MESYUARAT PANEL PERUNDINGAN TENAGA

By Mr. Gurcharan Singh

Head (GSO)

10th JUNE 2014

Kuah

Melaka

Seremban

Georgetown

Kota

Bharu

Kuala

Terengganu

Ipoh

Kuantan

Shah Alam

Alor

Setar

Kangar

JOHOR

PAHANG

MELAKA

NEGERI SEMBILAN

SELANGOR

PERAK

KEDAH

PULAU PINANG

KELANTAN

TERENGGANU

PERLIS

WILAYAHPERSEKUTUAN

LANGKAWI

MELAKA

BERSIA

KENERING

TEMENGOR

KENYIR

SG PIAH UPPER

SG PIAH LOWER

JOR

WOH

ODAK

CHENDEROH

PERGAU

N

Johor

Bahru

PRAI

GELUGOR

SEGARI

CONNAUGHT

BRIDGE

SERDANG

KAPAR

POWERTEK

PD

POWER

GENTING

SANYEN

PORT

DICKSON

YTL

PASIR

GUDANG

PAKA

YTL

Ayer Tawar

Batu GajahPapan

Kuala Kangsar

Bukit TambunJunjung

Bukit Tengah

Gurun

Bedong

Kota Setar

Chuping

Bukit Tarek

KL (N)KL (E)

Hicom G

KL (S)

Salak Tinggi

Melaka

Kg Awah

Scudai

Telok Kalong

Tanah Merah

JANAMANJUNG

YAN

Yong Peng (N)

Bukit Batu

Sedili

Lenggeng

Yong Peng (E)

3

• 21,509 MWGENERATION

INSTALLED CAPACITY

• 11,222 MW (52.2%)TNB

• 10,287 MW (47.8%)IPP

• 16,583 MWMAXIMUM DEMAND

(29/05/14)

• 4,926 MW (29.7%)RESERVE CAPACITY

MARGIN

• 345.25 GWH/DAYHIGHEST ENERGY

DEMAND (25/6/2013)

404SUBSTATION

21,092CIRCUIT KILOMETRES

95,990MVA INSTALLED CAPACITY

SYSTEM HIGHLIGHTS

2014

17,152 MW

2015

17,697 MW

2016

18,282 MW

2017

18 ,880 MW

2018

19,492 MW

17,152MW

FORECAST DEMAND GROWTH

Average growth of 3.31% from 2014 - 2018

17,697MW

18,282MW

18,880MW19,492MW

To support the Demand growth and Generation plant-up, Transmission needs augmentation of National Grid System.

12,000

13,000

14,000

15,000

16,000

17,000

Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug

MW

Monthly Peak Demand, MW

FY 08/09 FY 09/10 FY10/11 FY11/12 FY12/13 FY13/14

MONTHLY MAXIMUM DEMAND FY 2008/2009 – FY 2013/2014

MONTHLY MAXIMUM DEMAND FY 2008/2009 – FY 2013/2014

FinancialYear

HighestMD (MW)

08/09 14,245

09/10 15,072

10/11 15,476

11/12 15,826

12/13 16,562

13/14 16,583

Maximum Demand for 2014 forecasted to increase during June to August impacted by the El-Nino effect.

GENERATION MIX 2002-2013

0%

10%

20%

30%

40%

50%

60%

70%

80%

90%

100%

FY0203 FY0304 FY0405 FY0506 FY0607 FY0708 FY0809 FY0910 FY1011 FY1112 FY1213 FY1314

Generation Mix For Peninsula Malaysia

COAL GAS HYDRO OIL DISTILLATE

• Major fuel mix in Peninsula

Malaysia - Coal and Gas

• Gas dependability reduced

from 75% in 2003 to 47% in

2013.

• Coal contributes increased

to 45% in 2013.

• For FY1314, coal

percentage has dropped

due to major rectification

work by stations for tube

leak problems.

• Oil and Distillate are back up

fuels during gas curtailments

and coal unit forced

outages.

43 4239

36 36

41

46

5357

59

128

3 31

5 4 4 4 4

0

10

20

30

40

50

60

70

2014 2015 2016 2017 2018

Pe

rce

nta

ge G

en

era

tio

n M

ix b

y Fe

ul

Gas Coal LNG Hydro

GENERATION MIX BY FUEL 2014 - 2018

• Future plant-up of coal units

pushes Coal to 59% in

2018.

• Gas and LNG kept at 37%

and hydro at 4%.

• Coal becomes major fuel

mix going forward due to its’

competitive pricing and

availability readiness.

