jump to first page national instantaneous reserves market vladimir krichtal transpower new zealand
TRANSCRIPT
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National Instantaneous
Reserves Market
Vladimir Krichtal
Transpower New Zealand
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2
HVDC transfer model
NI
SI
Power transfer
Reserves Transfer
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3
Economics behind reserve transfer
Reserves
Reserv
es
pri
ce
Risk
0
New Reserve price
Reserve price function
Reserve price
New Reserves price function
Local Reservescleared
Reserves Import
Reserve Revenue saving
Reserve price
decrease
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4
Frequency Stabiliser and Instantaneous Reserves Sharing
Time (sec.)
Reserves sharing (MW)
30sec
Frequency stabiliser dynamic
Instantaneous reserves sharing
Guaranteed reserves sharing level
250 MW
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5
500 100
800
250
0
-400
Amount of time (%)
Nort
h r
eceiv
ed
(M
W)
-250
Power transfer
NI reserves transfer
SI reserves transfer
HVDC load duration curve & reserves transfer ability
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6
Structure of power and reserves flows at the HVDC line
NI Reserves RampUp
NI power transfer
NI & SI Modulation Limits 0
Power flow limit overload
Power flow limit - stable state
Power dead band
SI Reserves RampDown
SI reserves transfer
NI reserves transfer
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7
Existing Risk-Reserve model
ILR
Gn RiskG1 RiskManual
Risk
DC Risk
HVDC
Zone Res. pool
Biggest Zone Risk =max(G1,..,Gn,Man,DCE,DCECE)=
G1
GEN GEN
Island’s Reserve Price
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8
New Reserves model
HVDC reserves transfer capability. Using instantaneous reserves from one reserve zone to cover generation risks in the other reserve zone.
New reserves price structure.
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9
Proposed Risk-Reserves model
ILR
G2 RiskG1 RiskManual
Risk
G1 Res pool
HVDCG2 Res pool
Man Res pool
HVDC Res pool
Res Export
ResImport
GEN GEN
DC Risk
G1 Res pool price
G1 Res pool price
G1 Res pool price
G1 Res pool price
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10
New Reserves model (1)T o t a l r e s e r v e i n z o n e
Rz
Ii
IMz
ILz
GENziz
z
RRRR :,,
G e n e r a t o r ’ s R is k _ R e s e r v e c o n s t r a in t s
GRziz
GENziziz IiRGR ,,, :,,
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11
New Reserves model (2)
M anual R isk – Reserve constraints.
MRz
Manzz RR :,
D C L in e’s R isk _ R eserv e co n stra in ts
LRz
IMzzz RPR :
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12
Reserve transfer constraints (1)
R e s e r v e t r a n s f e r c o n s t r a i n e d b y H V D Cr a m p - u p a n d r a m p - d o w n a b i l i t i e s .
ELoCapNI
IMSI PPR
NIEUpCapIM
NI PPR
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13
Reserve transfer constraints (2)R e s e r v e t r a n s f e r , c o n s t r a i n e d b y H V D Cm o d u l a t i o n l i m i t s
MLimz
IMz RR
R e s e r v e t r a n s f e r , c o n s t r a i n e d b y r e s e r v ea v a i l a b i l i t y i n a s o u r c e a r e a
1
01,1),( 11,
zIiz
ILz
GENziz
IMz KzzRRKR
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14
Zonal reserve price
LRz
MRz
Ii
GRzi
Rz
z
,
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15
Old- New Reserves Revenue Difference
)(
))(
)((
,,,
,,,
,
LRz
IMz
SINIz Ii
GRzi
GENzi
LRz
IMzz
MRzz
SINIz Ii
GRzi
GENziz
SINIz
Rzz
RR
RRR
RR
RDiff
z
z
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16
The SPD model prototype :
HVDC configuration aggregation.
HVDC Losses adjustment.
Estimating parameters of HVDC reserve transfer capabilities.
The SPD prototype coding for simulation a new SPD model with HVDC reserve transfer ability.
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17
Reduction of Energy and Reserves revenue and cost:
Reserves sharing between islands.
Co-optimisation between Energy and Reserves .
Applying shadow price of each binding risk in case of multiple risk contingency instead of one price for each reserve zone.
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18
Revenue Difference (May 2004)
-500000
-400000
-300000
-200000
-100000
0
100000
Time
Re
ve
nu
e D
iffe
ren
ce (
$)
Res6sRev Res60sRev EnerDemRev TotRev
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19
Total Cost Difference (May 2004)
-40000
-35000
-30000
-25000
-20000
-15000
-10000
-5000
0
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31
Time
To
tal
Co
st D
iffe
ren
ce (
$)
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20
Results
Total revenue saving reaches $9.6m. over 4 months.
Net economic benefit reaches $0.68m. over 4 months.