quantifying co savings from wind power:...
TRANSCRIPT
Quantifying CO2 savings from wind power
Ireland
Joseph Wheatley
October 4 2012
Abstract
The contribution of wind power generation to operational CO2 sav-ings is investigated for the Irish electricity grid Wind contributed 17of electricity demand in 2011 and reduced CO2 emissions by 9 Windenergy saved 028 tCO2MWh on average relative to a grid carbon in-tensity in the absence of wind of 053tCO2MWh Emissions savings areat the lower end of expectations It is likely that this reflects decreasingeffectiveness of wind power as wind penetration increases
1 Outline of the problem
Increase in atmospheric greenhouse gases due mainly to burning of hydrocar-bons and coal is shifting the Earthrsquos radiative balance in favour of a warmerclimate[1] Reduction of industrial CO2 emissions is a major focus of global en-vironmental policy One widely adopted policy measure are state supports forwind power[2] on the grounds that wind power displaces fossil fuel generationand so reduces emissions State supports have included mandatory targets feed-in tariffs subsidised finance for infrastructure etc As a consequence significantamounts of wind power have been embedded into electrothermal generation sys-tems It has been known for some time that thermal generation responds in anon-trivial way when operated in parallel to stochastic power sources to meetsystem demand Not all thermal plant are displaced equally with flexible andorhigh marginal cost generation being displaced the most Average efficiency isreduced and higher cycling rates occur than would otherwise be the case Allof these effects tend to reduce the effectiveness of wind power in meeting itrsquosprimary policy goal namely emissions reduction
The task of quantifying emissions savings from wind power is not straight-forward Electricity grids are complex systems with many competing com-ponents and feedbacks Moreover every grid has a different combination offuel-mix generator types wind penetration interconnection despatch prac-tices etc Estimates of emissions savings have ranged widely[3] from higher thangrid average[4 5] to near zero[6 7] Savings assumptions by public authoritieshave trended lower over time[8] Meanwhile despatch models have demonstrated
1
that marginal savings decrease as installed wind capacity increases[9 10] andthat high levels of wind penetration may even be counterproductive in terms ofemissions[11]
Empirical approaches based on real world grid data can help shed furtherlight on these issues Ireland is a good empirical test case for the followingreasons
1 high average wind penetration (17 in 2011)
2 minimal electricity exports means that virtually all wind generation mustbe accommodated on the domestic grid
3 modern thermal plant portfolio with large amounts of relatively flexiblegas generation (asymp 58 of demand) as well as coal and peat plant
4 zero nuclear and a low level of hydro (asymp 2)
5 Irelandrsquos highly volatile wind resource favours statistical even over rela-tively short timeframes such as one year
6 availability of relatively high frequency grid data and mandatory emissionsreporting at plant level under EU-ETS[12]
The Irish grid operator[13] reports approximate system demand wind gen-eration and total CO2 emissions rate every 1
4 -hour It is easy to obtain a pre-liminary estimate of emissions savings from this dataset Linear regression ofthe time-series of grid carbon intensity (emissions rate per unit demand) ontowind penetration (wind generation per unit demand) gives a zero-wind emis-sions intensity of 051tCO2MWh and wind power savings 035tCO2MWh in2011 This is equivalent to a displacement effectiveness of just 65 A plausi-ble interpretation is that wind power displaces primarily clean gas (which havetypical emissions asymp 035tCO2MWh) rather than high emissions coal or peat
While these numbers are suggestive their origin and accuracy are unclearFirstly aggregate numbers cannot show which generators or fuels are beingdisplaced by wind power Secondly cycling effects (startup and ramping ofthermal plant) are not included in the carbon emissions algorithm used by thegrid operator Thirdly the role played by interconnection (electricity importsand exports) is unclear Fourthly the result for emissions savings is sensitiveto the correlation between wind generation and system demand Spurious cor-relation may be present because approximate wind generation is used in thecalculation of system demand
In this study time-series of CO2 emissions are estimated for each grid-connected thermal unit in 2011 This calculation is based on generation dataand physical characteristics of each generator Additional emissions due to start-ups are included Based on this CO2 data and a careful treatment of the windand system demand we estimate wind savings of -028tCO2MWh with impliedeffectiveness of only 53 Some implications of these numbers are discussed atthe end of the article
2
2 Data and model
Data on the Irish electricity grid is available from a number of sources[13][14][15]The Single Electricity Market Operator (SEMO) provide 1
2 -hourly generationdata ldquoEx Post Initialrdquo metered generation data is compiled four days after gen-eration date for invoicing purposes This accurate dataset is used here SEMOprovide a loss factor adjusted total metered generation (ldquoMGLFrdquo) time-serieswhich includes all domestic generation as well as power traded via intercon-nectors to Northern Ireland Each power source is weighted by a unit specifictransmission system loss factor which also depends on time of day and seasonMGLF is a proxy for total end-user demand because accurate balance betweengeneration and demand is required at all times in order to maintain grid fre-quency stability MGLF is very similar but not identical to the real-time systemdemand recorded by the grid operator (correlation 099)[13] A time-series ofnet intra-jurisdiction importsexports is also available (ldquoNIJIrdquo)
Under the priority despatch rule for wind conventional generation mustadjust continuously to match system demand minus wind generation Fromthe point of view of the conventional generation system wind generation is anexogenous random variable which reduces effective demand but also makes itmore volatile Figure 1 The aim is to find out what impact this has on individualthermal generators SEMO provides 1
2 -hourly metered generation data (ldquoMGrdquo)data on all grid-connected generators[15] Excluding wind power 54 generatorssupply the Irish grid 35 of these are thermal the rest are small hydropumpedstorage units Descriptions of thermal generators such as fuel type maximumcapacity etc are given in Table 3[15]
Wind generation is the sum of the outputs of more than 130 wind farmsMost of these are smaller installations connected to the distribution systemSEMO also provide 1
2 -hourly MG data for wind farms but there are gaps in thisdataset Some kind of statistical modelling is required to recover total windgeneration To do this generation data for 36 of the largest wind farms whichwere fully operational during 2011 (20 transmission and 16 distribution systemconnected) were compiled The sum of the capacities of this sample amountedto asymp 2
3 of the total installed wind capacity during 2011 The time-series of totaloutput from the sample was normalised upwards to reflect the correct totalinstalled monthly wind capacity (this allows for asymp 200MW increase in windcapacity during 2011) This is expected to be a good approximation becausewind generation is highly correlated in space and in time1 The estimate of windgeneration resulting from the procedure is similar to the real-time estimate ofthe grid operator (correlation amp 099)[13]
In all the generator dataset used in this study contains close to 2 milliondata points A visualisation of the dataset showing 1
2 -hourly generation fraction
1The physical reason for this is that the maximum linear separation of wind farms on theIrish grid is much less that the extent of typical mid-latitude weather systems which bringwindy or calm conditions For example the correlation between wind generation at Meentycatin extreme North-West and Carnsore in the extreme South-East is 047 Autocorrelation isalso very strong eg 12 hour lagged correlation is 065
3
by fuel type ( ldquofuel-mix plotrdquo) is shown in 2 [17] Gas is the dominant powersource (53) and it is displaced when wind generation is present
To model CO2 emissions detailed physical characteristics of individual ther-mal generators are required Parameters listed in Tables 34 are used by electric-ity market participants to determine fuel use and support despatch decisions[16]Table 4 gives Incremental Heat Rate Slopes (GJMWh) which are defined be-tween a set of capacity points (MW) specific to each generator Together withzero-load energy use (GJh) these can be inverted to find the rate of energyuse by the generator at each capacity point Full input-output curves were thenconstructed by cubic spline interpolation These input-output curves give theemissions rate when a generator is operated in steady state at any point between0MW and MaxCap (making use of fuel CO2 emission factors[14]) In practicegenerators can only operate in steady state only between MinCap and MaxCapor as spinning reserve (at 0MW)
Once input-output curves have been constructed they can be combined withgeneration data to create emissions time-series for each unit2 Total emissionscalculated in this way include the effects of generation mix and part-load effi-ciency Emissions from this model were 1164Mt in 2011 compared to 1167Mtusing the grid operator data[13] The two emissions time-series are similar butnot identical with a correlation of asymp 097 Further tests on the validity of thismodel are described below
Additional emissions arising from cycling (start-ups) can be calculated usingparameters in Table 3 Fuel costs (in GJ) depend on thermal state of thegenerator at start-up (Hot Warm or Cold) With appropriate initial conditionsa thermal state time-series is constructed for each generator using transitiontimes between the states (HotToWarm and WarmToCold) provided in Table 3Startup fuel which may be different from the primary fuel type in some cases(eg for coal generators startup fuel is a 68-32 oilcoal mixture) Figure3 shows an example of the emissions associated with a coal generator Startupemissions in 2011 were 014MtCO2 bringing total emissions to 1178MtCO2This compares to verified emissions of 1184MtCO2
2One peat generator (ldquoED1rdquo) was 15 co-fired with biomass material in 2011 This meansthat under emissions rules itrsquos net emissions are reduced by the same factor
4
Figure
1ndash
Upp
er
Dem
and
(MG
LF
bla
ck)
and
esti
mate
dw
ind
pow
ergen
erati
on
(gre
en)
Mea
ndem
and
is2813M
W
Mea
nw
ind
was
467M
Ww
ith
capaci
tyfa
ctor
was
30
T
he
corr
elati
on
bet
wee
nw
ind
gen
erati
on
and
dem
and
iscl
ose
toze
ro(asymp
00
5)
Low
er
Eff
ecti
ve
dem
and
(=dem
and
-w
ind)
as
seen
by
conven
tional
pla
nt
Eff
ecti
ve
dem
and
isasymp
38
more
vola
tile
than
syst
emdem
and
5
Figure 2 ndash Left Half-hourly fuel mix time-series (generation fraction) for 2011derived from SEMO data Right corresponding CO2-mix time series The verti-cal scale is day of year Mean generation fractions were (1) gas (+chp) 58 (2)wind 17 (3) coal 15 (4) peat 8 Mean emissions fractions on the other handwere (1) gas (+chp) 49 (2) coal 31 (3) peat 19
