
whi h for a given load- and inow fore ast produ e a good s hedule of the
power stations in the system where the obje tive fun tion is to operate the
stations as often on their lo albest-e ien y points and by that maximize
the value of stored water in the end of the planning period.
Furthermore the aim is to run dierent ases with dierent numbers of hy-
dropower stations, ree ting the new system in southern I eland. These
dierent ases are studied for dierent situations in load and inow to the
system, with the aim to ree t summer- and winter time situations in the
future system.
Theaimisalsotostudy howthe stationsparti ipateinsupplying ontra ted
load during the planning period for ea h ase. Further to investigate if the
balan e-and primary power is fullled, and how great surplus of se ondary
1.3 S ope of thesis
Thes opeofthis thesisistostudy shorttermhydropowerplanningwiththe
times aleofoneweekofthehydropowersysteminÞjórsá-andTungnaáriver
area in south part of I eland. Time period for longer time than one week
will not be under study here therefore seasonal planning or su h questions
are therefore not onsidered inthis thesis.
The model of the power generation hara teristi s inthis thesis ispie ewise
Linear Programming 1
modeling approximation of the dis harge-generation
urve. Another way and also interesting when study multi ma hine hy-
dropower system is to modeling the system as Mixed Integer Linear Pro-
gramming 2
problem, but su h problem isnot withinthe s ope of this thesis
and willnot be onsidered here.
Combinations of units whi h are on-line or o-line is therefore not stud-
ied. Questions regarding how the primary ontrolreserve is shared between
onlineunits an thereforenot be al ulated wherenobinary variableswhi h
presents ombination of on-line units are in use. Due to this limitationthe
totalsurplusofpowerinea hpowerstationeveryhouristhereforeonly on-
sidered in total, but not how the power surplus is divided down to on-line
units.
With same reasoning, start-up and shut-down osts of units or minimum
start-and stop times an notbetaken intoa ount,whereonly LP-modelis
used in this thesis. Units starts and stops are therefore outside the s ope of
the thesis.
1.4 Overview of the thesis
Chapter 2 ontains a presentation of the whole I elandi ele tri power sys-
tem. An introdu tion to the history of ele tri ation and development of
hydropower produ tion inI eland is given. Also introdu tions tothe devel-
opment inthe ele tri onsumptionare presented.
Chapter 3 ontains an overview over the I elandi ele tri ity market, its
parti ipants, the transmission system operator, produ ers, grid owners and
onsumers inI eland.
1
LP
2
Chapter 4 ontains an overview over the transmission system in I eland,
itsstru ture and its hara teristi s feature isexplained briey.
Chapter 5 ontain des riptions of theory regarding dierent planning peri-
ods, expansion-, seasonal-andshort termplanning. Powersystem operation
ispresented and introdu tiontofrequen y-, primary- and se ondary ontrol
isgiven
Chapter 6 ontains the theoreti al part of the thesis. This hapter ontains
the theory behind modeling of hydropower systems. Not only the theory
used in the thesis, but also the theory that might be used to develop and
improve the work already donein a later stage and infuture work.
Chapter 7 ontains short des ription of Landsvirkjun, the National power
ompany of I eland. Introdu tion is given to ea h of Landsvirkjun's power
stations in the present and future systems in the area under study. How
the system is modeled, how the problem is formulated and how the theory
andtheideasfrom hapter6areusedduringthatworkispresentedindetail.
Chapters8 ontains presentationsof test ases,the summerand wintertime
simulationsas well as introdu tion to howthe penalty ost is implemented.
The layout of allthe fourmodels models are presented.
Chapter 9 ontains sele ted part of obtained results of the onsidered ases
inthe models understudy.
Chapter 10 ontains dis ussions about obtained results and what on lu-
sion mightbe drawn from obtained results.
Chapter 11 ontains some ideas and suggestion about how the models an
The I elandi Hydro System
This hapter ontainsa presentation of the I elandi hydro ele tri al system.
Introdu tionsofthepowerprodu tion,as wellas theele tri onsumptionare
presented. An overview over thehistori al stages of ele tri ation in I eland
are given.
2.1 Ele tri energy system in I eland
Total installed apa ity in the I elandi power system in 2008 was 2.574
MW. The share of hydropower in total installed power is 1.879 MW, 575
MW omes from geothermal power and 120 MW from fuel power stations,
but fuel power are mainlyused as ba k-upstations aroundthe ountry [2℄.
Total ele tri energy produ tion in I eland in 2008 was 16.467 GWh, whi h
isequallytoyearly onsumptionofbarely52MWhperinhabitantinI eland.
Between the years 2007 and 2008 the ele tri al generation in reased about
27%mainlyduetoin reasedenergy onsumptioninthe aluminiumindustry,
wherenew aluminiumsmelterstartedoperation. In 2008 around75% ofthe
ele tri ity was generated with hydropower and 25% with geothermal power
inI eland [2℄ .
2.2 Hydropower in I eland - histori al overview
The history of ele tri ation in I eland an roughly be divided to three pe-
riods. In 2006 total 235 hydropower stations are re orded and registered in
I eland. Almost80%aresmallerthan100kWandusedasprivategenerators
on the ountry side [5℄. Table 2.1 gives overview over installedhydropower
inI eland in 2006.
2.2.1 The rst period 1904-1934
The rst period lasted from 1904 to 1934, but the rst hydropower turbine
ame onstream in De ember in 1904. This was a small hydropower station
whi h ele tried a arpenters workshop and manage to ele trify 12 other
houses in nearest surroundings as well. This small hydropower station had
installed apa ity of 6 kW and lo ated in Hafnarfjörður lose to Reykjavik
[27℄.
