GRID SYSTEM OPERATION AND PERFORMANCE REPORT
PENINSULAR MALAYSIA: FIRST HALF 2012 (JANUARY – JUNE 2012)
Installed Capacity: 21,817 MW
Maximum Demand: 15,826 MW (20 June 2012 @ 1600 hours)
Maximum Daily Energy: 328.7 GWh (20 June 2012)
A. OBSERVATIONS:
1. The first‐half 2012 (Jan‐June) year‐on‐year monthly basis of Maximum Demands show a steady growth trend. The highest Maximum Demand (MD) stood at 15,826 MW, which recorded on 20th June 2012. As compared to the previous year 2011 which the highest Maximum Demand was 15,476 MW, this first‐half 2012 shows an increase of 2.3% or 350MW.
2. Correspondingly, Maximum Daily Energy Demand has also shows a steady growth trend in the first‐half 2012. The highest energy demand has increased by 5.6% from 311.4 GWh in January to 328.7 GWh in June 2012. Last year highest energy demand was lower at 318.4 GWh.
3. In conjunction with the increased demand, the volume of gas allocated to the power sector was higher than the year before. The average daily gas off‐take by the power sector went from 981 mmscfd in 2011 to 1,014 mmscfd in first half 2012. So far, total curtailments for first half 2012 were 173 days as compared to 194 days for the whole year of 2011.
4. As a result, the energy generated from gas plants increased from 42.7% in 2011 to 44.2% for the first half 2012. The contribution from the hydroelectric plants was also increased from 5.6% to 6.5% due to higher water inflows. To compensate the increased contribution from gas and hydro generations, the system had to utilise more coals and that resulted into an increase in coal utilisation from 44.7% in 2011 to 45.9% in 2012. Utilisations of substitute fuels such as oil and distillate have also been reduced due to gas supply improvement. 5. The fire incident at Bekok C gas platform occurred in December 2010 has caused significant curtailment to gas supply until today. However, the supply of gas to the power sector will be improved significantly when the re‐gasification terminal (RGT) project scheduled to complete by end of 2012. As of now, the gas allocation was still limited to the maximum volume of 1,150 mmscfd as per Economic Council’s decision on 10th January 2012.
6. In terms of generation capacity, Peninsular has more than adequate capacity to serve the required demand. Install capacity will still remain at 21,817 MW for the rest of 2012. Currently the on‐going projects Ulu Jelai Hydro plant with the capacity of 250 MW, coal fired plants 1000 MW Janamanjung Unit 4 and 1000 MW Tanjung Bin Unit 4 are expected to be completed in 2015 and 2016.
7. Transmission network constraint was recorded for Penang Island supply from mainland. The constraint occurred on 18th June 2012 for a period of 33 days, which involved 132 kV cable from SKS Prai to Gelugor. There were five incidents of load loss of more than 50 MW recorded in Peninsula Malaysia for the first‐half 2012.
B. SUPPLY:
Installed Capacity (Start): 21,817 MW (1 January)
Installed Capacity (End): 21,817 MW (30 June)
Maximum Demand: 15,826 MW (20 June / Wednesday / 1600 hrs)1
Daily Energy: 328.7 GWh (20 June / Wednesday)2
Minimum Trough: 7,976.0 MW (24 Jan / Tuesday / 0800 hrs)
B.1 Installed Capacity
