Performance Report 2017

Reliability of Supply and Quality of Delivered Electricity Performance Report 2017 - 18029

Contents Introduction. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 Landsnet’s transmission system in 2017. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 Key figures. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 Statistics from operations – entire country . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 Grid disturbances, curtailments and energy consumption by region and major users. 8

Main operational disturbances to the transmission network. . . . . . . . . . . . . . . . . . 10 Security of supply. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 Index of Reliability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Average Outage Duration Index, outage minutes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Power Interruption Index . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Outage minutes in various regions of the country . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

System Minutes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Curtailments to sheddable load customers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Energy produced by backup power generators. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

Summary of the supply from the transmission net . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

14 14 17 17 19 20 20 21

Impact on security of supply. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 Grid disturbances. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 Number of faults. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28

Voltage and frequency quality . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 Frecuency . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 Voltage. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32

Appendix 1: About Landsnet. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36 Appendix 2: Definition of Indexes for Security of Supply: . . . . . . . . . . . . . . . . . . . . 37 Appendix 3: Definition of Incident Classification Scale . . . . . . . . . . . . . . . . . . . . . . 39 Appendix 4: Landsnet’s transmission lines at year-end 2017 . . . . . . . . . . . . . . . . . 40 Appendix 5: Landsnet’s substations at year-end 2017 . . . . . . . . . . . . . . . . . . . . . . . 42 Appendix 6: Indices for sheddable load and average curtailment load. . . . . . . . . 44 Appendix 7: Grid disturbances and faults. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 45 Appendix 8: Voltage quality . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 50 Appendix 9: Tables and graphs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 51

A section about economic cost due to disturbances is not included in this report due to errors in the calculation of macroeconomic costs, based on information and data from the Start Group (a workgroup focusing on operational disturbances: www.truflun.is).

3

4

Introduction

Landsnet defines five main key performance indexes, all linked to the promises Landsnet has given their stakeholders, which are customers, owners, the community and its employees. They are: Index Promise Trust

In harmony with society and the environment

Minutes of energy not supplied

Safe supply of electricity – quality and safety of the transmission system

Required return on equity

Efficient use of funds- effective operations

Work satisfaction

Positive work environment

Accident rate (H value)

Positive work environment

The Performance Report is a summary of information on the Icelandic transmission system in 2017, including statistics and a ten-year comparison. The Report assesses Landsnet’s performance with regard to the quality and secure delivery of electricity, in accordance with the obligations set out by Regulation 1048/2004 as well as the company’s internal objectives.

The number of registered grid disturbances in 2017 was similar to the preceding year. There were 711) grid disturbances in 2016, compared with 74 in 2017. The number of registered grid disturbances in substations increased in 2017, from 872) in 2016 to 893) in 2017, but the number of grid disturbances in high-voltage power lines decreased. The 10-year average for grid disturbances is 64 per year.

The total number of grid disturbances leading to curtailment of load was 39 compared with 35 in the previous year.

Energy not supplied to priority consumers due to grid disturbances was 1,495 MWh in 2017. The calculated outage duration was therefore 42.5 minutes and has not been higher since 2012. The year’s goal of 50 minutes or less was achieved.

Regulation No. 1048/2004 on the quality and secure delivery of electricity requires electricity companies to measure voltage characteristics in accordance with the ÍST EN 50160 Standard. Landsnet is obligated to take sample measurements from at least 6 points of supply, at various substations every year. Quality requirements were met in all 6 substations in 2017.

The Regulation also stipulates that delivery voltage must be within a +/-10% margin. More stringent requirements are made with regard to the supply voltage to power-intensive industries. Landsnet has defined these limits as -9% and +5%. These set limits are used when voltage quality in the 220kV system is assessed. The results of continuous measurements in the energy management system, conducted throughout the year, show that values were within these limits, with the exception of Bolungarvík and Ísafjörður.

The same regulation states that the target system frequency should be 50 Hz. The average operating frequency under normal operating conditions and measured over 10 seconds must be within the following limits:  50 Hz ± 1% Hz = 99.5% of the time  50 Hz +4/-6% = 100% of the time The average operating frequency in 2017 was within these limits 99.9962% of the time.

Internal objectives regarding the quality of frequency require that measured values be within the set limits of Hz +/- 0.2 Hz (over a ten second period) 99.5% of the time, each month. The quality of frequency in 2017 was within these limts 99.79% of the time.