The rst hydropower station with alternating urrent generation was built
in Seyðisfjörður, in the east part of I eland in 1913. In the beginning, the
power station namedFjarðarselsvirkjun, had an installed apa ity of 55 kW
andsuppliedthe town andits losest surroundings. This wastherst power
stationwhomanagedtoele trifyamuni ipalityonitsown. Todaythis isthe
oldestpowerstationstillinoperationandhavebeenupgradedto172kW[27℄.
The largest hydropower station built within the period was 1.1 MW sta-
tion,built 1919-1921,ownedand operatedby ity ofReykjavik. The station
be amethelargestoneinsixteenyearsandwasbuiltwiththeaimtoele trify
Reykjavik and was lo ated onthe outskirts of the town. Today this station
isstill inoperation but has been upgraded to3.2 MW.
2.2.2 The se ond period 1935-1964
During the years from 1935 to 1964 whi h an bedened as the se ond pe-
riod, a larger hydropower stations were built to meet in reasing population
density in the south west and north part of the ountry. In the beginning
of the period the onsumption in reased mainly be ause of general use of
Installed Numberof Totalinstalled Average annual
apa ity [MW℄ stations apa ity [MW℄ generation [GWh/year℄
0-0,1 180 3,6 25
0,1-1,0 30 9,3 69
1,0-10,0 15 47 415
10-100 5 207 985
>100 5 900 5.520
Total: 235 1.167 7.015
Table 2.1: Totalnumberof hydropowerstations inI elandin2006, installed
ele tri alequipmentathomes, butduring theyears 1953-1964 thepowerin-
tensive industry took larger share of the total ele tri al onsumption. Main
intensive industryat this time was afertiliser- and a ement fa tory.
During these ondperiod,the ity ofReykjavik startedtheSog PowerCom-
pany. The ompany build threehydropowerstation inthe area of Sog, lose
to Reykjavík. The power stations ame on stream the years 1937, 1953
and 1959. The stations are owned and operated by Landsvirkun sin e 1966,
when Reykjavik ity in orporated the stations into Landsvirkjun as part of
the owner's founding ontribution.
Tomeet the in reased onsumptiondue toin reased populationdensity,the
town of Akureyri started the Laxá Power Company, who build three hy-
dropowerstationsinthe riverofLaxá inthenorth east partof I eland. The
aimwastoele trifythe townofAkureyriand itsnearestsurroundings. From
1983 this stationshavebeen owned and operatedby Landsvirkun, whenthe
town of Akureyri in orporatedthe stations intoLandsvirkjun aspart of the
owner's founding ontribution.
2.2.3 The third period 1965 to present days
At the beginningof the sixties a dis ussions took pla e about howit would
be possible to utilize the ountry's energy resour es and at same time to
in rease theexports fromI eland,whi hatthis timewere almostonlybased
onsh produ ts.
The government founded a ommittee with the aim to investigate the pos-
sibilities to start up power intensive industry in I eland. Where the alu-
miniumpro ess isveryenergy onsumingindustry,andthealuminumindus-
try through the world was growing atthis time it was anattra tive idea to
start up aluminiumsmelter as an option to utilize the energy resour es for
ele tri algeneration.
In 1965 the national power ompany of I eland - Landsvirkjun was estab-
lished. The role of Landsvirkjun at this time was tobuild and operate new
powerstations with the aim tosupply the futures power intensive industry.
The dis ussions between the ommittee and foreign power intensive ompa-
nies resulted in an agreement for a onstru tion of an aluminum smelter.
The rst aluminum smelter, then owned by ISAL and Landsvirkjun's rst
Figure 2.1: The development of the I elandi ele tri ity system from 1960-
2007
From 1969, Landsvirkjun has built total eight hydropower stations. Five
are lo ated in the south part of I eland, in the Þjórsá- and Tungnaá river,
one in the north part and the new hydropower station in Kárahnjúkararea
inthe east part if I eland, who started operation inNovember 2007. These
power stations were more orless built parallelto new onsumers within the
intensiveindustry, su h as aluminium-and ferrosili onsmelters.
From 1965 to2008 the ele tri algeneration inI eland have in reased about
96% and about 73% during the twenty years period, from 1988 to 2008. In
gure 2.1 it an be seen how the power system has developed through the
years and how the system has been build up duringthe periodfrom1960 to
The I elandi Ele tri ity Market
This hapter ontains a short introdu tion of the I elandi ele tri ity mar-
ket. A presentation of the I elandi transmissionsystem and its stru ture is
given.
3.1 Reformed ele tri ity market
TheI elandi ele tri itymarketbe amereformedandee tiveinstagesfrom
July 2003, whenall ompanies inthe eld of powerintensive industry ould
hoose its supplier. In January 2005, all nal onsumers who were power
measured ould hoose their own suppliers. The third and the last stage
be ame ee tive in the middle of the year 2006 when all users were able to
hoose theirsupplier of ele tri ity [22℄.
ThepurposeofthenewEle tri ityA tisto ontributetoane onomi alele -
tri itysystem andtoenable ompetitioninthesales ofpower, by separating
the produ tionand saleof ele tri ity fromthe transmissionand distribution
part of the powersystem, whi h willremaina monopoly.