Type Main Fuel MW
Combined Cycle Gas Turbine Gas 9,373
Conventional Thermal Coal 7,170
Conventional Thermal Gas 840
Open Cycle Gas Turbine Gas 2,455
Open Cycle Gas Turbine Distillate 68
Hydroelectric Hydro 1,911
Total 21,817
1 New Maximum Demand, previous yearly record was 15,476 MW on 9th May 2011 2 New Highest Energy, previous yearly record was 318.4 GWh on 10th May 2011 B.3 Average Daily Generation Profile
DAILY GENERATION PROFILE (JAN ‐ JUNE 2012) 16,000
14,000
12,000
10,000
8,000
6,000
4,000
2,000
‐ 1‐Jan 11‐Jan 21‐Jan 31‐Jan 10‐Feb 20‐Feb 1‐Mar 11‐Mar 21‐Mar 31‐Mar 10‐Apr 20‐Apr 30‐Apr 10‐May 20‐May 30‐May 9‐Jun 19‐Jun 29‐Jun Date ST‐Coal CCGT‐Gas OCGT‐Gas ST‐Gas ST‐Oil Hydro Cogen Distillate IC SR
B.3 Average Normal Weekdays Generation Profile
DAILY GENERATION PROFILE (WORKING DAYS) 16,000
14,000
12,000
10,000
8,000
6,000
4,000
2,000
‐ 3‐Jan 13‐Jan 23‐Jan 2‐Feb 12‐Feb 22‐Feb 3‐Mar 13‐Mar 23‐Mar 2‐Apr 12‐Apr 22‐Apr 2‐May 12‐May 22‐May 1‐Jun 11‐Jun 21‐Jun Date ST‐Coal CCGT‐Gas OCGT‐Gas ST‐Gas ST‐Oil Hydro Cogen Distillate IC SR B.4 Spinning Reserve (Average MW on Half‐hourly Basis)
SPINNING RESERVE (JAN ‐ JUNE 2012) MW 2,500.0
2,000.0
1,500.0
1,000.0
500.0
‐ 0:00 0:30 1:00 1:30 2:00 2:30 3:00 3:30 4:00 4:30 5:00 5:30 6:00 6:30 7:00 7:30 8:00 8:30 9:00 9:30 10:00 10:30 11:00 11:30 12:00 12:30 13:00 13:30 14:00 14:30 15:00 15:30 16:00 16:30 17:00 17:30 18:00 18:30 19:00 19:30 20:00 20:30 21:00 21:30 22:00 22:30 23:00 23:30 Spinning Reserve (half‐hourly average)
B.5 Generation Mix3
GENERATION MIX (JAN ‐ JUNE 2012)
3.61% 0.04% 0.68% 6.46%
43.40%
46.38%
Gas Coal Hydro MFO & DF Co‐Gen Interconnection
3 Indicative generation mix based on SCADA readings. C. DEMAND:
C.1 Monthly Maximum Demand (from 2009 to June 2012)
MAXIMUM DEMAND (MD) FOR 2009, 2010, 2011 & 2012 MW 16,000
14,000
12,000
10,000
8,000
6,000
4,000
2,000
0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2009 2010 2011 2012 C.2 Monthly Energy Demand (from 2009 to June 2012)
ENERGY FOR 2009, 2010, 2011 & 2012 GWh 350
300
250
200
150
100
50
0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 2009 2010 2011 2012 D. SUPPLY / DEMAND ADEQUACY:
D.1 Availability Status
MW %
Maximum Demand 15,826.0 72.5
Spinning Reserve 1,327.4 6.1
Non‐Spinning Reserve 1,932.4 8.9
Operating Reserve 4,356.8 20.0
Unscheduled Outage 725.0 3.3
Scheduled Outage 1,416.8 6.5
Capacity Deration 589.4 2.7
AVAILABILITY (JAN ‐ JUNE 2012) 22,000MW
20,000
18,000
16,000
14,000
12,000
10,000
8,000
6,000
4,000
2,000
0 1‐Jan 1‐Feb 1‐Mar 1‐Apr 1‐May 1‐Jun Date MD Spinning Reserve Avai‐Capacity Unscheduled Scheduled Deration
D.2 Monthly Availability Trend
7,000
6,000
5,000
4,000
3,000
2,000
1,000
0 Unscheduled Outage Scheduled Outage Deration Operating Reserve
Jan Feb Mar Apr May Jun
D.3 Generation Profile during Highest Maximum Demand of 15,826 MW and Energy of 328.7 GWh on 20th June 2012
20 JUNE 2012 (WEDNESDAY) 18,000 16,000 S.Rsv IC 14,000 Distillate 12,000 ST-Oil 10,000 ST-Gas 8,000 Co-Gen OCGT 6,000 Hydro 4,000 CCGT 2,000 Coal 0 0:00 1:30 3:00 4:30 6:00 7:30 9:00 10:30 12:00 13:30 15:00 16:30 18:00 19:30 21:00 22:30
D.4 Generation Profile during Highest Energy of 328.7 GWh and Maximum Demand of 15,826 MW and on 20th June 2012