6
Figure 3 ndash Top Metered generation(MW) from coal generator MP2 (Money-point power station) during 2011 The red lines correspond to maximum andminimum stable operating capacities Thermal state (Cold Warm Hot) are in-dicated by colours blue brown black Bottom corresponding CO2 emissionsrate (tCO2h) The spikes in emissions correspond to cycling (start up) eventsFor visualisation and modelling convenience all cycling emissions are assumed tooccur within a half hour interval
As a consistency test of the emissions model comparison can be made withannual power plant emissions reported under to the European Emissions TradingScheme (EU-ETS) for 2011[12] These data provide an independent test of theemissions model because they are based on actual fuel consumption informationcollected using stock accounting principles To convert to CO2 standard emis-sions factors are associated with each fuel (although in the case of coal emissionsfactors can vary significantly from year to year) To make contact with thesedata the emissions time-series of the 35 thermal generators are aggregated into11 power plant and annual emissions calculated These data provide both aconsistency check and model constraint as illustrated in 4 In all agreementis satisfactory and is particularly good for gas base-load (Combined Cycle Gas
7
Turbine or CCGT) plant It is not surprising that errors are somewhat larger forintermittently used ldquopeakingrdquo plant but these form only a very small fractionof total emissions
Figure 4 ndash Comparison of model and reported power station emissions in 2011Carbon intensities (tCO2MWh) based on emissions reported under EU-ETS areshown in light colours while modeled values are shown in heavy colors Baseloadgas (CCGT) plant have lowest emissions intensities Emissions factors used toconvert from energy units to emissions (TWhtCO2) were coal = 899 peat= 1167 oil = 714 gas= 569 Verified EU-ETS emissions at Aughinish includeemissions unrelated to electric power generation for the grid so these have beenset to the model value
In fact the above emissions model is incomplete Ramping a thermal gen-erator burns additional fuel even when no start-ups occur This arises when agenerator is ramped between MinCap and MaxCap as in Figure 3 for exam-ple Simply summing emissions based on the generatorrsquos input-output curve asdone above does not capture this effect This additional source of emissions hasbeen emphasised particularly by le Pair Udo and de Groot[6] and is likely tobe especially significant in the case of less flexible base-load plant[18] Ramp-ing emissions were not included in the calculation described above primarilybecause no model parameterisations of this effect are available However inview of the good agreement between reported values and model there is no ev-idence of a large missing source of emissions from ramping (order of magnitudesim 01MtCO2) Emissions from CCGT gas plant in particular seem to be ac-curately described Nevertheless on physical grounds we know such emissionsdo exist and are likely to increase as wind penetration increases
3 Results and Discussion
Fuel-mix plots[13] (Figure 2) show that wind displaces gas generation and toa lesser extent coal Peat and gas CHP plant are operated on a ldquomust runrdquobasis These plant respond to system demand but they are not displaced bywind The CO2-mix plot in Figure 2 is calculated using the emissions modeldescribed above Coal and peat play a far larger role in the CO2 mix For
8
example peat provided only 8 of generation but produced 19 of emissionsWind power displaces gas generation and therefore it is not surprising thatperiods of high wind generation are associated with lower emissions from gasplant This can be seen clearly from Figure 5
Figure 5 ndash Left CO2 emission rates for gas coal and peat fuel generators as afunction of total system demand High wind generation is indicated in light blueand low wind generation is shown in dark blue Right Empirical probabilitydistribution for CO2 emission rates for ldquohighrdquo (green) and ldquolowrdquo (pink windgeneration ie lower or higher than the median wind generation The coal andgas plant portfolio is more likely to be found in a low emission state at high windgeneration This effect is far stronger for gas than for coal
Emissions intensity fall linearly with wind penetration A summary of thelinear regression fit is shown in Table 1 The intercept 053tCO2MWh corre-sponds to grid average emissions intensity in the absence of wind The fittedslope -028tCO2MWh corresponds to emissions savings due to wind genera-tion The displacement effectiveness of wind power is therefore just 53 (Ifstart-up emissions are omitted the fit parameters become 052tCO2MWh and03tCO2MWh respectively) If there was no wind in 2011 emissions wouldhave been 129MtCO2 versus 118MtCO2 observed ie a savings of asymp 9
It seems surprising at first sight that emissions savings of 028tCO2MWhis less than the emissions intensity of the cleanest thermal generators on thegrid Figure 4 To understand how this arises it is necessary to drill downand see how individual generators respond to wind generation In general therelationship between an individual generator and total system demand (or total
9
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
that marginal savings decrease as installed wind capacity increases[9 10] andthat high levels of wind penetration may even be counterproductive in terms ofemissions[11]
Empirical approaches based on real world grid data can help shed furtherlight on these issues Ireland is a good empirical test case for the followingreasons
1 high average wind penetration (17 in 2011)
2 minimal electricity exports means that virtually all wind generation mustbe accommodated on the domestic grid
3 modern thermal plant portfolio with large amounts of relatively flexiblegas generation (asymp 58 of demand) as well as coal and peat plant
4 zero nuclear and a low level of hydro (asymp 2)
5 Irelandrsquos highly volatile wind resource favours statistical even over rela-tively short timeframes such as one year
6 availability of relatively high frequency grid data and mandatory emissionsreporting at plant level under EU-ETS[12]
The Irish grid operator[13] reports approximate system demand wind gen-eration and total CO2 emissions rate every 1
4 -hour It is easy to obtain a pre-liminary estimate of emissions savings from this dataset Linear regression ofthe time-series of grid carbon intensity (emissions rate per unit demand) ontowind penetration (wind generation per unit demand) gives a zero-wind emis-sions intensity of 051tCO2MWh and wind power savings 035tCO2MWh in2011 This is equivalent to a displacement effectiveness of just 65 A plausi-ble interpretation is that wind power displaces primarily clean gas (which havetypical emissions asymp 035tCO2MWh) rather than high emissions coal or peat
While these numbers are suggestive their origin and accuracy are unclearFirstly aggregate numbers cannot show which generators or fuels are beingdisplaced by wind power Secondly cycling effects (startup and ramping ofthermal plant) are not included in the carbon emissions algorithm used by thegrid operator Thirdly the role played by interconnection (electricity importsand exports) is unclear Fourthly the result for emissions savings is sensitiveto the correlation between wind generation and system demand Spurious cor-relation may be present because approximate wind generation is used in thecalculation of system demand
In this study time-series of CO2 emissions are estimated for each grid-connected thermal unit in 2011 This calculation is based on generation dataand physical characteristics of each generator Additional emissions due to start-ups are included Based on this CO2 data and a careful treatment of the windand system demand we estimate wind savings of -028tCO2MWh with impliedeffectiveness of only 53 Some implications of these numbers are discussed atthe end of the article
2
2 Data and model
Data on the Irish electricity grid is available from a number of sources[13][14][15]The Single Electricity Market Operator (SEMO) provide 1
2 -hourly generationdata ldquoEx Post Initialrdquo metered generation data is compiled four days after gen-eration date for invoicing purposes This accurate dataset is used here SEMOprovide a loss factor adjusted total metered generation (ldquoMGLFrdquo) time-serieswhich includes all domestic generation as well as power traded via intercon-nectors to Northern Ireland Each power source is weighted by a unit specifictransmission system loss factor which also depends on time of day and seasonMGLF is a proxy for total end-user demand because accurate balance betweengeneration and demand is required at all times in order to maintain grid fre-quency stability MGLF is very similar but not identical to the real-time systemdemand recorded by the grid operator (correlation 099)[13] A time-series ofnet intra-jurisdiction importsexports is also available (ldquoNIJIrdquo)
Under the priority despatch rule for wind conventional generation mustadjust continuously to match system demand minus wind generation Fromthe point of view of the conventional generation system wind generation is anexogenous random variable which reduces effective demand but also makes itmore volatile Figure 1 The aim is to find out what impact this has on individualthermal generators SEMO provides 1
2 -hourly metered generation data (ldquoMGrdquo)data on all grid-connected generators[15] Excluding wind power 54 generatorssupply the Irish grid 35 of these are thermal the rest are small hydropumpedstorage units Descriptions of thermal generators such as fuel type maximumcapacity etc are given in Table 3[15]
Wind generation is the sum of the outputs of more than 130 wind farmsMost of these are smaller installations connected to the distribution systemSEMO also provide 1
2 -hourly MG data for wind farms but there are gaps in thisdataset Some kind of statistical modelling is required to recover total windgeneration To do this generation data for 36 of the largest wind farms whichwere fully operational during 2011 (20 transmission and 16 distribution systemconnected) were compiled The sum of the capacities of this sample amountedto asymp 2
3 of the total installed wind capacity during 2011 The time-series of totaloutput from the sample was normalised upwards to reflect the correct totalinstalled monthly wind capacity (this allows for asymp 200MW increase in windcapacity during 2011) This is expected to be a good approximation becausewind generation is highly correlated in space and in time1 The estimate of windgeneration resulting from the procedure is similar to the real-time estimate ofthe grid operator (correlation amp 099)[13]
In all the generator dataset used in this study contains close to 2 milliondata points A visualisation of the dataset showing 1
2 -hourly generation fraction
1The physical reason for this is that the maximum linear separation of wind farms on theIrish grid is much less that the extent of typical mid-latitude weather systems which bringwindy or calm conditions For example the correlation between wind generation at Meentycatin extreme North-West and Carnsore in the extreme South-East is 047 Autocorrelation isalso very strong eg 12 hour lagged correlation is 065