1. Corrected figure: The figure was 72 in the 2016 report.

2. Corrected figure: The figure was 85 in the 2016 report.

3. Of these 89 faults; 5 faults are registered as normal responses from the security systems which are designed to respond in this manner in order to prevent a complete system failure.

5

Landsnet’s transmission system in 2017

Kópasker Bolungarvík Ísafjörður

Bakki

Breiðidalur

Lindarbrekka Húsavík Dalvík

Þeistareykir

Mjólká Vopnafjörður

Laxá

Sauðárkrókur

Keldeyri

Krafla Rangárvellir Laxárvatn Lagarfoss

Varmahlíð

Geiradalur Blanda

Seyðisfjörður

Eyvindará Glerárskógar

Neskaupstaður Hrútatunga

Grundarfjörður

Eskifjörður

Hryggstekkur

Vogaskeið

Fljótsdalur

Ólafsvík

Stuðlar

Vegamót

Fáskrúðsfjörður

Teigarhorn Vatnshamrar

Andakíll

Brennimelur Klafastaðir Akranes Hnoðraholt

Korpa Nesjavellir

Reykjanes

Höfn

Sigalda

Sog Búrfell

Geitháls Hamranes Svartsengi Þorlákshöfn

Hólar

Vatnsfell

Flúðir

Öldugata Stakkur Fitjar Rauðimelur

Sultartangi Búðarháls Hrauneyjafoss

Kolviðarhóll

A12

Transmission lines:

Hveragerði

220 kV 132 kV

Selfoss Hella Hvolsvöllur

66 kV

Prestbakki

33 kV Substations:

Rimakot

Power-intensive users:

Vestmannaeyjar

Key figures

Objectives for security of supply Index of Reliability (AS)

2017

Target

99.992%

Over 99.9905%

Average Outage Duration Index, outage minutes (SMS)

42.5

Below 50

Power Interruption Index (SRA)

0.931)

Below 0.85

One disturbance longer than 10 system minutes (see Fig 13)2)

No disturbance longer than 10 system minutes

System Minutes (KM)

The key figures show Landsnet’s objectives with regard to the security of supply as well as real figures for 2017. The objective of 99.99% reliability within the transmission system was achieved in 2017 whereas the objective of less than 0.85% power interruption was not achieved. This can mainly be attributed to human error which resulted in tripping and subsequently grid disturbances on the 18th of January. Energy not supplied to priority consumers was just over 600 MW during these grid disturbances and surpassed 10 system minutes. This meant that Landsnet could no longer achieve its goal of ‘no grid disturbances over 10 system minutes’. However, the goal for outage minutes was achieved. This can be attributed to the rapid response of the smart grid3) as well as those responsible for the operation of the electricity system.

1 Goal was not achieved. See Figure 8 and Appendix 2.

2 See Chapter on security of supply (page 19).

3 A smart grid is an electricity network based on digital technology that is used to supply electricity to consumers via two-way digital communication.

6

Statistics from operations – entire country

Transmission system total feed-in

18,512 GWh

Highest average power of feed-in (hour value)

Transmission system total load

2,350 MW

18,140 GWh

15. December at 11 o’clock

Thereof 513 GWh to secondary load

?

?

Highest average power of load (hour value)

Transmission losses

Number of grid disturbances

2,298 MW

373 GWh

74

Number of faults

Number of faults leading to curtailment

89

39

15. December at 11 o’clock

Number of grid disturbances leading to curtailment

39

Of these 89 faults, 5 are registered as normal responses from the security system, designed to prevent a complete system failure

Total energy not supplied to primary load customers due to faults

Reserve fossil fuel generation due to faults

Total energy not supplied to curtailable secondary load customers due to faults

1,495 MWh

312 MWh

16,281 MWh

7

Grid disturbances, curtailments and energy consumption by region and major users West