3.2 Parti ipants in the ele tri ity market
Theparti ipantsonthe ele tri itymarkethavebeen gainingtheirexperien e
inafreemarketenvironmentthelast oupleofyears. Comparedtoele tri ity
markets inother ountries, the stru tureof the I elandi marketis dierent.
The market ontain no spot marketand the transmission system is isolated
from other ountries, so no ross border trading with ele tri ity is possible
with other ountries.
Whentheele tri itymarketwasformed,thestru tureand layoutofmarkets
in other ountries were taken into onsideration, but the market is though
partly ustom-made toI elandi ontext andwillbe under onstru tionand
development asparti ipantsgain their market experien e [10℄.
3.2.1 Transmission system operator
The transmission system operator (TSO)is responsible for onstantly keep-
ing all te hni al requirements in the power system within limits, su h as
voltagesand tomaintainthe frequen y requirementsby keepingthemomen-
tarybalan ebetweenprodu tionand onsumptioninthe powersystem. The
system operator has alsothe responsibility for keeping the spinning reserve
in the system within limits to be able to supply primary power when it is
needed.
The system operator is also a onsumer on the market, where he is respon-
sible for buypowerto over the losses in the transmission system.
The system operator in I eland is Landsnet. The owners of Landsnet are
threepower ompanies,Landsvirkjun-TheNationalPowerCompany,RARIK-
I eland State Ele tri ity, Orkuveita Reykjavíkur (Reykjavik Energy) and
Westfjord Power Company, whi h all put their distribution system and all
itsequipment into Landsnet as equity.
All power intensive onsumers and the distributors are onne ted to Land-
snet'stransmissionsystemaswellasallpowerstationswithsevenmegawatts
of installed apa ity and higher. Further,it isalso apart of Landsnet's rule
tomanagethe powertrading onthe balan ing marketand maintain enough
primary reserve powerfor se ured operationof the power system.
3.2.2 Produ ers
The produ erson anele tri ity marketare those who own and operates the
power stationsand produ ethe ele tri ity.
Landsvirkjun produ e ele tri ity for the power intensive industry and for
the wholesale market. The time span of power ontra ts within the power
intensiveindustry deviate between 20-40 years. No spotmarket is inopera-
long term ontra ts. The time spanof ontra ts today withother produ ers
orretailers,wherethe ele tri ityissold tothelo alhouseholds, isinformof
one, three, seven ortwelve years ontra ts.
In addition to Landsvirkjun, there are two other large produ ers on the
I elandi market. TheseareReykjavíkEnergy andSuðurnesHeading,whi h
operate a geothermal power stations. Additionally four other parti ipants
are onthe I elandi ele tri ity markettoday. Threeof them are lo alpower
ompanies, lo ated in the West-fjords, north part and east part of I eland
and one whi h are lo ated all around the ountry, These parti ipants also
operates their own power stations, but in small s ale and buy energy on
wholesale for aresale within their lo alarea.
3.2.3 Balan e responsibility
It an never be known in advan e how mu h ele tri ity ea h onsumer on-
sume and thereforeat sametime how mu hele tri ity ea h produ er ispro-
du ingtimetotime. Ingeneral,thedeviationin onsumptionandprodu tion
between expe tedandrealtime onsumptionis overed bytheplayersonthe
marked whi h are balan eresponsible orbalan eprovider.
The transmission system operator is responsible for the safety and stabil-
ity of the power system. In order to ompensate for the deviation between
plannedgenerationandrealtimegeneration,the TSOthereforeneedstobuy
balan epower onthe balan ing market to over the dieren e.
This balan epoweris boughtfrom Landsvirkjun, who isthe onlyprodu ers
who has ontra ts with Landsnet as a balan e provider. The minimum re-
quirementsforthe volumeof balan epowerinI eland isset to
±
40MWh/hfor upward- and downward regulation.
Primary power reserve is also needed in the system. Where Landsvirkjun
is the only large produ er with hydropower, the ompany has signed a long
term ontra twithLandsnetforhavingtotal100 MWh/hofprimaryreserve
power in the whole ountry. This power is distributed and lo ated in the
south, north and east part of the island and explained in hapter 4.
3.2.4 Grid owners
Themain roleof thegrid owners istomaintain andoperate thegrid intheir
power inowand poweroutowinthe grid. Where some losses o ur inthe
system, the grid owner is responsible to over these losses and needtherefor
tobuy ele tri ity to over these losses inhisown system.
3.2.5 Consumers
Consumers are all from normal households to large onsumers, like power
intensiveindustries. All onsumershavetosigna ontra t withtheprodu er
they want to buy the ele tri ity from. Further this same onsumers have to
sign a ontra t with the grid owners tobe onne ted tohisnetwork and get
The Transmission System in
I eland
4.1 The transmission lines
Allmainele tri altransmissionlinesinI elandisoperatedbyLandsnet. The
maintransmissionsystem onsistsoflines withvoltagelevelbetween 132 kV
and 220 kV. Landsnet also operates few lines on lower voltages su h as 66
kV and 33kV whi halsoare part of the transmission system [10℄.
ThetotallengthoftransmissionlinesinI elandis2.911km. Totallengthfor
ea hvoltagelevel an beseen intable 4.1. The highesttransmissionvoltage
inI elandis220kV,but the mostre entlines arebuilt for400kVvoltageto
be able tomeet in reased onsumption in the future. This lines are though
urrently operated at 220 KV.The round onne tion around the ountry is
operated at132 kV.