3
by fuel type ( ldquofuel-mix plotrdquo) is shown in 2 [17] Gas is the dominant powersource (53) and it is displaced when wind generation is present
To model CO2 emissions detailed physical characteristics of individual ther-mal generators are required Parameters listed in Tables 34 are used by electric-ity market participants to determine fuel use and support despatch decisions[16]Table 4 gives Incremental Heat Rate Slopes (GJMWh) which are defined be-tween a set of capacity points (MW) specific to each generator Together withzero-load energy use (GJh) these can be inverted to find the rate of energyuse by the generator at each capacity point Full input-output curves were thenconstructed by cubic spline interpolation These input-output curves give theemissions rate when a generator is operated in steady state at any point between0MW and MaxCap (making use of fuel CO2 emission factors[14]) In practicegenerators can only operate in steady state only between MinCap and MaxCapor as spinning reserve (at 0MW)
Once input-output curves have been constructed they can be combined withgeneration data to create emissions time-series for each unit2 Total emissionscalculated in this way include the effects of generation mix and part-load effi-ciency Emissions from this model were 1164Mt in 2011 compared to 1167Mtusing the grid operator data[13] The two emissions time-series are similar butnot identical with a correlation of asymp 097 Further tests on the validity of thismodel are described below
Additional emissions arising from cycling (start-ups) can be calculated usingparameters in Table 3 Fuel costs (in GJ) depend on thermal state of thegenerator at start-up (Hot Warm or Cold) With appropriate initial conditionsa thermal state time-series is constructed for each generator using transitiontimes between the states (HotToWarm and WarmToCold) provided in Table 3Startup fuel which may be different from the primary fuel type in some cases(eg for coal generators startup fuel is a 68-32 oilcoal mixture) Figure3 shows an example of the emissions associated with a coal generator Startupemissions in 2011 were 014MtCO2 bringing total emissions to 1178MtCO2This compares to verified emissions of 1184MtCO2
2One peat generator (ldquoED1rdquo) was 15 co-fired with biomass material in 2011 This meansthat under emissions rules itrsquos net emissions are reduced by the same factor
4
Figure
1ndash
Upp
er
Dem
and
(MG
LF
bla
ck)
and
esti
mate
dw
ind
pow
ergen
erati
on
(gre
en)
Mea
ndem
and
is2813M
W
Mea
nw
ind
was
467M
Ww
ith
capaci
tyfa
ctor
was
30
T
he
corr
elati
on
bet
wee
nw
ind
gen
erati
on
and
dem
and
iscl
ose
toze
ro(asymp
00
5)
Low
er
Eff
ecti
ve
dem
and
(=dem
and
-w
ind)
as
seen
by
conven
tional
pla
nt
Eff
ecti
ve
dem
and
isasymp
38
more
vola
tile
than
syst
emdem
and
5
Figure 2 ndash Left Half-hourly fuel mix time-series (generation fraction) for 2011derived from SEMO data Right corresponding CO2-mix time series The verti-cal scale is day of year Mean generation fractions were (1) gas (+chp) 58 (2)wind 17 (3) coal 15 (4) peat 8 Mean emissions fractions on the other handwere (1) gas (+chp) 49 (2) coal 31 (3) peat 19
6
Figure 3 ndash Top Metered generation(MW) from coal generator MP2 (Money-point power station) during 2011 The red lines correspond to maximum andminimum stable operating capacities Thermal state (Cold Warm Hot) are in-dicated by colours blue brown black Bottom corresponding CO2 emissionsrate (tCO2h) The spikes in emissions correspond to cycling (start up) eventsFor visualisation and modelling convenience all cycling emissions are assumed tooccur within a half hour interval
As a consistency test of the emissions model comparison can be made withannual power plant emissions reported under to the European Emissions TradingScheme (EU-ETS) for 2011[12] These data provide an independent test of theemissions model because they are based on actual fuel consumption informationcollected using stock accounting principles To convert to CO2 standard emis-sions factors are associated with each fuel (although in the case of coal emissionsfactors can vary significantly from year to year) To make contact with thesedata the emissions time-series of the 35 thermal generators are aggregated into11 power plant and annual emissions calculated These data provide both aconsistency check and model constraint as illustrated in 4 In all agreementis satisfactory and is particularly good for gas base-load (Combined Cycle Gas
7
Turbine or CCGT) plant It is not surprising that errors are somewhat larger forintermittently used ldquopeakingrdquo plant but these form only a very small fractionof total emissions
Figure 4 ndash Comparison of model and reported power station emissions in 2011Carbon intensities (tCO2MWh) based on emissions reported under EU-ETS areshown in light colours while modeled values are shown in heavy colors Baseloadgas (CCGT) plant have lowest emissions intensities Emissions factors used toconvert from energy units to emissions (TWhtCO2) were coal = 899 peat= 1167 oil = 714 gas= 569 Verified EU-ETS emissions at Aughinish includeemissions unrelated to electric power generation for the grid so these have beenset to the model value
In fact the above emissions model is incomplete Ramping a thermal gen-erator burns additional fuel even when no start-ups occur This arises when agenerator is ramped between MinCap and MaxCap as in Figure 3 for exam-ple Simply summing emissions based on the generatorrsquos input-output curve asdone above does not capture this effect This additional source of emissions hasbeen emphasised particularly by le Pair Udo and de Groot[6] and is likely tobe especially significant in the case of less flexible base-load plant[18] Ramp-ing emissions were not included in the calculation described above primarilybecause no model parameterisations of this effect are available However inview of the good agreement between reported values and model there is no ev-idence of a large missing source of emissions from ramping (order of magnitudesim 01MtCO2) Emissions from CCGT gas plant in particular seem to be ac-curately described Nevertheless on physical grounds we know such emissionsdo exist and are likely to increase as wind penetration increases
3 Results and Discussion
Fuel-mix plots[13] (Figure 2) show that wind displaces gas generation and toa lesser extent coal Peat and gas CHP plant are operated on a ldquomust runrdquobasis These plant respond to system demand but they are not displaced bywind The CO2-mix plot in Figure 2 is calculated using the emissions modeldescribed above Coal and peat play a far larger role in the CO2 mix For
8
example peat provided only 8 of generation but produced 19 of emissionsWind power displaces gas generation and therefore it is not surprising thatperiods of high wind generation are associated with lower emissions from gasplant This can be seen clearly from Figure 5
Figure 5 ndash Left CO2 emission rates for gas coal and peat fuel generators as afunction of total system demand High wind generation is indicated in light blueand low wind generation is shown in dark blue Right Empirical probabilitydistribution for CO2 emission rates for ldquohighrdquo (green) and ldquolowrdquo (pink windgeneration ie lower or higher than the median wind generation The coal andgas plant portfolio is more likely to be found in a low emission state at high windgeneration This effect is far stronger for gas than for coal
Emissions intensity fall linearly with wind penetration A summary of thelinear regression fit is shown in Table 1 The intercept 053tCO2MWh corre-sponds to grid average emissions intensity in the absence of wind The fittedslope -028tCO2MWh corresponds to emissions savings due to wind genera-tion The displacement effectiveness of wind power is therefore just 53 (Ifstart-up emissions are omitted the fit parameters become 052tCO2MWh and03tCO2MWh respectively) If there was no wind in 2011 emissions wouldhave been 129MtCO2 versus 118MtCO2 observed ie a savings of asymp 9
It seems surprising at first sight that emissions savings of 028tCO2MWhis less than the emissions intensity of the cleanest thermal generators on thegrid Figure 4 To understand how this arises it is necessary to drill downand see how individual generators respond to wind generation In general therelationship between an individual generator and total system demand (or total
9
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
2 Data and model
Data on the Irish electricity grid is available from a number of sources[13][14][15]The Single Electricity Market Operator (SEMO) provide 1
2 -hourly generationdata ldquoEx Post Initialrdquo metered generation data is compiled four days after gen-eration date for invoicing purposes This accurate dataset is used here SEMOprovide a loss factor adjusted total metered generation (ldquoMGLFrdquo) time-serieswhich includes all domestic generation as well as power traded via intercon-nectors to Northern Ireland Each power source is weighted by a unit specifictransmission system loss factor which also depends on time of day and seasonMGLF is a proxy for total end-user demand because accurate balance betweengeneration and demand is required at all times in order to maintain grid fre-quency stability MGLF is very similar but not identical to the real-time systemdemand recorded by the grid operator (correlation 099)[13] A time-series ofnet intra-jurisdiction importsexports is also available (ldquoNIJIrdquo)
Under the priority despatch rule for wind conventional generation mustadjust continuously to match system demand minus wind generation Fromthe point of view of the conventional generation system wind generation is anexogenous random variable which reduces effective demand but also makes itmore volatile Figure 1 The aim is to find out what impact this has on individualthermal generators SEMO provides 1
2 -hourly metered generation data (ldquoMGrdquo)data on all grid-connected generators[15] Excluding wind power 54 generatorssupply the Irish grid 35 of these are thermal the rest are small hydropumpedstorage units Descriptions of thermal generators such as fuel type maximumcapacity etc are given in Table 3[15]
Wind generation is the sum of the outputs of more than 130 wind farmsMost of these are smaller installations connected to the distribution systemSEMO also provide 1
2 -hourly MG data for wind farms but there are gaps in thisdataset Some kind of statistical modelling is required to recover total windgeneration To do this generation data for 36 of the largest wind farms whichwere fully operational during 2011 (20 transmission and 16 distribution systemconnected) were compiled The sum of the capacities of this sample amountedto asymp 2
3 of the total installed wind capacity during 2011 The time-series of totaloutput from the sample was normalised upwards to reflect the correct totalinstalled monthly wind capacity (this allows for asymp 200MW increase in windcapacity during 2011) This is expected to be a good approximation becausewind generation is highly correlated in space and in time1 The estimate of windgeneration resulting from the procedure is similar to the real-time estimate ofthe grid operator (correlation amp 099)[13]