West Fjords

MWh

Northwest

MWh

Northeast

MWh

MWh

1

204,153

1

206,942

1

98,421

1

256,988

2

0.1

2

7.6

2

2.6

2

9.7

3

0.0

3

207.2

3

1.2

3

1.0

4

0.0

4

63.5

4

0.0

4

22.4 en ts ilm

5/5

Cu rta

en ts ilm

ilm Cu rta

Cu rta

en ts

en ts ilm Cu rta

s ce an

s ce an

s ce an

s ce an

2/3

b ur

b ur

b ur

b ur

17 / 57

st Di

st Di

st Di

st Di

2/1

Major users

ts en ilm

rta

0.0

rta

ts ilm en Cu

Cu

ts ilm en

4

es

rta

1.0

nc

Cu

3

a rb

tailm

1,330

u st

s

es

Cur

14,869,950

10 / 39

South

MWh

East

MWh

MWh

1,363,704

1

236,352

1

483,108

1

451,675

2

21.5

2

28.8

2

59.8

2

34.9

3

0.5

3

0.8

3

15,785.2

3

285.4

4

0.0

4

0.0

4

215.9

4

10.2

1

Total load in the region (primary and secondary load)

2

Total energy curtailment to secondary load due to grid disturbances

3

Total energy curtailment to primary load due to grid disturbances

4

Backup power production

Figure 1.

8

20 / 18

Suรฐurnes

MWh 1

ce

nc

Capital

n ba

a rb

s

ce

5/4

1 2

Di

u st

n ba

13 / 4

ur st Di

Di

ur st Di

ents

MWh

9

Main operational disturbances to the transmission network

There were 74 grid disturbances in 2017 and 891) faults occurred in connection with these grid disturbances (more than one fault occurred in some grid disturbances).

Number of registered grid disturbances 2017

Energy not supplied to priority consumers, due to grid disturbances, was 1.4952) MWh

3

or 42.53) outage minutes (99.992% security of supply).

Landsnet’s ‘incident classification scale’ which defines the severity of disturbances is partly based on the guidelines outlined by ENTSO-E4). The classification of disturbances

18

in Landsnet’s transmission system in 2017 is shown in Figure 2 (colour classification according to severity)5).

The main disturbances leading to sheddable load in 2017 were as follows:  18.01.2017: Unforseen activity in protection equipment in the Fjarðaál Substation

53

caused a bus coupler circuit breaker to open in Landsnet’s substation in Fljótsdalur.

Five turbines at the Fljótsdalur Station subsequently became isolated from the network and tripped due to over-frequency. This resulted in under-voltage at

Severity 0 Severity 1

Fljótsdalur and other areas of the network and the total load for Fjarðaál became

Severity 2 Severity 3

Figure 2.

under voltage. System protection equipment divided the system between Blanda and Hólar as a result of instability and extensive energy transmission, via the national network. The load in the North and East of Iceland tripped in a number of areas due to over- frequency and under- frequency. Voltage control in the East of Iceland was problematic until the first turbines came online at Fljótsdalur Station. Curtailments to primary load users reached a total of approx.848.5 MWh and system minutes reached a total of 22.66. Sheddable load customers experienced a reduction of 5.3 MWh.  08.02.2017: A fault resulted in tripping on Rimakotslína Line 1 (Hvolsvöllur – Rimakot). A transmission line tower caught fire when the cable became loose and set fire to it. Curtailments to primary load reached a total of approx. 44.2 MWh and 72.4 MWh for sheddable load users.  11.02.2017: A disturbance occurred when a line at Norðurál tripped, causing power fluctuations in the national network.

System protection equipment divided the transmission system into two islands: Southwest Hólar and Northeast Blanda.

The effects of these disturbances were widespread, affecting the Keldeyri area in the West Fjords, turbines in the Andakíl and Svartsengi stations. Other energy-intensive users in the southwest area experienced decreased load.

Curtailments to primary load were reached a total of approx. 12.4 MWh and 1.3 MWh for sheddable load users.  14.02.2017: Unforseen activity in protection equipment at Landsnet’s substation in Hamranes resulted in tripping on Ísal Line 2 (Hamranes – Ísal). Hafnarfjörður Line 1 (Hamranes – Öldugata) experienced an outage when the line came back online. Curtailments to primary load reached a total of approx. 14.3 MWh.  05.04.2017: A fault in Vestmannaeyjastreng Cable 3 (Rimakot – Westmann Islands) caused tripping on the sub-sea cable. The fault occurred on a submerged section of the cable and repairs were time consuming. An especially equipped repair ship was needed to complete the work which could only be carried out when weather and sea conditions allowed. The cable was offline for 73 days. Curtailments to primary load reached a total of approx. 8.7 MWh and 15.593.6 MWh for sheddable load users.  26.04.2017: Tripping was experienced by sheddable load users in the East of Iceland. This was caused by maintenance work which shut down Krafla Line 1 (Krafla – Rangárvellir) which also disturbed the power flow to Blanda Line 2 (Blanda – Varmahlíð). Initially, human error was thought to have disabled the smart grid transmission system but this was not the case and the system caused tripping to sheddable load users in the East. Curtailments to sheddable load users reached a total of approx. 29.9 MWh.  26.04.2017: A bus coupler tripped in Landsnet’s substation in Sigalda during maintenance work. Krafla Line 1 (Krafla – Rangárvellir) also tripped due to maintenance work elsewhere and the transmission system was therefore divided into 2 islands: Soutwest Krafla and Northeast Sigalda. Energy-intensive users in the East and Southwest parts of the country experienced curtailments to primary load (approx. 65.2 MWh).