Length of transmission lines atspe i voltage level km
220 kV 612
132 kV 1.244
33 kV and 66 kV 1.055
Totallength of transmission lines: 2.911
Table 4.1: Lengthof transmission lines at spe i voltagelevels.
4.2 The stru ture of the transmission system
The transmission system as it looks today is presented in gure 4.1. As
mentioned all power stations above seven megawatts of installed power are
onne ted to the transmission system. Total 19 su h onne tion points for
inow of power are in the system today. The onne tion points where en-
ergy is taken out from the transmission system today is on 57 pla es and
onne tion points for power intensive industry have four onne tion points
tothe system. Landsnet's transmissionsystem is shown in gure4.1, where
the system is divided up tove areas roundthe ountry [11℄.
Figure4.1: The transmissionsystem inI eland 2008.
Areaone - the south part, in ludeslarge amount of hydropower stationand
approximately40%ofinstalledpowerinthe I elandi system. Thetransmis-
sion networkis strong inthis area and onsistsof meshed 220 kV lines. The
produ tionis dominant in area one and therefore a high share of the power
istransmittedtosouth west part, wherethe main onsumptioninI eland is
lo ated. Totalprimarypowerreserveinthe areais60MWh/handislo ated
inthe power stationsat Þórsá- and Tungnaáriverarea [11℄.
tion in the system and most of the largest onsumer, Reykjavik ity and
surrounding towns, as well as three of four ompanies within the power in-
tensive industry. The power stations in this area are mostly geothermal
power stations with approximately 20% of total installed power in the sys-
tem. Large volume of imported power is needed to supply the onsumption
inthe area. This power istransmittedfrom the southpart 1
and north part 2
through the west part of I eland [11℄.
Area tree - the west part of I eland and the west fjords in ludesquite weak
transmission system with long 132 kV as well as 66 kV lines. This area has
small share of energy produ tion, therefore it is needed to import largest
share of onsumed power to the area from north part of I eland, from area
four[11℄.
Area four - the north part of I eland ontains long 132 kV transmission
lines whi h is a part of the round- onne ted lines round the island. In the
north part, the onsumption is low ompared tothe generated power inthe
area. Installed power in the north part of I eland is approximately 10% of
installedpowerinthesystem, where7%ishydropowerand3%isgeothermal
power. Surplus of power in area four is transmitted out from the area and
even to the west- and/or east part of I eland. Total primary power reserve
intheareais10MWh/handislo atedinthehydropowerstationBlanda[11℄.
Area ve - the east and southeast part of I eland onsist of long 132 kV
whi h form part of the round onne tion round I eland. Also 220 kV lines
from the new Fljótsdalurstation to the aluminiumsmelterin the east part,
around 50 km distan e. Approximately 30% of installed power in the I e-
landi system are lo ated in this area. The majority of generated power is
suppliedto the Aluminium smelter,but alsoit is transmissionto- and from
thenorth-andsouthpart ifI eland. Totalprimarypowerreserve inthe area
is 30 MWh/h and is lo ated in the new hydropower station at the Kárahn-
júkar area [11℄.
Compared to total supplied power to the transmission system in 2008, the
total losses in the transmission system be ame 400 GWh or 2,4% of trans-
mittedpower [2℄
1
Areaonein gure4.1
2
System Planning
This hapter ontains introdu tion of dierent planning periods used when
operationof powersystemsareplanned. Theideabehindthetheoryregarding
system operation and frequen y ontrol isgiven.
5.1 Produ tion planning
Whenpowerstationsare operated,itmaybeoneof themostimportanttask
for the owner and the operator,to run the units in su h a way that natural
resour esare utilizedinasoptimalway aspossible. Bydoingthatthepower
station owner maximize itsin ome at same time, whi h must be one of the
main issue.
When produ tion plans for hydropower systems are made, wheremany sta-
tionsandmanylo alinowrivers arein luded,manyparametersneedstobe
taken intoa ount to makereliable, e ien y and useable produ tionplan.
Many parameter like inow and onsumptions are not known in advan e.
Therefore some un ertainties o ur in ea h made s hedule, whi h lead to
that planning s hedules are needed to be made over and over again, when
new and more reliabledata are a essible.
Byupdatingimportantparameters onstantlywithnewinformationgivethe
planner opportunity to make asreliable produ tion plan as possible though
it willneverbeperfe t.
Dierent planning periods and planningmethods an be dened in atleast
three groups:
•
ExpansionPlanning•
SeasonalPlanning•
ShortTerm Planning5.1.1 Expansion planning
The time horizon within expansion planning an be years or even de ades.
Within the time horizon of expansion planning, power produ ers makes a
s hedule for futures proje ts like building new power stations. When on-
siderexpansionplanningthe un ertaintyisobviouswhere theplanninghave
to onsider the future growth in ele tri al onsumption, the environmental
impa tas wellas development of investment and operational ost [20℄.
5.1.2 Seasonal planning
Thetimehorizonwithinseasonalplanningisbetween6-12months. Theaim
with seasonal planningis tomake s hedule for the water storagewithin the
timehorizonandmakede isionsaboutappropriatetimeoflargemaintenan e
workinthepowerstations[25℄. Themainun ertainties inseasonalplanning
are the riverinow, availabilityof powerstations and the load.
5.1.3 Short term planning
The time horizon within short term planning is from one week down to 24
hours. Theaimofshort termplanningistomakes heduleforthepowersta-
tions understudy. The s hedule has to full ontra ts about sold ele tri ity
as well as the requirement regarding reserved power and other physi al re-
quirements. In short termplanning, more detaileddes riptionsof the power
stationsareneeded aswellasthehydrologi al ouplingsbetween thestations
have tobewellknown tomakereasonableprodu tionanddis hargeplan for
the whole system.