20 JUNE 2012 (WEDNESDAY) 18,000 16,000 S.Rsv IC 14,000 Distillate 12,000 ST-Oil 10,000 ST-Gas 8,000 Co-Gen OCGT 6,000 Hydro 4,000 CCGT 2,000 Coal 0 0:00 1:30 3:00 4:30 6:00 7:30 9:00 10:30 12:00 13:30 15:00 16:30 18:00 19:30 21:00 22:30
D.5 Generation Profile during Lowest Trough of 7,976 MW, Lowest Energy of 219.6 GWh and Maximum Demand of 10,732 GWh on 24th January 2012
24 JANUARY 2012 (TUESDAY) 18,000
16,000 S.Rsv 14,000 IC Distillate 12,000 ST-Oil 10,000 ST-Gas 8,000 Co-Gen 6,000 OCGT 4,000 Hydro CCGT 2,000 Coal 0 0:00 1:30 3:00 4:30 6:00 7:30 9:00 10:30 12:00 13:30 15:00 16:30 18:00 19:30 21:00 22:30
E. FUEL AVAILABILITY
E.1 Gas
Average Gas Volume Nominated 1,088 mmscfd Average Gas Volume Allocated 1,014 mmscfd Total Volume Nominated 198,033 mmscf Total Volume Allocated 184,624 mmscf Total Production (Kerteh and JDA) 364,081 mmscf Average Production (JDA) 370 mmscfd Average Production (Kerteh) 1,630 mmscfd Total Number of Curtailment (day)4 173
Daily Nomination and Allocation to Power Sector
GAS NOMINATION &ALLOCATION (JAN ‐ JUNE 2012) 1,400
1,300
1,200
1,100
1,000
900
800 Volume Nominated: 198,033 mmscf (1,088 mmscfd) Volume Allocated: 184,624 mmscf (1,014 mmscfd) Days of Curtailment: 173 700 Scheduled: 26 days (PGB letter dated 9 November 2011) Unscheduled: 147 days
600 1‐Jan 8‐Jan 15‐ 22‐ 29‐ 5‐Feb 12‐ 19‐ 26‐ 4‐Mar 11‐ 18‐ 25‐ 1‐Apr 8‐Apr 15‐ 22‐ 29‐ 6‐May 13‐ 20‐ 27‐ 3‐Jun 10‐ 17‐ 24‐ Jan Jan Jan Feb Feb Feb Mar Mar MarDate Apr Apr Apr May May May Jun Jun Jun Gas Nomination Gas Allocation
4 Based on daily maximum gas requirement of 1,250 mmscfd. Allocation to power sector has been fixed at 1,150 mmscfd as per Economic Council’s decision on 10th January 2012. E.2 Coal
Stock Level
COAL STOCK LEVEL (JAN ‐ JUNE 2012) MT 3,200,000 MAX : 3.15 MT
2,800,000
2,400,000
MIN : 1.96 MT 2,000,000
1,600,000
1,200,000
800,000
400,000
0
Date JMJG KEV TBIN JEV Applicable Coal Price
E.3 Hydro (Lake Level)
Temengor
TEMENGGOR LAKE LEVEL FOR 2010, 2011 & 2012 (JAN‐JUNE) m 249 Spill Level : 284.4 m
247
245
243
241
239
237
235
233 1‐Jan 1‐Feb 1‐Mar 1‐Apr 1‐May 1‐Jun 1‐Jul 1‐Aug 1‐Sep 1‐Oct 1‐Nov 1‐Dec Date 2010 2011 2012 Kenyir
KENYIR LAKE LEVEL FOR 2010, 2011 & 2012 (JAN‐JUNE) m 146 Spill Level : 145 m
144
142
140
138
136
134
132
130 1‐Jan 1‐Feb 1‐Mar 1‐Apr 1‐May 1‐Jun 1‐Jul 1‐Aug 1‐Sep 1‐Oct 1‐Nov 1‐Dec Date 2010 2011 2012 F. NETWORK
F.1 Line Constraints
Location Impact Contingency Limit Days Last Day
1. Gelugor – SKS Prai Penang Gelugor – SKS Prai 132kV 130% 33 18 June 132kV Cable 1 Island Cable 2 12
F.2 Load Loss above 50 MW
Date Duration Component Load Loss Energy Not Cause(s) (Start/End) (MW) Served (MWh)
25 Jan 1106/1512 Larkin, Johor 132/22 kV 70 181.5 Damanged to Incomer 22kV
1 Mac 2117/2332 NUNI, Bangi, Selangor & 71 96.59 132/33kV Putrajaya 275/132/33/11 90MVA T4 kV faulty
6 Mac 1817/1913 Alor Setar to Kota Setar 66 23.4 Outside L1 & L2 132 kV work
28 Apr 1908/1941 Pasir Gudang Power 81 42.91 132 kV Station 132 kV busbar tripped
25 Mac 0958/1140 KL North to Damansara 106 49.77 Dead End Height 132 kV Clamp conductor faulty
Prepared by: Electricity Market Operations Unit Electricity Supply & Market Regulations Department Suruhanjaya Tenaga 17 August 2012