In all the generator dataset used in this study contains close to 2 milliondata points A visualisation of the dataset showing 1
2 -hourly generation fraction
1The physical reason for this is that the maximum linear separation of wind farms on theIrish grid is much less that the extent of typical mid-latitude weather systems which bringwindy or calm conditions For example the correlation between wind generation at Meentycatin extreme North-West and Carnsore in the extreme South-East is 047 Autocorrelation isalso very strong eg 12 hour lagged correlation is 065
3
by fuel type ( ldquofuel-mix plotrdquo) is shown in 2 [17] Gas is the dominant powersource (53) and it is displaced when wind generation is present
To model CO2 emissions detailed physical characteristics of individual ther-mal generators are required Parameters listed in Tables 34 are used by electric-ity market participants to determine fuel use and support despatch decisions[16]Table 4 gives Incremental Heat Rate Slopes (GJMWh) which are defined be-tween a set of capacity points (MW) specific to each generator Together withzero-load energy use (GJh) these can be inverted to find the rate of energyuse by the generator at each capacity point Full input-output curves were thenconstructed by cubic spline interpolation These input-output curves give theemissions rate when a generator is operated in steady state at any point between0MW and MaxCap (making use of fuel CO2 emission factors[14]) In practicegenerators can only operate in steady state only between MinCap and MaxCapor as spinning reserve (at 0MW)
Once input-output curves have been constructed they can be combined withgeneration data to create emissions time-series for each unit2 Total emissionscalculated in this way include the effects of generation mix and part-load effi-ciency Emissions from this model were 1164Mt in 2011 compared to 1167Mtusing the grid operator data[13] The two emissions time-series are similar butnot identical with a correlation of asymp 097 Further tests on the validity of thismodel are described below
Additional emissions arising from cycling (start-ups) can be calculated usingparameters in Table 3 Fuel costs (in GJ) depend on thermal state of thegenerator at start-up (Hot Warm or Cold) With appropriate initial conditionsa thermal state time-series is constructed for each generator using transitiontimes between the states (HotToWarm and WarmToCold) provided in Table 3Startup fuel which may be different from the primary fuel type in some cases(eg for coal generators startup fuel is a 68-32 oilcoal mixture) Figure3 shows an example of the emissions associated with a coal generator Startupemissions in 2011 were 014MtCO2 bringing total emissions to 1178MtCO2This compares to verified emissions of 1184MtCO2
2One peat generator (ldquoED1rdquo) was 15 co-fired with biomass material in 2011 This meansthat under emissions rules itrsquos net emissions are reduced by the same factor
4
Figure
1ndash
Upp
er
Dem
and
(MG
LF
bla
ck)
and
esti
mate
dw
ind
pow
ergen
erati
on
(gre
en)
Mea
ndem
and
is2813M
W
Mea
nw
ind
was
467M
Ww
ith
capaci
tyfa
ctor
was
30
T
he
corr
elati
on
bet
wee
nw
ind
gen
erati
on
and
dem
and
iscl
ose
toze
ro(asymp
00
5)
Low
er
Eff
ecti
ve
dem
and
(=dem
and
-w
ind)
as
seen
by
conven
tional
pla
nt
Eff
ecti
ve
dem
and
isasymp
38
more
vola
tile
than
syst
emdem
and
5
Figure 2 ndash Left Half-hourly fuel mix time-series (generation fraction) for 2011derived from SEMO data Right corresponding CO2-mix time series The verti-cal scale is day of year Mean generation fractions were (1) gas (+chp) 58 (2)wind 17 (3) coal 15 (4) peat 8 Mean emissions fractions on the other handwere (1) gas (+chp) 49 (2) coal 31 (3) peat 19
6
Figure 3 ndash Top Metered generation(MW) from coal generator MP2 (Money-point power station) during 2011 The red lines correspond to maximum andminimum stable operating capacities Thermal state (Cold Warm Hot) are in-dicated by colours blue brown black Bottom corresponding CO2 emissionsrate (tCO2h) The spikes in emissions correspond to cycling (start up) eventsFor visualisation and modelling convenience all cycling emissions are assumed tooccur within a half hour interval
As a consistency test of the emissions model comparison can be made withannual power plant emissions reported under to the European Emissions TradingScheme (EU-ETS) for 2011[12] These data provide an independent test of theemissions model because they are based on actual fuel consumption informationcollected using stock accounting principles To convert to CO2 standard emis-sions factors are associated with each fuel (although in the case of coal emissionsfactors can vary significantly from year to year) To make contact with thesedata the emissions time-series of the 35 thermal generators are aggregated into11 power plant and annual emissions calculated These data provide both aconsistency check and model constraint as illustrated in 4 In all agreementis satisfactory and is particularly good for gas base-load (Combined Cycle Gas
7
Turbine or CCGT) plant It is not surprising that errors are somewhat larger forintermittently used ldquopeakingrdquo plant but these form only a very small fractionof total emissions
Figure 4 ndash Comparison of model and reported power station emissions in 2011Carbon intensities (tCO2MWh) based on emissions reported under EU-ETS areshown in light colours while modeled values are shown in heavy colors Baseloadgas (CCGT) plant have lowest emissions intensities Emissions factors used toconvert from energy units to emissions (TWhtCO2) were coal = 899 peat= 1167 oil = 714 gas= 569 Verified EU-ETS emissions at Aughinish includeemissions unrelated to electric power generation for the grid so these have beenset to the model value
In fact the above emissions model is incomplete Ramping a thermal gen-erator burns additional fuel even when no start-ups occur This arises when agenerator is ramped between MinCap and MaxCap as in Figure 3 for exam-ple Simply summing emissions based on the generatorrsquos input-output curve asdone above does not capture this effect This additional source of emissions hasbeen emphasised particularly by le Pair Udo and de Groot[6] and is likely tobe especially significant in the case of less flexible base-load plant[18] Ramp-ing emissions were not included in the calculation described above primarilybecause no model parameterisations of this effect are available However inview of the good agreement between reported values and model there is no ev-idence of a large missing source of emissions from ramping (order of magnitudesim 01MtCO2) Emissions from CCGT gas plant in particular seem to be ac-curately described Nevertheless on physical grounds we know such emissionsdo exist and are likely to increase as wind penetration increases
3 Results and Discussion
Fuel-mix plots[13] (Figure 2) show that wind displaces gas generation and toa lesser extent coal Peat and gas CHP plant are operated on a ldquomust runrdquobasis These plant respond to system demand but they are not displaced bywind The CO2-mix plot in Figure 2 is calculated using the emissions modeldescribed above Coal and peat play a far larger role in the CO2 mix For
8
example peat provided only 8 of generation but produced 19 of emissionsWind power displaces gas generation and therefore it is not surprising thatperiods of high wind generation are associated with lower emissions from gasplant This can be seen clearly from Figure 5
Figure 5 ndash Left CO2 emission rates for gas coal and peat fuel generators as afunction of total system demand High wind generation is indicated in light blueand low wind generation is shown in dark blue Right Empirical probabilitydistribution for CO2 emission rates for ldquohighrdquo (green) and ldquolowrdquo (pink windgeneration ie lower or higher than the median wind generation The coal andgas plant portfolio is more likely to be found in a low emission state at high windgeneration This effect is far stronger for gas than for coal
Emissions intensity fall linearly with wind penetration A summary of thelinear regression fit is shown in Table 1 The intercept 053tCO2MWh corre-sponds to grid average emissions intensity in the absence of wind The fittedslope -028tCO2MWh corresponds to emissions savings due to wind genera-tion The displacement effectiveness of wind power is therefore just 53 (Ifstart-up emissions are omitted the fit parameters become 052tCO2MWh and03tCO2MWh respectively) If there was no wind in 2011 emissions wouldhave been 129MtCO2 versus 118MtCO2 observed ie a savings of asymp 9
It seems surprising at first sight that emissions savings of 028tCO2MWhis less than the emissions intensity of the cleanest thermal generators on thegrid Figure 4 To understand how this arises it is necessary to drill downand see how individual generators respond to wind generation In general therelationship between an individual generator and total system demand (or total
9
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
by fuel type ( ldquofuel-mix plotrdquo) is shown in 2 [17] Gas is the dominant powersource (53) and it is displaced when wind generation is present
To model CO2 emissions detailed physical characteristics of individual ther-mal generators are required Parameters listed in Tables 34 are used by electric-ity market participants to determine fuel use and support despatch decisions[16]Table 4 gives Incremental Heat Rate Slopes (GJMWh) which are defined be-tween a set of capacity points (MW) specific to each generator Together withzero-load energy use (GJh) these can be inverted to find the rate of energyuse by the generator at each capacity point Full input-output curves were thenconstructed by cubic spline interpolation These input-output curves give theemissions rate when a generator is operated in steady state at any point between0MW and MaxCap (making use of fuel CO2 emission factors[14]) In practicegenerators can only operate in steady state only between MinCap and MaxCapor as spinning reserve (at 0MW)
Once input-output curves have been constructed they can be combined withgeneration data to create emissions time-series for each unit2 Total emissionscalculated in this way include the effects of generation mix and part-load effi-ciency Emissions from this model were 1164Mt in 2011 compared to 1167Mtusing the grid operator data[13] The two emissions time-series are similar butnot identical with a correlation of asymp 097 Further tests on the validity of thismodel are described below
Additional emissions arising from cycling (start-ups) can be calculated usingparameters in Table 3 Fuel costs (in GJ) depend on thermal state of thegenerator at start-up (Hot Warm or Cold) With appropriate initial conditionsa thermal state time-series is constructed for each generator using transitiontimes between the states (HotToWarm and WarmToCold) provided in Table 3Startup fuel which may be different from the primary fuel type in some cases(eg for coal generators startup fuel is a 68-32 oilcoal mixture) Figure3 shows an example of the emissions associated with a coal generator Startupemissions in 2011 were 014MtCO2 bringing total emissions to 1178MtCO2This compares to verified emissions of 1184MtCO2