In short term planningthe un ertainties are mainlythe same asin seasonal
planning. Butwhereshortterm plannings hedulesare madedailyandeven
several times per day, when and if new and more reliabledata appears, the
variationof the un ertainties are not aslarge asfor largerplanninghorizons
[20℄.
system intoa ount. If there is any bottlene ks due to amaintenan e work
in the transmission system on spe i area. If that is the ase it may ee t
the operation of the power stations inthe nearest surrounding.
5.2 System operation
Ele tri alenergy an not bestored. Duetothat reason, allele tri alenergy
needtobegeneratedatsametimeasitis onsumed. Thetransmissionsystem
operatoris responsibleto keep momentarilybalan ebetween the generation
and onsumption in a power system and maintain se ure operation of the
system.
5.2.1 Frequen y ontrol
Tokeepthemomentarybalan ebetween theprodu tionand onsumptionin
a power system it is ne essary to have automati ontrol system whi h an
respond within few se onds to deviation between generation and onsump-
tion. Su hautomati ontrolsystem is alledprimaryregulationand itsaim
is tostabilizethe frequen y in the power system.
When disturban es o ur in a power system, where loss of load or loss of
generation o ur, the new stable frequen y will deviate from the nominal
value. The new frequen y will be higher - for the ase with loss of load, or
lower - inthe ase of loss of generation.
Whenthe primary ontrolreservehasbeen usedtostabilizethe frequen yin
the powersystem afterdisturban es, anadditional ontrolis needed toreset
the frequen y toitsnominalvalues. Todothat, se ondary ontrolis usedto
regain the primary ontrol ba k, whi h then an be used again during next
disturban es.
5.2.2 Primary ontrol
Primary ontrol determines the apa ity of the power system to meet un-
expe ted load- or generation hanges. Primary power is automati ontrol
systemwiththe aimtokeep themomentarybalan ebetween generationand
onsumption. The total primary power in multi ma hine hydropower sys-
tem, are dened as the sum of dieren e between the maximum generation
apa ity for the ombination of units s heduled on line and their present
In a syn hronous power system, the deviationbetween produ tion and on-
sumptiono ursinfrequen y deviationinthe system. Thenominalvalueof
the frequen y an vary between power systems and ountries. In North and
South Ameri a the nominal value is usually 60 Hz, whereas in the Nordi
ountries, Europe and most of the remaining world uses 50 Hz [26℄.
Asmentionedbefore, energy an not bestored ina power system,but there
isalarge rotationalmass storedinthe system, so alledmoment ofinertia -
rotating. Thismassisstoredinalltherotatingsyn hronous rotorsandtheir
turbineshafts.
Assume loss of generating unit ina syn hronous power system. From other
generatorspointofview, lossofgenerationisequaltoin reaseinload. Right
after the failure in this generating unit, there is a shortage of power in the
system.
Sin e the generation and the onsumption always need to to be in balan e,
the de it of power is ompensated by using the rotational energy in the
rotors and their shafts, whi h lead to de rease in rotational speed of all the
rotatingma hines inthe system.
Where there is a strong onne tion between rotor speed and ele tri fre-
quen y in syn hronous ma hines, the redu ed rotor speed results in a fre-
quen y de rease in the grid.
To response to the falling frequen y in the grid, frequen y sensitive equip-
ment, lo ated onsome of the primary ontrolunits in hydropower stations,
give a signalto in rease the openingof the guidevane of the turbines to in-
reasethedis hargethrough theturbine, andatsametimethe poweroutput
fromthe generator.
When parti ipating generators in the primary ontrol have in reased their
generationto ompensateforthelostunit,thefrequen y stopde reasingand
stabilizeagain, but atfrequen y lower than the nominalfrequen y. Balan e
has been obtained between generation and onsumption again.
Similar ourses of events appears in the ase of load de rease or genera-
tion in rease. Then only dieren e is that the frequen y in reases, whi h
results in need of de rease the generation in units parti ipating to the pri-
How mu h ea h generators parti ipate in the primary ontrol depends on
their installed frequen y sensitive equipment. Generally, the minimum re-
quirements of speed droop hara teristi s is set by the transmission system
operator inea h ountry.
The I elandi TSO has set minimum requirements regarding the volume
of speed droop hara teristi s to 400 MW/Hz. As des ribed in Chapter
4, the spinning reserve requirements is now set to total 100 MWh/h in the
whole ountry. Additionalminimumbalan epowerneededtobeavailablefor
upward- and downward regulation on the balan ing market is
±
40MWh/hfor se ondary response ontrol.
Sin ethe I elandi system issmall omparedwiththe powersysteminother
ountries, allthe dynami alswings happen very fast. Therefore the need of
systems su h as fast and well tuned fault breakers and frequen y sensitive
equipments are of grate important.
5.2.3 Se ondary ontrol
The primary ontrol only stabilize the frequen y in the power system. It
does not restorethe system frequen y to the nominalfrequen y again.
Afterthefrequen yinthepowersystemisstable,apartofitssystemreserve
has been usedup tomaintain thebalan ebetween generationand onsump-
tion. In su h ondition, the system isnot able towithstand another faultor
hanges inthe system inform of lostgeneration orin reased load.