Gas and LNG is differentiated by price and quantum.

• Below 1000mmscfd – GAS (Subsidised price)

• Above 1000mmscfd – LNG (Bintulu price)

GENERATION MIX BY FUEL 2014-2018

0

2

4

6

8

10

12

14

16

18

20

20

14

17.93

13.67

7.32

9.34

6.56

1.02 0.82 1.01 1.030.44

-98%

• The international benchmark

for system performance and

reliability.

• An index that measures the

severity of each system

disturbance relative to the size

of the system.

• Determined by calculating the

ratio of unsupplied energy

during an outage to the

energy that would be supplied

during one minute, if the

supplied energy was at its

peak value.

TNB managed to reduce the transmission system minutes from 20min in

2002 to 0.44min in 2013.

PERFORMANCE - SYSTEM MINUTES

SYSTEM MINUTES - BENCHMARKING

0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00

TRANSCO Phillipines

ELECTRANET Australia

ESKOM South Africa

RTE France

TNB Malaysia - 2013

12.23

8.30

4.73

2.30

0.44

Minutes

For 2013, TNB’s performance was better than KEPCO and TEPCO, two

major utility in Asia.

KEPCO: 25.106 minutes

TEPCO: 9 minutes

Bukit TengahBukit Tengah

Kuah

Melaka

Seremban

Georgetown

Kota

Bharu

Kuala

Terengganu

Ipoh

Kuantan

Shah Alam

Alor

Setar

Kangar

JOHOR

PAHANG

MELAKA

NEGERI SEMBILAN

SELANGOR

PERAK

KEDAH

PULAU PINANG

KELANTAN

TERENGGANU

PERLIS

WILAYAHPERSEKUTUAN

LANGKAWI

MELAKA

BERSIA

KENERING

TEMENGOR

KENYIR

SG PIAH UPPER

SG PIAH LOWER

JOR

WOH

ODAK

CHENDEROH

PERGAU

Johor

Bahru

PRAI

GELUGOR

SEGARI

CONNAUGHT

BRIDGE

SERDANG

KAPAR

POWERTEK

PD

POWER

GENTING

SANYEN

PORT

DICKSON

YTL

PASIR

GUDANG

PAKA

YTL

Ayer Tawar

Batu GajahPapan

Kuala Kangsar

Bukit TambunJunjung

Bukit Tengah

Gurun

Bedong

Kota Setar

Chuping

Bukit Tarek

KL (E)

Hicom G

KL (S)

Salak Tinggi

Melaka

Kg Awah

Scudai

Telok Kalong

Tanah Merah

JANAMANJUNG

YAN

Yong Peng (N)

Bukit Batu

Sedili

Lenggeng

Yong Peng (E)

Prai (TNB)2 x 535 MW CCGT (Jan 2016)

Connaught Bridge (TNB)1 x 350 MW CCGT(Sep 2015)

Janamanjung (TNB)Unit 4: 1 x 1000 MW Coal (Mar 2015)Unit 5: 1x1000 MW Coal (Oct 2017)

Tg Bin (IPP)Unit 4: 1 x 1000 MW Coal (Mar 2016)

PCP, Pengerang (IPP)400 MW Import (Jul 2017)

Hulu Terengganu (TNB)250 MW Hydro(Sep 2015)

Ulu Jelai (TNB)372MW Hydro(2018)

Chenderoh (TNB)12MW Hydro(Dec 2015)

Tembat (TNB)15MW Hydro

ADDITIONAL 7,500 MW GENERATION CAPACITY COMMITTED UNTIL 2019

1MDB (IPP)Unit : 2 x 1000 MW Coal (2019)

GURUN (E)

JUNJUNG

AYER TAWAR

JANAMANJUNG

BKT TAREK

KAPAR

LENGGENG

OLAK LEMPIT

JIMAH

YONG PENG (E)

BKT BATU

TG BINPASIR GUDANG

500kV line500kV line but energized at 275kV

BENTONG (S)

ULU JELAI

TRANSMISSION PROJECTS REINFORCING THE GRID

TAPAH

HULU TERENGGANU

NEW PRAI

Kuala Ketil

• 500KV LINES AYER TAWAR

– TAPAH & LENGGENG –

YONG PENG(E) (2019)

• ULU JELAI HYDRO (2017)

• TG BIN U4 (2016)

• JANAMANJUNG U4 & U5

(2015)

• PRAI (2016)

• HULU TERENGGANU

(2015)

MAJOR CHALLENGES

Constraint on generation

operating reserves

Risk of water supply to power

stationsChallenging Weather

Reduced rainfall at hydro catchments

3

2 4

High unplanned generator outages

Major Challenges Faced by

Transmission Grid System

1

Gas supply issues5

North-Central FlowConstraint

6

0%

10%

20%

30%

Jan-13 Apr-13 Jul-13 Oct-13 Jan-14 Apr-14

Generator Outages 2013 - 2014

Unplanned Deration Planned

• Total generators outages

(plan and forced) averages

at 17% for last 2 years.