2One peat generator (ldquoED1rdquo) was 15 co-fired with biomass material in 2011 This meansthat under emissions rules itrsquos net emissions are reduced by the same factor
4
Figure
1ndash
Upp
er
Dem
and
(MG
LF
bla
ck)
and
esti
mate
dw
ind
pow
ergen
erati
on
(gre
en)
Mea
ndem
and
is2813M
W
Mea
nw
ind
was
467M
Ww
ith
capaci
tyfa
ctor
was
30
T
he
corr
elati
on
bet
wee
nw
ind
gen
erati
on
and
dem
and
iscl
ose
toze
ro(asymp
00
5)
Low
er
Eff
ecti
ve
dem
and
(=dem
and
-w
ind)
as
seen
by
conven
tional
pla
nt
Eff
ecti
ve
dem
and
isasymp
38
more
vola
tile
than
syst
emdem
and
5
Figure 2 ndash Left Half-hourly fuel mix time-series (generation fraction) for 2011derived from SEMO data Right corresponding CO2-mix time series The verti-cal scale is day of year Mean generation fractions were (1) gas (+chp) 58 (2)wind 17 (3) coal 15 (4) peat 8 Mean emissions fractions on the other handwere (1) gas (+chp) 49 (2) coal 31 (3) peat 19
6
Figure 3 ndash Top Metered generation(MW) from coal generator MP2 (Money-point power station) during 2011 The red lines correspond to maximum andminimum stable operating capacities Thermal state (Cold Warm Hot) are in-dicated by colours blue brown black Bottom corresponding CO2 emissionsrate (tCO2h) The spikes in emissions correspond to cycling (start up) eventsFor visualisation and modelling convenience all cycling emissions are assumed tooccur within a half hour interval
As a consistency test of the emissions model comparison can be made withannual power plant emissions reported under to the European Emissions TradingScheme (EU-ETS) for 2011[12] These data provide an independent test of theemissions model because they are based on actual fuel consumption informationcollected using stock accounting principles To convert to CO2 standard emis-sions factors are associated with each fuel (although in the case of coal emissionsfactors can vary significantly from year to year) To make contact with thesedata the emissions time-series of the 35 thermal generators are aggregated into11 power plant and annual emissions calculated These data provide both aconsistency check and model constraint as illustrated in 4 In all agreementis satisfactory and is particularly good for gas base-load (Combined Cycle Gas
7
Turbine or CCGT) plant It is not surprising that errors are somewhat larger forintermittently used ldquopeakingrdquo plant but these form only a very small fractionof total emissions
Figure 4 ndash Comparison of model and reported power station emissions in 2011Carbon intensities (tCO2MWh) based on emissions reported under EU-ETS areshown in light colours while modeled values are shown in heavy colors Baseloadgas (CCGT) plant have lowest emissions intensities Emissions factors used toconvert from energy units to emissions (TWhtCO2) were coal = 899 peat= 1167 oil = 714 gas= 569 Verified EU-ETS emissions at Aughinish includeemissions unrelated to electric power generation for the grid so these have beenset to the model value
In fact the above emissions model is incomplete Ramping a thermal gen-erator burns additional fuel even when no start-ups occur This arises when agenerator is ramped between MinCap and MaxCap as in Figure 3 for exam-ple Simply summing emissions based on the generatorrsquos input-output curve asdone above does not capture this effect This additional source of emissions hasbeen emphasised particularly by le Pair Udo and de Groot[6] and is likely tobe especially significant in the case of less flexible base-load plant[18] Ramp-ing emissions were not included in the calculation described above primarilybecause no model parameterisations of this effect are available However inview of the good agreement between reported values and model there is no ev-idence of a large missing source of emissions from ramping (order of magnitudesim 01MtCO2) Emissions from CCGT gas plant in particular seem to be ac-curately described Nevertheless on physical grounds we know such emissionsdo exist and are likely to increase as wind penetration increases
3 Results and Discussion
Fuel-mix plots[13] (Figure 2) show that wind displaces gas generation and toa lesser extent coal Peat and gas CHP plant are operated on a ldquomust runrdquobasis These plant respond to system demand but they are not displaced bywind The CO2-mix plot in Figure 2 is calculated using the emissions modeldescribed above Coal and peat play a far larger role in the CO2 mix For
8
example peat provided only 8 of generation but produced 19 of emissionsWind power displaces gas generation and therefore it is not surprising thatperiods of high wind generation are associated with lower emissions from gasplant This can be seen clearly from Figure 5
Figure 5 ndash Left CO2 emission rates for gas coal and peat fuel generators as afunction of total system demand High wind generation is indicated in light blueand low wind generation is shown in dark blue Right Empirical probabilitydistribution for CO2 emission rates for ldquohighrdquo (green) and ldquolowrdquo (pink windgeneration ie lower or higher than the median wind generation The coal andgas plant portfolio is more likely to be found in a low emission state at high windgeneration This effect is far stronger for gas than for coal
Emissions intensity fall linearly with wind penetration A summary of thelinear regression fit is shown in Table 1 The intercept 053tCO2MWh corre-sponds to grid average emissions intensity in the absence of wind The fittedslope -028tCO2MWh corresponds to emissions savings due to wind genera-tion The displacement effectiveness of wind power is therefore just 53 (Ifstart-up emissions are omitted the fit parameters become 052tCO2MWh and03tCO2MWh respectively) If there was no wind in 2011 emissions wouldhave been 129MtCO2 versus 118MtCO2 observed ie a savings of asymp 9
It seems surprising at first sight that emissions savings of 028tCO2MWhis less than the emissions intensity of the cleanest thermal generators on thegrid Figure 4 To understand how this arises it is necessary to drill downand see how individual generators respond to wind generation In general therelationship between an individual generator and total system demand (or total
9
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
Figure
1ndash
Upp
er
Dem
and
(MG
LF
bla
ck)
and
esti
mate
dw
ind
pow
ergen
erati
on
(gre
en)
Mea
ndem
and
is2813M
W
Mea
nw
ind
was
467M
Ww
ith
capaci
tyfa
ctor
was
30
T
he
corr
elati
on
bet
wee
nw
ind
gen
erati
on
and
dem
and
iscl
ose
toze
ro(asymp
00
5)
Low
er
Eff
ecti
ve
dem
and
(=dem
and
-w
ind)
as
seen
by
conven
tional
pla
nt
Eff
ecti
ve
dem
and
isasymp
38
more
vola
tile
than
syst
emdem
and
5
Figure 2 ndash Left Half-hourly fuel mix time-series (generation fraction) for 2011derived from SEMO data Right corresponding CO2-mix time series The verti-cal scale is day of year Mean generation fractions were (1) gas (+chp) 58 (2)wind 17 (3) coal 15 (4) peat 8 Mean emissions fractions on the other handwere (1) gas (+chp) 49 (2) coal 31 (3) peat 19
6
Figure 3 ndash Top Metered generation(MW) from coal generator MP2 (Money-point power station) during 2011 The red lines correspond to maximum andminimum stable operating capacities Thermal state (Cold Warm Hot) are in-dicated by colours blue brown black Bottom corresponding CO2 emissionsrate (tCO2h) The spikes in emissions correspond to cycling (start up) eventsFor visualisation and modelling convenience all cycling emissions are assumed tooccur within a half hour interval
As a consistency test of the emissions model comparison can be made withannual power plant emissions reported under to the European Emissions TradingScheme (EU-ETS) for 2011[12] These data provide an independent test of theemissions model because they are based on actual fuel consumption informationcollected using stock accounting principles To convert to CO2 standard emis-sions factors are associated with each fuel (although in the case of coal emissionsfactors can vary significantly from year to year) To make contact with thesedata the emissions time-series of the 35 thermal generators are aggregated into11 power plant and annual emissions calculated These data provide both aconsistency check and model constraint as illustrated in 4 In all agreementis satisfactory and is particularly good for gas base-load (Combined Cycle Gas
7
Turbine or CCGT) plant It is not surprising that errors are somewhat larger forintermittently used ldquopeakingrdquo plant but these form only a very small fractionof total emissions
Figure 4 ndash Comparison of model and reported power station emissions in 2011Carbon intensities (tCO2MWh) based on emissions reported under EU-ETS areshown in light colours while modeled values are shown in heavy colors Baseloadgas (CCGT) plant have lowest emissions intensities Emissions factors used toconvert from energy units to emissions (TWhtCO2) were coal = 899 peat= 1167 oil = 714 gas= 569 Verified EU-ETS emissions at Aughinish includeemissions unrelated to electric power generation for the grid so these have beenset to the model value
In fact the above emissions model is incomplete Ramping a thermal gen-erator burns additional fuel even when no start-ups occur This arises when agenerator is ramped between MinCap and MaxCap as in Figure 3 for exam-ple Simply summing emissions based on the generatorrsquos input-output curve asdone above does not capture this effect This additional source of emissions hasbeen emphasised particularly by le Pair Udo and de Groot[6] and is likely tobe especially significant in the case of less flexible base-load plant[18] Ramp-ing emissions were not included in the calculation described above primarilybecause no model parameterisations of this effect are available However inview of the good agreement between reported values and model there is no ev-idence of a large missing source of emissions from ramping (order of magnitudesim 01MtCO2) Emissions from CCGT gas plant in particular seem to be ac-curately described Nevertheless on physical grounds we know such emissionsdo exist and are likely to increase as wind penetration increases
3 Results and Discussion
Fuel-mix plots[13] (Figure 2) show that wind displaces gas generation and toa lesser extent coal Peat and gas CHP plant are operated on a ldquomust runrdquobasis These plant respond to system demand but they are not displaced bywind The CO2-mix plot in Figure 2 is calculated using the emissions modeldescribed above Coal and peat play a far larger role in the CO2 mix For
8
example peat provided only 8 of generation but produced 19 of emissionsWind power displaces gas generation and therefore it is not surprising thatperiods of high wind generation are associated with lower emissions from gasplant This can be seen clearly from Figure 5
Figure 5 ndash Left CO2 emission rates for gas coal and peat fuel generators as afunction of total system demand High wind generation is indicated in light blueand low wind generation is shown in dark blue Right Empirical probabilitydistribution for CO2 emission rates for ldquohighrdquo (green) and ldquolowrdquo (pink windgeneration ie lower or higher than the median wind generation The coal andgas plant portfolio is more likely to be found in a low emission state at high windgeneration This effect is far stronger for gas than for coal