It is therefore important to restore the frequen y to its nominal value, to
release the primary ontrol reserves and by that prepare the system to be
able towithstand another faultand frequen y deviation.
Tosolvethesekindofproblemsthese ondary ontrolisused. These ondary
ontrolisslowresponse ontroland an bea tivatedwithin fewminutes. In
the Nordi ountries all se ondary ontrol is ontrolled manually from the
ontrolroomsof the system operators,whi h allforup- ordown regulation
fromthe balan eproviders on the ele tri ity market.
In some powersystems, where the I elandi system is amongthem, the se -
ondary ontrolismanaged with automati generation ontrol(AGC), tore-
reserves.
Modeling of Hydropower Systems
This hapter ontains the theoreti al part of the thesis - the theory behind
modelingahydropowersystem. Apartofthetheoryintrodu edinthis hapter
are then used to built the simulation models studied in the test ases.
6.1 Hydropower generation
Hydropower generation utilizes the dieren e in potential energy between
the headwater surfa e and the tailwater surfa e for power produ tion. The
layout anddesign ofhydropower stationsare largelyinuen ed by lo alnat-
ural onditionsand the generation apa ity isusually expressed inkilowatts
(kW) for small power generation or megawatts (MW) for large power gen-
eration. The sele tion is based on a areful evaluation of several important
parameters, i.e. the gross head and the dis harge. The gross head is the
dieren e inelevation between the the headwater surfa e, and the tailwater
surfa e.
Inthepro esswhendeliveringthe waterfromtheintakegate,down thepen-
sto k intothe turbine losses o urs resultingin de reased gross head. With
in reased dis harge through a hydropower station the gross head de rease
where the headwater surfa e lowered a bit and in same way the tailwater
surfa e rise. Also the losses will in rease in the pensto k with in reased
dis harge. The losses are therefore a fun tion of the head- and tailwater
surfa e level or up- and downstream reservoirs levels. The generation in a
hydropowerstationwillthereforebeafun tionofup-and downstreamreser-
voirlevel as wellas the dis harge through the turbines [23℄,[21℄.
The losses has an impa t on the station's e ien y often alled station or
plant e ien y [23℄. The plant e ien y des ribes how large share of the
potential energy stored in the water in the reservoirs an be onverted to
ele tri alenergy.
The main losses in ahydropower station, ee ting the station e ien y are
informoflossesinawaterways,turbineandgenerator. Wherenotwopower
stationshaveneitherthe samelayout nor the same design,their statione-
ien y are dierent. Forea h powerstation the e ien y,
η tot, is a onstant
and an be dened as [23℄:
η tot = η w · η t · η g (6.1)
where
η w is the e
ien
y in a waterways, η t is turbine e
ien
y and η g the
η g the
e ien y inthe generator. Normal values of thesee ien ies anbearound
η w ≈ 0.90
,η t ≈ 0.93
andη g ≈ 0.98
[23℄.The power outputof a hydropower station isproportionaltothe produ tof
the head and dis harge and within the statione ien y it an be expressed
as:
P = ρ · g · H · u · η tot (6.2)
where
P= powerprodu tion[kW℄
ρ
= water density [kg/litre℄g= a elerationdue to gravity [m/s
2
℄
H =gross head [m℄
u= dis hargethrough the station [m
3
/s℄
The total energy produ tion, over a time period an then be al ulated
as:
E =
Z
P (t) dt
[MWh℄ (6.3)6.2 E ien y and dis harge
Oneof the hara teristi sforhydropowersystemis limitationamountofen-
ergy. The energy is stored in the reservoirs, in form of water, and an be
used for ele tri alprodu tion in the future. Where this energy is limited it
optimalway aspossible.
To be able to operate a hydropower system in e ien y way a model is
needed to des ribe the ouplings between dierent parts of the system su h
asreservoirsandtheriversaswellasthepowerstationslo atedinthesystem.
Forshorttermplanningproblemsitisimportanttoobtainasdetailedrepre-
sentationofthepowerstationsaspossiblewheretheoutputoftheshort-term
planning s hedule will be used to operate the system during the up oming
planningperiod.
To determine a generation in a power station it is ne essary toobtain data
aboutitsgeneration hara teristi swhi hdes ribesthe generationasafun -
tion of the dis harge through the station and data about the station's e-
ien y.
Few on epts are needed to des ribe a hara teristi s for a power station.
This on epts haveto be lear in mindand well dened when modeling and
al ulating the power generation in a hydropower station. These on epts
are theprodu tionequivalent,marginalprodu tionequivalentand e ien y
orrelative e ien y.
6.2.1 Hour equivalent of water
In following se tions within this hapter the water dis harge, water spillage
and reservoir ontents are all dened in the equations as hour equivalents
[HE℄.One HE orresponds to the volume of 1m
3
/s water dis harged during
one hour, whi h means 3600 m
3
[26℄.
6.2.2 Produ tion equivalent
The produ tion equivalent is the quota between energy generation and the
dis harge through the turbines and is dierent for dierent dis harge. The
produ tionequivalentishere denoted by
γ
and measured inMWh/HE. Ob-taining data for a generation and dis harge, the produ tion equivalent for
powerstation
i
atthe dis hargeu
an be al ulated by [26℄:γ i (u) = P i (u)
u
[MWh/HE℄ (6.4)6.2.3 Constant produ tion equivalent
The onstant produ tion equivalent, for power station
i
at the dis hargeu
an be dened as the onstant:
γ i = P i
u
[MWh/HE℄ (6.5)where
P i and u
are installed
apa
ity for power station i
and maximal dis-
harge through the station respe tively.