10

1 Of these 89 faults; 5 faults are registered as normal responses from the security systems which are designed to respond in this manner in order to prevent a complete system failure.

2. Curtailments to secondary load customers are not included.

3. Curtailments to secondary load customers are not included.

4. www.entsoe.eu.

5. Appendix 3 gives further information on Landsnet’s incident classification scale.

 12.05.2017: A capacitor was due to be taken offline at Landsnet’s substation in Rangárvellir but human error meant that Rangárvellir Line 1 (Varmahlíð – Rangárvellir) went offline instead. The transmission system was divided into three islands: Southwest, North and Northeast at Rángárvöllum and Blanda and Hólar.  17.05.20171): A smelting pot leak incident at Norðurál required an emergency stop. System protection equipment divided the transmission system into two islands: Soutwest and Northeast in Sigalda and Blanda. Fluctuations in production and usage and the weak national network meant that neither of the islands were able to maintain stable operations and protection equipment on Fljótsdalur Line 2 (Fljótsdalur – Hryggstekkur) tripped. A number of operating units also subsequently tripped including Lagarfoss Line 1 (Eyvindará – Lagarfoss), Sigalda Line 4 (Sigalda – Prestbakki), Höfn Line 1 (Hólar – Höfn), as well as a number of production units located all over the country. The remaining systems short circuit power was too low to maintain the voltage due to the underground cable Stuðlar Line 1. As a result, the overvoltage damaged the surge arrestors connected to the cable at Stuðlar. Furthermore, as Fljótsdalur Line 2 was energised after the disturbance the cable appeared not to be fully disconnected from the system. As a result the tranformers in Fljótsdal tripped and the entire system from Siglada to Fljotsdal collapsed.  15.06.2017: Four turbines tripped at the Búrfell Station. The system protection equipment divided the transmission system into two islands: Southwest and Northeast at Hólar and Blanda. A shortage of spinning reserves led to curtailments to sheddable load users and energy intensive users. Curtailments to primary load reached a total of approx. 86.2 MWh and 12.6 MWh for sheddable load users.  30.06.2017: Lightning in the North of Iceland caused tripping on Kópasker Line 1 (Laxá – Kópasker). Lightening protection equipment was damaged and14 pylons were also damaged. Curtailments to primary load reached a total of 9.4 MWh.  10.08.2017: Maintenance work was carried out at Landsnet’s substation in Mjólká and island operation therefore became necessary in the West Fjord area. Human error disabled the smart grid in the West Fjords and island operations were therefore not successful. This resulted in outages in the West Fjord area. Curtailments to primary load reached a total of approx. 1.2 MWh.  22.08.2017: Mistakes were made during maintenance work which resulted in outages in the West Fjord area.

Curtailments to primary load reached a total of approx. 2.3 MWh and 11.3 MWh for sheddable load users.  05.11.2017: Tripping occured as a result of lightning strikes affecting Suðurnes Line 1 (Hamranes – Fitjar) and a transformer tripped at Öldugata. Curtailments to primary load reached a total of approx. 74.6 MWh and 0.8 MWh for sheddable load users.  05.11.2017: Tripping occured as a result of lightning strikes, affecting Rimakot Line 1 (Hvolsvöllur – Rimakot).

Curtailments to primary load reached a total of approx. 6.6 MWh and 13.7 MWh for sheddable load users.  23.11.2017: Tripping occurred on Eyvindará Line 1 (Hryggstekkur – Eyvindará) as a result of sand storms in the area.