Emissions intensity fall linearly with wind penetration A summary of thelinear regression fit is shown in Table 1 The intercept 053tCO2MWh corre-sponds to grid average emissions intensity in the absence of wind The fittedslope -028tCO2MWh corresponds to emissions savings due to wind genera-tion The displacement effectiveness of wind power is therefore just 53 (Ifstart-up emissions are omitted the fit parameters become 052tCO2MWh and03tCO2MWh respectively) If there was no wind in 2011 emissions wouldhave been 129MtCO2 versus 118MtCO2 observed ie a savings of asymp 9
It seems surprising at first sight that emissions savings of 028tCO2MWhis less than the emissions intensity of the cleanest thermal generators on thegrid Figure 4 To understand how this arises it is necessary to drill downand see how individual generators respond to wind generation In general therelationship between an individual generator and total system demand (or total
9
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
Figure 2 ndash Left Half-hourly fuel mix time-series (generation fraction) for 2011derived from SEMO data Right corresponding CO2-mix time series The verti-cal scale is day of year Mean generation fractions were (1) gas (+chp) 58 (2)wind 17 (3) coal 15 (4) peat 8 Mean emissions fractions on the other handwere (1) gas (+chp) 49 (2) coal 31 (3) peat 19
6
Figure 3 ndash Top Metered generation(MW) from coal generator MP2 (Money-point power station) during 2011 The red lines correspond to maximum andminimum stable operating capacities Thermal state (Cold Warm Hot) are in-dicated by colours blue brown black Bottom corresponding CO2 emissionsrate (tCO2h) The spikes in emissions correspond to cycling (start up) eventsFor visualisation and modelling convenience all cycling emissions are assumed tooccur within a half hour interval
As a consistency test of the emissions model comparison can be made withannual power plant emissions reported under to the European Emissions TradingScheme (EU-ETS) for 2011[12] These data provide an independent test of theemissions model because they are based on actual fuel consumption informationcollected using stock accounting principles To convert to CO2 standard emis-sions factors are associated with each fuel (although in the case of coal emissionsfactors can vary significantly from year to year) To make contact with thesedata the emissions time-series of the 35 thermal generators are aggregated into11 power plant and annual emissions calculated These data provide both aconsistency check and model constraint as illustrated in 4 In all agreementis satisfactory and is particularly good for gas base-load (Combined Cycle Gas
7
Turbine or CCGT) plant It is not surprising that errors are somewhat larger forintermittently used ldquopeakingrdquo plant but these form only a very small fractionof total emissions
Figure 4 ndash Comparison of model and reported power station emissions in 2011Carbon intensities (tCO2MWh) based on emissions reported under EU-ETS areshown in light colours while modeled values are shown in heavy colors Baseloadgas (CCGT) plant have lowest emissions intensities Emissions factors used toconvert from energy units to emissions (TWhtCO2) were coal = 899 peat= 1167 oil = 714 gas= 569 Verified EU-ETS emissions at Aughinish includeemissions unrelated to electric power generation for the grid so these have beenset to the model value
In fact the above emissions model is incomplete Ramping a thermal gen-erator burns additional fuel even when no start-ups occur This arises when agenerator is ramped between MinCap and MaxCap as in Figure 3 for exam-ple Simply summing emissions based on the generatorrsquos input-output curve asdone above does not capture this effect This additional source of emissions hasbeen emphasised particularly by le Pair Udo and de Groot[6] and is likely tobe especially significant in the case of less flexible base-load plant[18] Ramp-ing emissions were not included in the calculation described above primarilybecause no model parameterisations of this effect are available However inview of the good agreement between reported values and model there is no ev-idence of a large missing source of emissions from ramping (order of magnitudesim 01MtCO2) Emissions from CCGT gas plant in particular seem to be ac-curately described Nevertheless on physical grounds we know such emissionsdo exist and are likely to increase as wind penetration increases
3 Results and Discussion
Fuel-mix plots[13] (Figure 2) show that wind displaces gas generation and toa lesser extent coal Peat and gas CHP plant are operated on a ldquomust runrdquobasis These plant respond to system demand but they are not displaced bywind The CO2-mix plot in Figure 2 is calculated using the emissions modeldescribed above Coal and peat play a far larger role in the CO2 mix For
8
example peat provided only 8 of generation but produced 19 of emissionsWind power displaces gas generation and therefore it is not surprising thatperiods of high wind generation are associated with lower emissions from gasplant This can be seen clearly from Figure 5
Figure 5 ndash Left CO2 emission rates for gas coal and peat fuel generators as afunction of total system demand High wind generation is indicated in light blueand low wind generation is shown in dark blue Right Empirical probabilitydistribution for CO2 emission rates for ldquohighrdquo (green) and ldquolowrdquo (pink windgeneration ie lower or higher than the median wind generation The coal andgas plant portfolio is more likely to be found in a low emission state at high windgeneration This effect is far stronger for gas than for coal
Emissions intensity fall linearly with wind penetration A summary of thelinear regression fit is shown in Table 1 The intercept 053tCO2MWh corre-sponds to grid average emissions intensity in the absence of wind The fittedslope -028tCO2MWh corresponds to emissions savings due to wind genera-tion The displacement effectiveness of wind power is therefore just 53 (Ifstart-up emissions are omitted the fit parameters become 052tCO2MWh and03tCO2MWh respectively) If there was no wind in 2011 emissions wouldhave been 129MtCO2 versus 118MtCO2 observed ie a savings of asymp 9
It seems surprising at first sight that emissions savings of 028tCO2MWhis less than the emissions intensity of the cleanest thermal generators on thegrid Figure 4 To understand how this arises it is necessary to drill downand see how individual generators respond to wind generation In general therelationship between an individual generator and total system demand (or total
9
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
Figure 3 ndash Top Metered generation(MW) from coal generator MP2 (Money-point power station) during 2011 The red lines correspond to maximum andminimum stable operating capacities Thermal state (Cold Warm Hot) are in-dicated by colours blue brown black Bottom corresponding CO2 emissionsrate (tCO2h) The spikes in emissions correspond to cycling (start up) eventsFor visualisation and modelling convenience all cycling emissions are assumed tooccur within a half hour interval
As a consistency test of the emissions model comparison can be made withannual power plant emissions reported under to the European Emissions TradingScheme (EU-ETS) for 2011[12] These data provide an independent test of theemissions model because they are based on actual fuel consumption informationcollected using stock accounting principles To convert to CO2 standard emis-sions factors are associated with each fuel (although in the case of coal emissionsfactors can vary significantly from year to year) To make contact with thesedata the emissions time-series of the 35 thermal generators are aggregated into11 power plant and annual emissions calculated These data provide both aconsistency check and model constraint as illustrated in 4 In all agreementis satisfactory and is particularly good for gas base-load (Combined Cycle Gas
7
Turbine or CCGT) plant It is not surprising that errors are somewhat larger forintermittently used ldquopeakingrdquo plant but these form only a very small fractionof total emissions
Figure 4 ndash Comparison of model and reported power station emissions in 2011Carbon intensities (tCO2MWh) based on emissions reported under EU-ETS areshown in light colours while modeled values are shown in heavy colors Baseloadgas (CCGT) plant have lowest emissions intensities Emissions factors used toconvert from energy units to emissions (TWhtCO2) were coal = 899 peat= 1167 oil = 714 gas= 569 Verified EU-ETS emissions at Aughinish includeemissions unrelated to electric power generation for the grid so these have beenset to the model value
In fact the above emissions model is incomplete Ramping a thermal gen-erator burns additional fuel even when no start-ups occur This arises when agenerator is ramped between MinCap and MaxCap as in Figure 3 for exam-ple Simply summing emissions based on the generatorrsquos input-output curve asdone above does not capture this effect This additional source of emissions hasbeen emphasised particularly by le Pair Udo and de Groot[6] and is likely tobe especially significant in the case of less flexible base-load plant[18] Ramp-ing emissions were not included in the calculation described above primarilybecause no model parameterisations of this effect are available However inview of the good agreement between reported values and model there is no ev-idence of a large missing source of emissions from ramping (order of magnitudesim 01MtCO2) Emissions from CCGT gas plant in particular seem to be ac-curately described Nevertheless on physical grounds we know such emissionsdo exist and are likely to increase as wind penetration increases
3 Results and Discussion
Fuel-mix plots[13] (Figure 2) show that wind displaces gas generation and toa lesser extent coal Peat and gas CHP plant are operated on a ldquomust runrdquobasis These plant respond to system demand but they are not displaced bywind The CO2-mix plot in Figure 2 is calculated using the emissions modeldescribed above Coal and peat play a far larger role in the CO2 mix For
8
example peat provided only 8 of generation but produced 19 of emissionsWind power displaces gas generation and therefore it is not surprising thatperiods of high wind generation are associated with lower emissions from gasplant This can be seen clearly from Figure 5
Figure 5 ndash Left CO2 emission rates for gas coal and peat fuel generators as afunction of total system demand High wind generation is indicated in light blueand low wind generation is shown in dark blue Right Empirical probabilitydistribution for CO2 emission rates for ldquohighrdquo (green) and ldquolowrdquo (pink windgeneration ie lower or higher than the median wind generation The coal andgas plant portfolio is more likely to be found in a low emission state at high windgeneration This effect is far stronger for gas than for coal
Emissions intensity fall linearly with wind penetration A summary of thelinear regression fit is shown in Table 1 The intercept 053tCO2MWh corre-sponds to grid average emissions intensity in the absence of wind The fittedslope -028tCO2MWh corresponds to emissions savings due to wind genera-tion The displacement effectiveness of wind power is therefore just 53 (Ifstart-up emissions are omitted the fit parameters become 052tCO2MWh and03tCO2MWh respectively) If there was no wind in 2011 emissions wouldhave been 129MtCO2 versus 118MtCO2 observed ie a savings of asymp 9