6.2.4 Marginal produ tion equivalent
To measure how mu h the power generation will deviate for a small hange
indis hargethe marginalprodu tionequivalentisintrodu ed. Themarginal
produ tionequivalentis de lared as:
µ = d
du P (u)
[MWh/HE℄ (6.6)6.2.5 Relative e ien y
The relative e ien y is a measure of how mu h energy an be extra ted
fromea hm
3
ofwater omparedtothemaximalpossible,i.e. itmeasure the
produ tionequivalentfor some dis harge ompared tothe maximal produ -
tion equivalent obtained for the power station.
Therelativee ien y ispresented as
η
and is measured inper ent. Havinga ess todata showing produ tion equivalentas afun tion of the dis harge,
the relativeprodu tion equivalent an be al ulated as:
η(u) = γ(u) γ max
[%℄ (6.7)
where
γ maxisthemaximalprodu tionequivalentobtainedforthestation[26℄.
If the main obje t of a short-term planning s hedule was only to onsider
the energy generation, without taking other onstraints into a ount, then
the power stations would always been operated attheir maximal e ien y.
For a station with more than one unit, it an be preferable to share the
dis harge between the units in su h a way that the e ien y is maximized,
whereforea h ombinationofunits,therewillbealo albest-e ien ypoint
0 50 100 150 200 250 300 350 0
20 40 60 80 100 120 140
Generation vs. Discharge
Discharge [m 3 /s]
Generation [MW]
Figure 6.1: An example of a genera-
tion hara teristi s. Power generation
as a fun tion of dis harge through a
station.
0 50 100 150 200 250 300 350
0.5 0.6 0.7 0.8 0.9 1
Relative Efficiency vs Dicharge
Discharge [m 3 /s]
Relative Efficiency
Figure 6.2: An example of a relative
e ien y for hydropower station with
two units. Same station as in gure
6.1.
Figures 6.1 and 6.2 shows a generation as a fun tion of dis harge and the
relativee ien y urverespe tivelyforoneofthe powerstationunderstudy.
As anbeseen ingure6.2 alo albest-e ien ypointappearforea h om-
bination of units. When the dis harge rea h the lo al best-e ien y point
with highest dis harge the e ien y de rease fast.
During high load periods, or during spring oods and summer time when
largeinowisintothe system,powerstationsmightbeoperatedabove their
lo albest-e ien y pointwith highest ow toavoidspillage.
6.3 Modeling hydropower generation
Where the relationbetween power generation, dis harge and head is a non-
linearornon- on averelationship,itissomehowneeded toapproximatethis
relationstobeabletomodelingthepowergenerationasalinearprogramming
problem. Several models are on ave approximations of this non-linear or
non- on averelationshipsasthepowergenerationis. The mostsimplestand
ommon models for the generation hara teristi s are a linear model and a
pie ewise linear model.
6.3.1 The linear model
In a linear model the generation is proportional to the dis harge and have
lem.
On the other hand, using linear model have several disadvantages. In a
linear model the solutionmay often ontain operation points far away from
the lo albest e ien y points,resulting inlow e ien y solutions point.
Also itis not possible to onsider osts for start-ups or shutdowns in power
stationsnor forbiddendis harge intervals. Tobeable totakethis point into
a ountmixed integerlinear programminghas to be onsideredwith binary
integerstopresentthe unitstatusinthepowerstations[20℄,[21℄, butwillnot
be onsidered inthis thesis.
6.3.2 The pie ewise linear model
In the pie ewise linear model, shown in gure 6.3, the generation asa fun -
tion of the dis harge isdivided into one ormore segments. The breakpoints
between the segments are lo ated to those dis harges where lo al maxima
appears inthe e ien y. This isone of the main advantages with the pie e-
wise linear model, be ause these dis harges are then more likely to appear
inthe solution for s heduled dis harge. The marginalprodu tionequivalent
0 50 100 150 200 250 300 350
0 20 40 60 80 100 120 140
Generation vs. Discharge
Generation [MW]
0 50 100 150 200 250 300 350
0.5 0.6 0.7 0.8 0.9 1
Relative Efficiency vs Dicharge
Discharge [m 3 /s]
Relative Efficiency
µ i,1
µ i,2
µ i,3
u i,1
u i,2
u i,3
for station
i
and in ea h segmentj
is approximated by the onstantµ i,j,
a ording togure 6.3 and alsoinequation (6.6) [26℄.
But it is however possible that the model give solution, where s heduled
power stations are not operated lose to their lo al best-e ien y points.
In gure 6.3 it an be seen that if the dis harge is between the lo al best-
e ien y points the power generation will be overestimated. On the other
hand,ifs heduleddis hargeisplannedbetweenthelo albest-e ien ypoint
with highest dis harge and maximaldis harge through the station,the gen-
eration willbeunderestimated [21℄,[20℄.
So the model work properly the marginal produ tion equivalent have to be
de reasing with in reased number of segments. That is, generation in the
rst segment have to be more protable than the se ond segment, se ond
segment has to bemore protable than the thirdand soon.
Here, protable means that more ele tri energy an by subtra ted out of
ea h HE of water. To fulll this requirements following have to be valid
µ i,j > µ i,k if j < k
. Here µ i,j is the marginalprodu
tion equivalent inpower
station iand segmentj [26℄.