Tripping also occurred in two transformers in Stuðlar. This resulted in the load being transferred to another transformer at Stuðlar which became overloaded and tripped a few minutes later. The Eastern Fjords subsequently experienced electricity shortages. Curtailments to primary load reached a total of approx. 21.1 MWh and 49.4 MWh for sheddable load users.  07.12.2017: Unforseen activity in protection equipment in Landsnet’s substation at Öldugata resulted in tripping on Hafnarfjörður Line 1 (Hamranes – Öldugata) when the line was supposed to come back online after maintenance work was carried out on protective equipment. Curtailments to primary load reached a total of approx 10.7 MWh and 0.5 MWh for sheddable load users.

1. This fault is not included in Figure 2. Faults within Landsnet’s system are included whereas faults in other systems are not.

11

Figure 3 shows all curtailments by date – 2017.

848.5

Curtailments to primary load users in 2017 – by date

Curtailment MWh

200 Disturbances in other systems

Disturbances in the transmissions grid

150

100

50

0 1/5/17

2/5/17

3/5/17

4/5/17

5/5/17

6/5/17 Figure 3.

12

7/5/17

8/5/17

9/5/17

10/5/17

11/5/17

12/5/17

13

Security of supply

Landsnet’s security of supply is assessed on the basis of the following indexes and in accordance with Regulation No. 1048/2004 on the Quality of Voltage and Security of Electricity. Landsnet must outline specific objectives with regard to the first three: 1) Index of Reliability (AS)

4) System Minutes (KM)

2) Average Outage Duration Index, outage minutes (SMS) 5) Power Energy Curtailment Index (SSO) 3) Power Interruption Index (SRA)

6) Power Supply Average Curtailment per Disturbance (SMA)

These indexes have been calculated for 2017 and will be discussed below, including a ten year analysis (for comparison purposes). These calculations include all grid disturbances within the transmission system.

The origin of the grid disturbance is also indicated; from Landsnet’s system or other systems (which subsequently have a knock-on effect). These may involve grid disturbances in the systems of both energy producers and energy consumers.

Index of Reliability

%

100.0000 99.9900

AS 99.9800 99.9700 99.9600 Landsnet’s system Landsnet’s system and others Landsnet’s goal

99.9500 99.9400 2008

2009

2010

2011

2012

2013

2014

2015

2016

2017

Figure 41).

Index of Reliability The Index of Reliability shows the reliability of the system as a proportion of the number of curtailed hours during the year and can be converted to percentages. Figure 4 shows the index of reliability converted into percentages as well as Landsnet’s objectives with regard to security of supply; that the reliability of supply from the transmission system should be more than 99.9905%. This is equal to 50 outage minutes per year or 0.833 curtailed hours.

The National Energy Authority now requires the measurement of ther indices. These have no specific objectives but are described in Appendix 6.

Average Outage Duration Index, outage minutes Outage minutes are one of the main indicators used by Landsnet to assess the transmission system’s security of supply.

Our goal is to ensure that outage minutes do not exceed 50 minutes per year. The total number of outage minutes in 2017 was 42.5 minutes or just within the set limit. Landsnet has only failed to stay within its set limit twice (2008 and 2012).

1. Table 5 in Appendix 9 shows the data which the graph is based on.

14

Outage minutes

Outage minutes due to operational disturbances

200 180

SMS

160 140 120 100 80 60 40 20 0 2008

2009

2010

Disturbances in other systems

2011

2012

2013

Disturbances in Landsnet’s system

2014

2015

2016

2017

Landsnet’s goal 5 year running average, Landsnet’s system

Figure 51).

Figure 5 shows the number of outage minutes due to grid disturbances in the transmission system. Curtailments due to disturbances in other systems such as production, distribution or energy intensive systems are not included in the main results. Some of these disturbances are shown in Figures 6 and 7. Energy not supplied to sheddable load customers is not included in these figures.

Outage minutes

Outage minutes - power intensive users

500

400

300

200

100

0 2008

2009

2010

Disturbances in other systems

2011

2012

2013

Disturbances in Landsnet’s system

2014

2015

2016

2017

5 year running average, Landsnet’s system

Figure 62).

Figures 6 and 7 show both outage minutes calculated for power-intensive industries and distribution systems. The total number of outages due to disturbances in the transmission system was low between 2009 and 2011 but increased in 2012 and decreased again in 2013. Outage minutes in general distribution systems have decreased significantly since 2012.