It seems surprising at first sight that emissions savings of 028tCO2MWhis less than the emissions intensity of the cleanest thermal generators on thegrid Figure 4 To understand how this arises it is necessary to drill downand see how individual generators respond to wind generation In general therelationship between an individual generator and total system demand (or total
9
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
Turbine or CCGT) plant It is not surprising that errors are somewhat larger forintermittently used ldquopeakingrdquo plant but these form only a very small fractionof total emissions
Figure 4 ndash Comparison of model and reported power station emissions in 2011Carbon intensities (tCO2MWh) based on emissions reported under EU-ETS areshown in light colours while modeled values are shown in heavy colors Baseloadgas (CCGT) plant have lowest emissions intensities Emissions factors used toconvert from energy units to emissions (TWhtCO2) were coal = 899 peat= 1167 oil = 714 gas= 569 Verified EU-ETS emissions at Aughinish includeemissions unrelated to electric power generation for the grid so these have beenset to the model value
In fact the above emissions model is incomplete Ramping a thermal gen-erator burns additional fuel even when no start-ups occur This arises when agenerator is ramped between MinCap and MaxCap as in Figure 3 for exam-ple Simply summing emissions based on the generatorrsquos input-output curve asdone above does not capture this effect This additional source of emissions hasbeen emphasised particularly by le Pair Udo and de Groot[6] and is likely tobe especially significant in the case of less flexible base-load plant[18] Ramp-ing emissions were not included in the calculation described above primarilybecause no model parameterisations of this effect are available However inview of the good agreement between reported values and model there is no ev-idence of a large missing source of emissions from ramping (order of magnitudesim 01MtCO2) Emissions from CCGT gas plant in particular seem to be ac-curately described Nevertheless on physical grounds we know such emissionsdo exist and are likely to increase as wind penetration increases
3 Results and Discussion
Fuel-mix plots[13] (Figure 2) show that wind displaces gas generation and toa lesser extent coal Peat and gas CHP plant are operated on a ldquomust runrdquobasis These plant respond to system demand but they are not displaced bywind The CO2-mix plot in Figure 2 is calculated using the emissions modeldescribed above Coal and peat play a far larger role in the CO2 mix For
8
example peat provided only 8 of generation but produced 19 of emissionsWind power displaces gas generation and therefore it is not surprising thatperiods of high wind generation are associated with lower emissions from gasplant This can be seen clearly from Figure 5
Figure 5 ndash Left CO2 emission rates for gas coal and peat fuel generators as afunction of total system demand High wind generation is indicated in light blueand low wind generation is shown in dark blue Right Empirical probabilitydistribution for CO2 emission rates for ldquohighrdquo (green) and ldquolowrdquo (pink windgeneration ie lower or higher than the median wind generation The coal andgas plant portfolio is more likely to be found in a low emission state at high windgeneration This effect is far stronger for gas than for coal
Emissions intensity fall linearly with wind penetration A summary of thelinear regression fit is shown in Table 1 The intercept 053tCO2MWh corre-sponds to grid average emissions intensity in the absence of wind The fittedslope -028tCO2MWh corresponds to emissions savings due to wind genera-tion The displacement effectiveness of wind power is therefore just 53 (Ifstart-up emissions are omitted the fit parameters become 052tCO2MWh and03tCO2MWh respectively) If there was no wind in 2011 emissions wouldhave been 129MtCO2 versus 118MtCO2 observed ie a savings of asymp 9
It seems surprising at first sight that emissions savings of 028tCO2MWhis less than the emissions intensity of the cleanest thermal generators on thegrid Figure 4 To understand how this arises it is necessary to drill downand see how individual generators respond to wind generation In general therelationship between an individual generator and total system demand (or total
9
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
example peat provided only 8 of generation but produced 19 of emissionsWind power displaces gas generation and therefore it is not surprising thatperiods of high wind generation are associated with lower emissions from gasplant This can be seen clearly from Figure 5
Figure 5 ndash Left CO2 emission rates for gas coal and peat fuel generators as afunction of total system demand High wind generation is indicated in light blueand low wind generation is shown in dark blue Right Empirical probabilitydistribution for CO2 emission rates for ldquohighrdquo (green) and ldquolowrdquo (pink windgeneration ie lower or higher than the median wind generation The coal andgas plant portfolio is more likely to be found in a low emission state at high windgeneration This effect is far stronger for gas than for coal
Emissions intensity fall linearly with wind penetration A summary of thelinear regression fit is shown in Table 1 The intercept 053tCO2MWh corre-sponds to grid average emissions intensity in the absence of wind The fittedslope -028tCO2MWh corresponds to emissions savings due to wind genera-tion The displacement effectiveness of wind power is therefore just 53 (Ifstart-up emissions are omitted the fit parameters become 052tCO2MWh and03tCO2MWh respectively) If there was no wind in 2011 emissions wouldhave been 129MtCO2 versus 118MtCO2 observed ie a savings of asymp 9
It seems surprising at first sight that emissions savings of 028tCO2MWhis less than the emissions intensity of the cleanest thermal generators on thegrid Figure 4 To understand how this arises it is necessary to drill downand see how individual generators respond to wind generation In general therelationship between an individual generator and total system demand (or total
9
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
Estimate Std Error t value Pr(gt|t|)(Intercept) 05253 00008 67253 00000
Wind Penetration -02788 00035 -7938 00000
Table 1 ndash Fit parameters and standard error for grid emissions intensity(tCO2MWh) vs wind penetration
wind) is non-linear and noisy However since linear behaviour is observed for thegrid as a whole Table 1 it can be assumed that this derives from relationshipsof the form co2g = αgD + βgW at the individual generator level Here co2gis emissions rate of generator g D is system demand and W is wind powerMultiple linear regression yields the fit parameters αg and βg for the 35 thermalgenerators shown in Table Significant negative value of βg indicates thatemissions from generator g are displaced by wind It is clear from Table thatmost of the displacement of thermal plant emissions occurs at just four of themodern base-load gas units (CCGT)
With this information a simple example illustrates how efficiency losses canpush CO2 savings below the average emission intensity of the CCGT generatorswhich are displaced by wind At full-load (1600MW maximum efficiency) av-erage emissions intensity of the four units is 035tCO2MWh according to themodel input-output curves At part-load (770MW minimum stable operatingcapacity) emissions intensity rise to 04tCO2MWh Assume that initially thefour CCGT plant are operating at optimal full-load1600MW and wind gener-ation is zero If wind generation increases to 840MW their combined outputdrops to their minimum operation capacity 770MW The change in emissionsrate per unit wind power in this scenario is (035 x 1600 - 04 x 770)840 =03tCO2MWh This illustrates how efficiency losses alone can lower emissionssavings below the emissions intensity of the cleanest thermal plant
The presence of electricity imports and exports means that grid averageemissions intensity can be expressed in different ways For example carbonintensity can be expressed with respect to total system demand (as above)system demand net of exports (ie ldquodomestic demandrdquo) or system demandnet of imports (ie ldquodomestic generationrdquo) This also affects how wind powersavings are expressed In the case of Ireland in 2011 SEMO ldquoNIJIrdquo data showthat total imports and exports were 3 and 1 of demand respectively sothat the differences between these measures of carbon intensity are relativelysmall In other situations the differences may be substantial With respect toldquodomestic demandrdquo and ldquodomestic generationrdquo zero-wind grid intensity were053tCO2MWh and 055tCO2MWh respectively while wind power savingswere 026tCO2MWh an 030tCO2MWh respectively Corresponding displace-ment effectiveness were 50 and 56
10
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
generator fuel alpha betaADC CCGT 00264 -00502DB1 CCGT 00400 00029HNC CCGT 00317 -00562HN2 CCGT 00388 -00143PBC CCGT 00327 -00027TYC CCGT 00251 -00586WG1 CCGT 00432 -00528SK3 CHP 00076 00031SK4 CHP 00088 00020MP1 coal 00523 -00238MP2 coal 00569 -00414MP3 coal 00564 -00137LR4 peat 00312 -00033ED1 peat 00292 00042WO4 peat 00260 00220AD1 OGCT 00026 00126AT1 OGCT 00014 00048AT2 OGCT 00004 00021AT4 OGCT 00001 00003NW4 OGCT 00000 00000NW5 OGCT 00049 00023MRT OGCT 00012 00007GI1 OGCT 00002 -00005GI2 OGCT 00001 -00005GI3 OGCT 00007 -00020RH1 oil 00001 -00001RH2 oil 00000 -00001TB1 oil 00003 -00008TB2 oil 00002 -00004TB3 oil 00030 -00084TB4 oil 00017 -00051ED3 oil 00002 -00005ED5 oil 00002 -00004TP1 oil 00000 -00001TP3 oil 00000 -00001All 05235 -02788
Table 2 ndash Displacement of generator emissions by wind power using the lin-ear response model The multiple regression fits assume zero intercept To-tals
sumαg represents the grid average intensity and
sumβg represents wind power
savings (tCO2WMh) Most of the emissions reductions occurred at just fourmodern CCGT plants shown in boldface Aghada (commissioned in 2010)Huntstown(2002) Tynagh(2006) and Whitegate (2010) The anti-correlation be-tween wind and emissions at WO4 (West Offaly peat plant) arose because therewas an outage at this plant during the summer when wind generation is lowestThe data suggest that MP2 increased to compensate
11
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
4 Conclusion
As currently deployed wind power is a supplementary power source whose roleis to reduce fossil fuel use by displacing thermal generation The Irish situationis typical in the sense that it has rapidly growing wind penetration embedded ina diverse portfolio of thermal plant A detailed empirical model of operationalCO2 savings was developed for 2011 It is found that savings of 028tCO2MWhwere achieved versus a zero-wind emissions intensity of 053tCO2MWh Thisestimate is at the lower end of expectations[9] In particular it is significantlylower than the emissions intensity of the CCGT plant which play the primaryrole in balancing wind generation Effectiveness is likely to fall further as windpenetration increases[10 11]