• Highest outage rate was

29%, on 22 Jan 2014.

• We are operating at 30%

reserve margin now.

• Reserve Margin is expected

to drop to 25%

0

1000

2000

3000

4000

Jan-13 Apr-13 Jul-13 Oct-13 Jan-14 Apr-14

MW

Generator on Forced Outages 2013-2014

• Forced Outage in system can

reach up to 3800MW on

certain days.

HIGH UNPLANNED GENERATOR OUTAGES

0

2,000

4,000

6,000

8,000

Jan-13 Apr-13 Jul-13 Oct-13 Jan-14 Apr-14

MW

900 MW

1800 MW

Yellow Warning

• 13th – 27th May 2013

• 13th Nov – 6th Dec 2013

• 20th – 24th Jan 2014

Orange Warning

•6th – 8th May 2014

•26th – 27th May 2014

Red Warning

•7th May 2014

2300 MW

Actual OR

Minimum

Operating

Reserve

OR target was reduced to 1800MW due to:-• Demand increase

• To meet schedule outage requirements

LOW GENERATION OPERATING RESERVE

237

239

241

243

245

247

249

1-Sep 1-Dec 1-Mar 1-Jun

TMGR LAKE LEVEL

'1112

current level

'1213

CHALLENGING WEATHER

135

137

139

141

143

145

147

1-Sep 1-Dec 1-Mar 1-Jun

KNYR LAKE LEVEL

'1112

Current Level

'1213

• Current lake level at Kenyir is the

lowest for the last 14 years.

• Current water inflow in the

catchments area are below

average.

• The year end target levels for

Kenyir and Temenggor revised

due to impounding work for Hulu

Trengganu project and the

anticipated El-Nino impact.

• Available water resources must

be carefully utilized to ensure full

capacity throughout the year and

2015.

• Water resources also must be

ensured available to meet the

relevant agencies minimum

discharge requirements.

WATER SUPPLY TO POWER STATIONS

• Raw water supply to power stations are

essential for the plant operation.

• All power station are listed as ‘sasaran

penting’, thus water supply will be given

top priority by water suppliers.

• Station have identified the risk and

established mitigation actions if water

supply is disrupted.

Survival rate, 3 to 10 days.

• High risk states are N. Sembilan and

Selangor.

Concentration of power stations

GAS SUPPLY

• 12 number of planned gas curtailments.

• 72 days with shortfall exceeding 400mmscfd.

• Critical shutdown planned in 2014

• June, 28 days of TTM shutdown during high demand period.

• August, 14 days of TCOT shutdown.

Kulim

Lumut

Kuala Berang

TemerlohBentong

Gua Musang

Kuala Lipis

Jerantut

Muadzam Shah

Mentakab

Kuala Pilah

Segamat

Mersing

Kluang

Kuah

Sg. Petani

Dungun

Taiping

Teluk Intan

Kuala Selangor

Kuala Kubu Baru

Banting

Gemas

Muar

Batu Pahat

Pontian Kechil

Seri Iskandar

Kampar

Melaka

Seremban

Georgetown

Kota Bharu

Kuala Terengganu

Ipoh

Kuantan

Shah Alam

Kangar

JOHOR

PAHANG

MELAKA

NEGERI SEMBILAN

SELANGOR

PERAK

KEDAH

PULAU PINANG

KELANTAN

TERENGGANU

PERLIS

WILAYAHPERSEKUTUAN

LANGKAWI

PAHLAWAN

Pasir Gudang

BERSIA

KENERING

TEMENGOR

KENYIR

SG PIAH UPPER

SG PIAH LOWER

JOR

WOH

ODAK

CHENDEROH

PERGAU

Johor Bahru

PRAI

SEGARI

CONNAUGHT BRIDGESERDANG

KAPAR

POWERTEK

PD POWER

GENTING SANYEN

TJPS

YTL

PASIR GUDANG

PAKA

YTL

Ayer Tawar

Batu GajahPapan

Kuala Kangsar

Bukit TambunJunjung

GurunBedong

Kota Setar

Chuping

Bukit Tarek

KL (N) KL (E)

Hicom G

KL (S)