The outage minute figure is normally higher for general distribution systems than for power-intensive industries as the voltage level is higher (less units and therefore fewer disturbances) whereas the voltage supplied to general distribution systems is generally either 66KW or 33KW.

1. Table 6 i Appendix 9 shows the figures in the graph.

2. Table 7 in Appendix9 shows data related to Figures 6 and 7.

15

Outage minutes

Outage minutes – distributors

550 500 450 400 350 300 250 200 150 100 50 0 2008

2009

2010

2011

Disturbances in other systems

2012

2013

2014

2015

2016

2017

5 year running average, Landsnet’s system

Disturbances in Landsnet’s system

Figure 71).

Tables 1 and 2 show an overview of curtailments as well as the calculated duration of outages experienced by customers in 2017, due to grid disturbances in Landsnet’s transmission system. The outage time is calculated from the ratio of energy not supplied and energy sales to each customer over the year. The year 2016 is shown for comparison purposes.

2017 2016

No. of events U nsupplied energy Outage duration

No. of events Unsupplied energy Outage duration

LN Other LN syst. syst. syst.

Other syst.

LN Other LN Other syst. syst. syst. syst.

(No.) (No.)

[MWh]

[d hh:mm]

[d hh:mm]

Power-intensive users total

24

Customer, Prm load

HS Veitur, Prm load Norðurorka, Prm load

[MWh]

8 1,330.33 156.583

6

1

LN Total syst.

(No.) (No.)

0 00:47

0 00:52

9

3

67.574

5.788

0 01:07

0 01:13

2

0

[MWh]

[MWh]

68.55 80.583 7.319

0

LN syst. [d hh:mm]

Total [d hh:mm]

0 00:02

0 00:05

0 00:06

0 00:06

0

0

0

0

0 00:00

0 00:00

2

0

1.682

0

0 00:07

0 00:07

10

0

7.642

0

0 00:42

0 00:42

36

0

14.969

0

0 00:59

0 00:59

Orkuveita Reykjavíkur, Prm load

0

0

0

0

0 00:00

0 00:00

1

0

3.397

0

0 00:01

0 00:01

RARIK, Prm load

14

2 89.666

33.735

0 00:53

0 01:14

26

0 73.588

0

0 00:32

0 00:32

Orkubú Vestfjarða, Prm load

Table 1.

Customer,

Sec load

2017 2016

No. of events U nsupplied energy Outage duration

No. of events Unsupplied energy Outage duration

LN Other LN syst. syst. syst.

Other syst.

LN Other LN Other syst. syst. syst. syst.

(No.) (No.)

[MWh]

[MWh]

[d hh:mm]

[d hh:mm]

LN Total syst.

[MWh]

[MWh]

[d hh:mm]

Total [d hh:mm]

HS Veitur, Sec load

8

1 1,5786.48

10.523

25 05:59

25 06:53

3

0

7.519

0

0 00:34

0 00:34

Norðurorka, Sec load

0

0

0

0

0 00:00

0 00:00

1

0

0.071

0

0 00:02

0 00:02

Orkubú Vestfjarða, Sec load

11

1

207.201

1.26

0 16:25

0 16:31

49

0 682.159

0

2 10:15

2 10:15

Orkuveita Reykjavíkur, Sec load

0

0

0

0

0 00:00

0 00:00

0

0

0

0

0 00:00

0 00:00

RARIK, Sec load

11

2

286.555 48.379

0 09:27

0 11:03

0

1

35.09

0.827

0 01:40

0 01:42

Table 2.

1. Table 7 in Appendix 9 shows data related to Figures 6 and 7.

16

(No.) (No.)

LN syst.

Power Interruption Index The Power Interruption Index for the transmission system was 0.93 in 2017. Landsnet’s goal of 0.85 was therefore not achieved. These interruptions can be attributed to a number of disturbances that led to curtailments (disturbances on the 18th of January, 17th of May and 15th of June). Figure 8 shows the transmission system’s ‘Power Interruption Index’ over the past 10 years.

Power Interruption Index

MW/MWyear

2.5

2.0

SRA 1.5

1.0

0.5

0.0 2008

2009

2010

Disturbances in other systems

2011

2012

2013

Disturbances in Landsnet’s system

2014

2015

2016

2017

Landsnet’s goal

Figure 81).