Assessments of the economic or environmental benefit of wind power arenot credible unless they are based on accurate emissions (and fuel) savingsThis study suggests that savings may be lower than contemplated by publicagencies to date The Irish government has an ambitious target of meeting 37of domestic electricity demand using wind power by 2020 It is a concern that at17 wind penetration the system is already in a regime where effectiveness isapproaching asymp 50 even before significant curtailment andor exports of windpower begin to occur
Finally life-cycle estimates of CO2 emissions involved in construction andinstallation of wind power are sensitive to assumptions about the capacity factoreconomic life of wind turbines infrastructure requirement etc[19] Estimates arein the range 0002-008 tCO2MWh At the upper end of this range life-cycleemissions are a significant fraction of operational CO2 savings
References
[1] Global Warming The complete briefing Third Edition John HoughtonCambridge University Press 2004
[2] For example ldquoDirective 200928EC on renewable energy implemented byMember States by December 2010 sets ambitious targets for all MemberStates such that the EU will reach a 20 share of energy from renewablesources by 2020 and a 10 share of renewable energy specifically in thetransport sectorrdquo httpeceuropaeuenergyrenewablestargets_
enhtm
[3] Wind power the economic impact of intermittency G Cornelis van KootenLetters in Spatial and Resource Sciences (2010) 3 117
[4] Blowing Away the Myths British Wind Energy Association Report February2005 p 4 recommended use of emissions savings of 086tCO2MWhhttpwwwbweacompdfref_threepdf BWEA currently recommend useof a ldquogrid averagerdquo number 043tCO2MWh httpwwwbweacomedu
calcshtml
12
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
[5] Emissions savings from wind power generation Evidence from Texas Cali-fornia and the Upper Midwest Daniel T Kaffine Brannin J McBee JozefLieskovsky Working Paper Colorado School of Mines
[6] Wind turbines as yet unsuitable as electricity providers C le Pair F Udoand K de Groot Europhysics News Vol 43 No 2 2012 pp 22-25
[7] Why wind power does nor deliver the expected emissions reductions HInnhaber Renewable and Sustainable Energy Reviews 15(2011) 2557-2562
[8] Wind Power in the UK Sustainable Development Commission Novem-ber 2005 SDC used a wind savings value 035tCO2MWh (ie basedon CCGT emissions) httpwwwsd-commissionorgukdatafiles
publicationsWind_Energy-NovRev2005pdf
[9] Impact of Wind Power Generation In Ireland on the Operation of Conven-tional Plant and the Economic Implications ESB National Grid February2004
[10] System-Wide Emissions Implications of Increased Wind Power Penetra-tion Lauren Valentino Viviana Valenzuela Audun Botterud Zhi Zhou andGuenter Conzelmann Environmental Science and TechnologyEnviron SciTechnol 2012 46 (7) pp 42004206
[11] Quantifying the Total Net Benets of Grid Integrated Wind E Denny andM OMalley IEEE Transactions on Power Systems 2007 22 (2) p 605-615
[12] The EU Emissions Trading System (EU ETS) httpeceuropaeu
climapoliciesg-gasindex_enhtm
[13] wwweirgridcom
[14] Sustainable Energy Authority of Ireland Provisional Energy Balance2011 httpwwwseaiiePublicationsStatistics_Publications
Energy_Balance
[15] Single Electricity Market Operator httpwwwsemo-ocom
[16] SEM-11-052 2011-12 Validated SEM Generator Data Parameters PUBLICv1xls Single Electricity Market Operator document
[17] All-Island Wind and Fuel Mix Summary Report 2011 Eirgridand SONI operations httpwwweirgridcomoperations
systemperformancedataall-islandwindandfuelmixreport
[18] How less became moreWind power and unintended consequencesin the colorado energy market httpwwwbentekenergycom
WindCoalandGasStudyaspx
[19] Life Cycle Greenhouse Gas Emissions of Utility-Scale Wind Power StaceyL Dolan and Garvin A Heath Journal of Industrial Ecology 16(s1) p136-154 April (2012)
13
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
Source
IDNam
eFuel
Min
Cap
MaxCap
Ram
pUp
Ram
pD
own
Cold
Start
Warm
Start
HotStart
HotToW
arm
Warm
ToCold
Aughin
ish
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Aughin
ish
SK
4Sealrock
4(Aughin
ish
CHP)
Gas
400
0830
060
060
012000
010000
08000
080
0240
0Edenderry
ED
1Edenderry
PeatBio
mass
410
01176
017
617
623080
010840
04360
040
0480
0ESBPG
AA1
Ardnacrusha
Unit
1120
0210
060
060
000
000
000
0120
0480
0ESBPG
AA2
Ardnacrusha
Unit
2120
0220
060
060
000
000
000
0120
0480
0ESBPG
AA3
Ardnacrusha
Unit
3120
0190
060
060
000
000
000
0120
0480
0ESBPG
AA4
Ardnacrusha
Unit
4120
0240
060
060
000
000
000
0120
0480
0ESBPG
AD
1Aghada
Unit
1G
as
360
02580
051
051
043020
021850
012730
050
0670
0ESBPG
AT1
Aghada
CT
Unit
1G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT2
Aghada
CT
Unit
2G
as
150
0900
050
050
0630
0630
0630
0120
0480
0ESBPG
AT4
Aghada
CT
Unit
4G
as
150
0900
050
050
0630
0630
0630
0120
0480
0Endesa
GI1
Great
Isla
nd
Unit
1O
il250
0540
007
010
05620
04490
02180
0120
0480
0Endesa
GI2
Great
Isla
nd
Unit
2O
il250
0490
007
010
05620
04490
02180
0120
0480
0Endesa
GI3
Great
Isla
nd
Unit
3O
il300
01130
007
015
07430
06000
02930
0120
0600
0ESBPG
MP1
Moneypoin
tUnit
1FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP2
Moneypoin
tUnit
2FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MP3
Moneypoin
tUnit
3FG
DSCR
Coal
990
02850
030
040
0146200
069200
043600
0120
0600
0ESBPG
MRT
Marin
aNo
ST
Gas
200
0880
050
050
0630
0630
0630
0120
0280
0ESBPG
NW
4Northwall
Unit
4G
as
873
01630
037
8120
0800
0800
0800
0120
0600
0ESBPG
NW
5Northwall
Unit
5G
as
40
01040
080
080
0500
0500
0500
0120
0480
0ESBPG
PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
2320
04800
0110
0110
028000
018000
015000
080
01120
0ESBPG
WO
4W
est
Offaly
Power
Peat
450
01370
007
007
07500
06000
04500
0120
0600
0Synergen
DB1
Dublin
Bay
Power
Gas
2090
04150
0100
090
077000
026040
026000
0120
0600
0Tynagh
TYC
Tynagh
Gas
1940
03885
0125
0125
050330
029440
020170
0120
0480
0Virid
ian
HN2
Huntstown
Phase
II
Gas
1940
04040
0200
0200
06440
05310
03180
0120
0600
0Virid
ian
HNC
Huntstown
Gas
1840
03430
070
070
047720
028030
08350
0120
0600
0ESBPG
AD
CAghada
CCG
TG
as
2130
04350
0124
3124
324000
018000
012000
0120
0600
0ESBPG
LR4
Lough
Rea
Peat
680
0910
013
713
75000
04000
03000
0120
0480
0Bord
Gais
WG
1W
hitegate
Gas
1800
04450
0300
0300
04370
03300
02230
0120
0600
0Endesa
RH1
Rhode
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
RH2
Rhode
2D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Endesa
TB1
Tarbert
Unit
1O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB2
Tarbert
Unit
2O
il200
0540
010
010
05620
04490
02180
0120
0600
0Endesa
TB3
Tarbert
Unit
3O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TB4
Tarbert
Unit
4O
il349
02400
017
022
031800
019340
010720
0140
01200
0Endesa
TP1
Tawnaghm
ore
1D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0Edenderry
ED
3Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Edenderry
ED
5Cushaling
Distilla
te
200
0580
050
050
0200
0200
0200
005
010
0Endesa
TP3
Tawnaghm
ore
3D
istilla
te
120
0520
050
0100
0240
0240
0240
0120
0600
0ESBPG
ER1
Erne
Unit
140
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER2
Erne
Unit
240
0100
050
0100
000
000
000
0120
0480
0ESBPG
ER3
Erne
Unit
350
0225
0100
0225
000
000
000
0120
0480
0ESBPG
ER4
Erne
Unit
450
0225
0100
0225
000
000
000
0120
0480
0ESBPG
LE1
Lee
Unit
130
0150
024
0150
000
000
000
0120
0480
0ESBPG
LE2
Lee
Unit
210
040
006
040
000
000
000
0120
0480
0ESBPG
LE3
Lee
Unit
330
080
015
080
000
000
000
0120
0480
0ESBPG
LI1
Liffe
yUnit
130
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI2
Liffe
yUnit
230
0150
050
0100
000
000
000
0120
0480
0ESBPG
LI4
Liffe
yUnit
404
040
020
020
000
000
000
0120
0480
0ESBPG
LI5
Liffe
yUnit
502
040
000
320
000
000
000
0120
0480
0ESBPG
TH1
Turlo
ugh
HillUnit
150
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH2
Turlo
ugh
HillUnit
250
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH3
Turlo
ugh
HillUnit
350
0730
02100
02700
000
000
000
0120
0480
0ESBPG
TH4
Turlo
ugh
HillUnit
450
0730
02100
02700
000
000
000
0120
0480
0
Table
3ndash
(a)
The
50
gri
d-c
onnec
ted
non-w
ind
gen
erato
rsuse
din
this
study
Min
Cap
and
MaxC
ap
are
min
imum
and
maxiu
mum
stable
op
erati
ng
capaci
ties
(MW
)R
am
pU
pand
Ram
pD
own
are
maxiu
mum
ram
pup
rate
s(M
Wm
in)
Cold
Sta
rt
Warm
Sta
rtand
HotS
tart
are
ther
mal
state
dep
enden
tst
art
up
ener
gy
cost
s(G
J)
HotT
oW
arm
and
Warm
ToC
old
are
cooling
dow
nti
mes
(hours
)A
dapte
dfr
om
Ref
[1
6]
14
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-
IDNam
eFuel
NoLoad
Cap1
Cap2
Cap3
Cap4
IHRS01
IHRS12
IHRS23
IHRS34
SK
3Sealrock
3(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0SK
4Sealrock
4(Aughin
ish
CHP)
Gas
1000
0400
0830
050
050
0ED
1Edenderry
PeatBio
mass
4976
0880
01120
01180
039
389
589
5AD
1Aghada
Unit
1G
as
1828
31200
01900
02580
078
184
585
2AT1
Aghada
CT
Unit
1G
as
2950
5400
0900
081
0100
5AT2
Aghada
CT
Unit
2G
as
2950
5400
0900
081
0100
5AT4
Aghada
CT
Unit
4G
as
2950
5400
0900
081
0100
5G
I1G
reat
Isla
nd
Unit
1O
il510
7250
0450
0540
0135
9135
9136
7G
I2G
reat
Isla
nd
Unit
2O
il510
7250
0450
0490
0135
9135
9136
7G
I3G
reat
Isla
nd
Unit
3O
il1026
5300
0980
01130
0108
8108
8109
8M
P1
Moneypoin
tUnit
1FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P2
Moneypoin
tUnit
2FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
P3
Moneypoin
tUnit
3FG
DSCR
Coal
1737
71950
02800
02850
094
895
8140
9M
RT
Marin
aNo
ST
Gas
2588
4470
0810
0880
086
694
8114
1NW
4Northwall
Unit
4G
as
3513
4870
01150
01620
060
768
482
3NW
5Northwall
Unit
5G
as
3336
1500
01040
090
397
0PBC
Poolb
eg
Com
bin
ed
Cycle
Gas
4521
14800
05100
061
369
9W
O4
West
Offaly
Power
Peat
1186
71370
090
0D
B1
Dublin
Bay
Power
Gas
4793
42030
04150
050
051
6TYC
Tynagh
Gas
6040
01940
02500
04040
040
054
657
4HN2
Huntstown
Phase
II
Gas
6036
01950
02300
04120
040
056
257
4HNC
Huntstown
Gas
5412
02000
02300
02500
03520
040
051
959
960
1AD
CAghada
CCG
TG
as
5923
92130
04300
04350
040
054
055
6LR4
Lough
Rea
Peat
852
9910
086
5W
G1
Whitegate
Gas
6666
81850
03990
04600
040
052
661
1RH1
Rhode
1D
istilla
te
850
1120
0520
098
298
2RH2
Rhode
2D
istilla
te
850
1120
0520
098
298
2TB1
Tarbert
Unit
1O
il446
6200
0460
0540
0116
3116
3117
5TB2
Tarbert
Unit
2O
il446
6200
0460
0540
0116
3116
3117
5TB3
Tarbert
Unit
3O
il2476
1350
01000
01800
02400
080
780
790
691
5TB4
Tarbert
Unit
4O
il2476
1350
01000
01800
02400
084
084
094
396
4TP1
Tawnaghm
ore
1D
istilla
te
866
2120
0520
0100
095
9ED
3Cushaling
Distilla
te
850
0580
090
0ED
5Cushaling
Distilla
te
850
0580
090
0TP3
Tawnaghm
ore
3D
istilla
te
866
2120
0520
0100
095
9
Table
4ndash
(b)
Addit
ional
para
met
ers
for
35
gri
d-c
onnec
ted
ther
mal
gen
erato
rsuse
din
this
study
NoL
oad
isth
eex
trap
ola
ted
zero
load
(Cap0)
ener
gy
use
(in
GJh)
Capaci
tyP
oin
ts(C
ap1
etc
MW
)are
use
dto
spec
ify
the
hea
tra
tecu
rve
IHR
Sva
lues
are
Incr
emen
tal
Hea
tR
ate
Slo
pes
(GJM
Wh)
defi
ned
bet
wee
nea
chpair
of
capaci
typ
oin
ts
Thes
edata
are
use
dto
crea
test
ati
cC
O2
emis
sions
vs
gen
erati
on
curv
es(C
O2h
vs
MW
)or
ldquoin
put-
outp
utrdquo
curv
esfo
rea
chgen
erato
rA
dapte
dfr
om
Ref
[1
6]
15
- Outline of the problem
- Data and model
- Results and Discussion
- Conclusion
-