6.3.3 Total dis harge and power generation
Where the marginalprodu tionequivalent isapproximated by a onstantin
ea h segment, the total dis harge through power station have tobe divided
in one variable per segment. For the power station i, the total dis harge
through the power station an mathemati ally be expressed as:
u i (k) =
n i
X
j=1
u i,j (k)
(6.8)u i (k)
= dis harge through power stationi, during hourk.u i,j (k)
= dis harge in power station i,segment j, during hour k.n i = numberof segmentsin power stationi.
The total power generation in a power station an then be expressed as
:
P i (k) =
n i
X
j=1
µ i,j u i,j (k)
(6.9)P i (k)
= power generation inpowerstation i,during hour k.µ i,j = marginal produ tion equivalent in power station i, seg-
6.4 River inow
To be able to make reliable produ tion plans for a hydropower system and
operatethe system in anoptimalmanner, itis importanttohave asreliable
inowfore asttoea hpowerstationand reservoir inthe systemaspossible.
Inthisthesisthe riverinowtopowerstation
i
duringhourk
isexpressed asw i (k)
. Weather onditions su hasrain, temperatureand snow meltinghave great ee t on the river inow. However it an be very di ult to make agood fore ast wherethe weatherfore asts is not always reliable.
For a short term planning, whi h normally span the time s ale from one
day to one week, it is ommon approximation to onsider the fore asts for
the riverinow and the ele tri al onsumptions asperfe t and reliable fore-
asts. Whennew fore asts are available forthe riverinowor onsumptions
the s hedules are updated.
6.5 Reservoirs
Where the ele tri al onsumption is high during periods when natural ow
in the rivers are low, like during winter time, reservoirs are needed to store
the water, whi hthen an beused for energy generation later in the future.
Many reservoirs are often lo ated in the same river system, with dierent
ontents volume and dierent role fromthe system operation point of view.
Thereservoirswithlargestvolume ontentsinariversystem arenormallylo-
atedintheupperpartof thesystem, whilethesmallerreservoirarelo ated
inthe lowerpart.
6.5.1 Seasonal reservoirs
Some reservoirs have large storage volume in order to store water from the
spring ood to the winter when the onsumption is high. These type of
reservoirs are normally lo ated in the upper part of the river system, as
previouslymentioned,andarenormallyusedforlongtermorseasonalenergy
storage. If there is no rivers onne ted to the system downstream, these
6.5.2 Short term reservoirs
Reservoirs used for water storage on weekly and daily basis are normally
lo ated in the lower part of the river system. These kind of reservoirs are
often used for short term operation su h as weekly or daily operation of a
powerstationsandarenormallylo atedinthelowerpartoftheriversystem.
6.5.3 Reservoirs operation
Reservoirwitha powerstation downstreammay have somerequirementsre-
garding how mu h the water level in a reservoir an variate up and down
from some spe i normal level time to time. Often the normal operation
levelforareservoirisdened fromthe situationwhen allunits forthepower
stationunder study are inoperation. Theserequirementsmay be set due to
environmental orte hni al reasons and an variatefor dierent periods and
dierent season of the year.
From a ele tri al produ er point of view it is also important to keep the
reservoirlevelwithin spe i limitstoobtain and maintain good generation
e ien y.
6.5.4 Reservoir onstraints
For a power station
i
, with the reservoir storage ontentsx i, it may be
desirable to keep the reservoir level within some upper and lower limits,
denedhereas
x iandx irespe
tively. Preferableoperationlevelofareservoir
for apower stationi
an then be be dened as:
i
an then be be dened as:x i (k) ≤ x i (k) ≤ x i (k)
(6.10)Requirementsregarding how fast the water surfa e an beregulated up and
down an also be found in some reservoirs. Normally this an be found in
those reservoirs where the reservoirs ontents are quite small or where the
reservoirswater levelis sensitivedue toinow, dis harge orspillage.
Su h onstraints an also be found where large and high dis harging hy-
dropower station is lo ated with many units. These stations are often able
todis harge large volume of water through the turbines duringshort period
6.6 Spillage
The spillageisthe volumeof water owing froma reservoir, by apowersta-
tion without owing through the turbines. Here, the spillage, dened as
s
,inpowerstation
i
hourk
is expressed ass i (k)
.Spillage an be ontrolled and un ontrolled. Controlled spill an havelower
limit
s i and anupperlimits i.
s i (k) ≤ s i (k) ≤ s i (k)
(6.11)6.6.1 Un ontrolled spillage
Un ontrolled spillage an appears during spring oods when river inow is
large and all the reservoirs in the system are full and an not store more
water. During su h situation the water ows normally over the spe ially
designed overowspillways on the dam and down its naturalriverbed.
6.6.2 Controlled spillage
Controlled spillage is the ontents of water owing through a ontrollable
gates. Due to environmental reasons it may be stated by spe ial water- or
environmental ourt that it may be needed to spill some minimum ow of
waterpast apowerstation,down naturalriverbed whi hotherwise wouldbe
dry.
It may also be needed to spill water during maintenan e periods to fulll
minimumrequiredinows todownstreampowerstations,where somepower
stationsdo not have any naturalinow. Howsu h power stationsare oper-
ated fromhour tohour, depends on howthe losest power stationupstream
are operated atsame time and the spillage fromthat power station.
6.7 Hydrologi al oupling between power sta-
tions
Hydropower stations an form quite ompli ated system when they are lo-
ated in the same river with many reservoirs, dierent in size and with dif-
ferent role in the system. Cas aded power stations form a oupled system
where the operation of the power stations lo ated in the upper part of the