Outage minutes in various regions of the country The security of supply to general consumers varies according to region. Outage minutes are therefore calculated for each area of the country and are based on the load in each region. The outage minutes shown are therefore the outage minutes experienced by each separate region. The Reykjavík area experienced the least outage minutes or an average of 2 minutes per year, over the last five years. The Suðurnes area has experienced 20 outage minutes per year, over the last five years. The South, West, Northwest, Northeast and finally the East of Iceland have experienced an average of 40-70 outage minutes in the last five years. The security of supply is weakest in the West Fjords of Iceland with an average of 590 outage minutes per year, in the last five years. However, there has been a measurable decrease in outage minutes in this region as a result of the back-up power station located in Bolungarvík and the smart grid in the West Fjords area which generally responds within 90 seconds of a disturbance. The outage minutes in this region subsequently decreased in 2017 to 10% of the average outage minutes experienced every five years and the total is now in line with other regions.

Figures 9 and 10 show the number of outage minutes experienced in 2017 (by region) as well as the five year average.

The number of outage minutes is variable according to region and year and one large-scale disturbance can significantly alter these results.

Outage minutes due to sheddable load were high in the south in 2017. This can be attributed to a fault in Westmann Island Line 3 which lasted for 73 days and had a negative impact on domestic heating utilities on the island as oil is used to supply the system in the absence of electricity. This could have created extensive problems for the island’s main industries, such as fishmeal production but the fish catch was low during this period. Outage minutes were high in the Suðurnes area in 2017 as a result of curtailments to energy- intensive industry load. The companies affected included United Silicon, Verne and Advania.

1. Table 8 in Appendix 9 shows the figures in the graph

17

Outage minutes

Outage minutes – general primary load by region

100 Average 2013-2017

90

2017

589

80 70 60 50 40 30 20 10 0 Capital

Suðurnes

South

West

West Fjords

Northwest Northeast

East

Total general primary load

Figure 91).

Outage minutes

Outage minutes – total primary load by region

600 Average 2013-2017

500

2017

400 300 200 100 0

Capital

Suðurnes

South

West

West Fjords

Northwest

Northeast

East

Total primary load

Figure 102).

Outage minutes by cause

Number

200 Weather

180

Technical fault

Human error

Other

160 140 120 100 80 60 40 20 0 2008

2009

2010

2011

2012

2013

2014

2015

2016

2017

Figure 113).

Figure 11 shows the division of outage minutes by cause. The unusually high figure in 2017 can be attributed to human error and reflects the complexity of operating the transmission system. The development of protective systems has been rapid, with the aim of improving the management of a heavily loaded system. The national network is weak, causing instability and fluctuations between regions. The most serious disturbances in this category occurred on the 18th of January, 14th of February, 26th of April and 15th of June this year. Each incident was reviewed and the necessary improvements were implemented.

Figure 12 shows how many curtailment cases occured within determined time limits in 2017. The first column shows the number of curtailments lasting between 0–3 minutes; the next column shows the number of curtailments lasting between 3–30 minutes, etc. Curtailment cases are categorised according to units e.g. lines and cables, substations and system 1. Table 9 in Appendix 9 shows the data used for the graph.

2. Table 10 in Appendix 9 shows the data used for the graph.

3. Table 11 in Appendix 9 shows the data used for the graph.

18

Number of curtailment events within set time limits 2017

Number 60 50 40 30 20 10 0

0-3 min

3-30 min

30-60 min

Substations

1-12 hours

12-24 hours

Lines and Cables

1-7 days

More

System failures

Figure 121).

failures. System failures include disturbances that are generally classified as system disturbances and not specific unit failures such as disturbances experienced as a result of actions within the smart grid and control centre. The disturbances that fall within this category are actually a defense response within the system in order to avoid an absolute system failure.

System Minutes The System Minutes Index shows how serious each case is. The severity of each case is categorised as follows: Category 0, instances are < 1 min

Category 2, instances are ≥ 10 and <100 min.

Category 1, instances are ≥ 1 and < 10 min

Category 3, instances are ≥ 100 and < 1000 min.

Number 60

Categorisation of disturbances 2008-2017 by outage minutes

50 40 30 20 10 0 2008

2009

2010

2011

Category 0

2012

2013

Category 1 Figure 132).