Salak Tinggi

Melaka

Kg Awah

Skudai

Telok Kalong

Tanah Merah

Yong Peng (N)

ButterworthBukit Tengah

GELUGOR

JANAMANJUNG

TTPC

MELAKA

Gelang Patah

Alor Setar

7498 MW

•16,583 MWMAXIMUM DEMAND

(28/05/14)

• 7,498MWCENTRAL

AREA MAX. DEMAND

THREAT OF LOSS MAJOR TRANSMISSION CORRIDORS

Proposed network configuration during and after commissioning of JMJG U4

(Before Point A is ready)

JMJG500

BTRK500

U1 U3U2

ATWR275ATWR500

U4

L1L2

Split JMJG500 and ATWR500 with either 1400MW or 1700MW direct to

BTRK

Transmission constraint with JMJG U4

Proposed network configuration during and after commissioning of JMJG U4

(After Point A is ready)

L1L2

Point A

Split JMJG500 with either 1400MW or 1700MW direct to BTRK

Transmission constraint with JMJG U4

E-ATTEND SCHEME

The original 500kV LILO configuration has the risk of Out of Step and voltage problems for contingency n-2 BTRK-JMJG/ATWR

Incompletion of point A will further reduce system reliability where:

Propose to split JMJG and ATWR with 1400MW or 1700MW directly connected to BTRK

n-1 of the circuit with 1700MW attached will possibly trigger UFLS

Contingencies can cause overload on the parallel 275kV lines can be handled by a Special Protection Scheme called E-ATTEND with enhanced functionality – to reduce generation at JMJG/SGRI and/or trip SGRI and/or load shedding in Central area

E-ATTEND scheme recommends to include these functions: HVDC Run-back

Direct Hydro Intertrip Scheme (DHIS)

Event-based Load Shedding (at 49.5Hz)

DEMAND CONTROL IN MALAYSIAN GRID CODE

Operating Code No. 4 (OC4) governs the procedures to be

followed by the GSO and Users to facilitate Demand Control

in the event that insufficient

generating capacityis available to meet forecast or real-time

Demand

the possibility of frequency excursions

outside the limits given in the Planning

Code.

Demand Control shall include but not limited to the following actions on load or demand:

• (1) Automatic load or demand shedding;•Under frequency Load Shedding Scheme

•Under Voltage Load Shedding Scheme

• (2) Manual load or demand shedding; and• Load Shed & Restore (LSR)

•ROTA Load shedding

• (3) Reduction of load through voltage reduction;

These provisions may be used by the GSO to prevent System thermal overloads or System voltage collapse on any part of the Grid.

25

YELLOW WARNING

ORANGE WARNING

RED WARNING

NOTIFICATION FOR DEMAND CONTROL

26

12000

13000

14000

15000

16000

17000

18000

19000

1-May 2-May 3-May 4-May 5-May 6-May 7-May 8-May 9-May 10-May 11-May 12-May

MW

System Availability vs Maximum Demand

Genenator Availability Maximum Demand

JMJG U1

PLPS BLKJMAH U1

JMJG U2 JMJG U3 SRDG GT1

TJGS ST1C KLPP GT11 PDPS GT2 PKLG U2

• Multiple forced outages of generators since 2nd May 2014.• Availability reduced from 18400MW to 15900MW.

• System survived on 6th May 2014 – Imported from EGAT and Singapore.• Generation and demand unbalance very huge on 7th May 2014. GSO

resorted to load shed to protect the grid system.

GENERATION SHORTAGE TO MEET THE DEMAND

0800 0900 1000 1100 1200 1300 1400 1500 1600 1700

9:00 - 17:00

Steel Mills were

requested to stop

arcing in order to

reduce demand.

07000600

@ 0524hrs

TJGS Blk 1 (240MW)

tripped due to faulty

control valve.

7th May 2014 morning, generation availability was already low due to previous day forced outage of JMJG U2 and U3.

@ 0900hrs

started IMPORT from

Singapore & Thailand.

@ 1238hrs

PKLG U2 (145MW)

tripped due to cooling

water pump failure.

@ 1450hrs

PKLG U1 (285MW)

tripped due to cooling

water pump failure.

@ 1345hrs

RED warning was issued.

@ 1411hrs

ROTA was initiated and followed by EMLS which

amounting to a total of 470MW load interruption.

15:35 - 17:20

Restoration of supply

after PKLG U2 was

back online @1521hrs.

Red Warning was

cancelled @1720hrs

with Orange Warning

reinstated.

SEQUENCE OF EVENT ON 7th MAY 2014