2014

2015

Category 2

2016

2017

Category 3

Landsnet’s goal is to ensure that no grid disturbance lasts for more than 10 system minutes. This goal has been achieved five times since 2008. One disturbance lasted more than 10 minutes in 2017. The disturbance occurred on the 18th of January and is described on page 10. Figure13 shows the division of system minutes into the above categories, over a period of 10 years.

1. Table 12 in Appendix 9 shows the data used for the graph.

2. Table 13 in Appendix 9 shows the data used for the graph.

19

Curtailments to sheddable load customers Curtailable transmission refers to the permitted curtailment of electricity due to instances outlined in Article 5.1 of Grid Code B5: Terms for Curtailable Transmission.

Curtailments of secondary load have increased significantly over the last years due to the increased load on the transmission system. These curtailments are either enforced as a result of a request from Landsnetâ&#x20AC;&#x2122;s control centre or automatically initiated with circuit breakers. Landsnet has set up the automatic tripping of secondary load to increase operational security and to improve the utilisation of the transmission system. Curtailments of secondary load, due to grid disturbances, increased by 98% between 2013 and 2015 but decreased in 2016. Extensive curtailments were necessary in 2017 and can mostly be attributed to an outage on Vestmannaeyjastreng Line 3 which took over two months to repair.

The estimated curtailment of sheddable load was 16,281 MWh which corresponds to 462 system minutes.The system minutes of the transmission system would have increased by the same amount in 2017 if the agreement on secondary load did not exist.

Figure 14 shows the curtailment of secondary load for the last 5 years, due to disturbances in the transmission system.

Curtailments to sheddable load customers in Landsnetâ&#x20AC;&#x2122;s system 2013-2017

MWh

18000 16281 16000 14000 12000 10000 8000 6000 4667 4000 2000

1212

1989 725

0 2013

2014

2015

2016

2017

Figure 14.

Energy produced by backup power generators Distribution utilities have installed backup power generators to produce electricity when disturbances affect the supply.

Landsnet has access to these power stations which are used to feed primary load during disturbances, and during any system maintenance. Starting up these power generators can take some time and the curtailment of primary load can therefore occur during disturbances, until the back-up energy is made available. Backup power generators accounted for 312 MWh in 2017 which is a decrease from the previous year.

If Landsnet did not have access to these backup power stations, the system minutes for priority consumers would have been 51 minutes, instead of 42.5 minutes (an increase of 9 minutes).

Figure 15 shows electricity generation by backup power stations due to disturbances in the transmission system over the last 5 years.

20

Backup station energy usage due to disturbances in Landsnetâ&#x20AC;&#x2122;s system 2013-2017

MWh

3000

2061 2000

878

1000 198

368

312

2016

2017

0 2013

2014

2015 Figure 15.

Summary of the supply from the transmission net The increased load in the transmission system and a rise in grid disturbances have led to an increase in the use of back up generators/stations. Curtailments on sheddable load have also increased. There are numerous examples of how smart grid solutions and the rapid response of Landsnetâ&#x20AC;&#x2122;s control centre have minimised or prevented curtailments to priority consumers. Landsnet has achieved its delivery targets in the last few years, despite the high number of disturbances.

Table 3 and Figure 16 shows the total amount of back up power produced and converted to system minutes. The influence of these factors on the security of supply is evident and highlights the importance of backup power sources and permitted curtailments. Otherwise, the total number of system minutes would be 519 instead of the 42.5 recorded in 2017.

Outages, curtailments to sheddable load users and back-up energy use

MWh

SMSin mins

Outages-priority consumers

1,495

42.5

Outages due to grid disturbances in other systems

196

5.6

Back-up energy use due to grid disturbances

312

8.9

16,281

462.2

18,285

519.1

Curtailments to sheddable load Total (outages, curtailments & back-up energy use) Table 3.

21

Curtailments to primary load users due to disturbances in Landsnet’s system 2013-2017

MWh

1600

1495

1400 1200 1000

600

856

748

800 595

400 170

200 0

2013

2014

2015

2016

2017

Figure 16.

MWh

Curtailments due to other system disturbances 2013-2017

400

365

358 350 300 250

196

200 150

149

148

100 50 0 2013

2014

2015

2016

2017

Figure 17.

Summary of security of supply in transmission system – disturbances 2013-2017

Outage minutes

600 500 400 300 200 100 0

2013

2014

2015

Curtailment to primary load Production backup stations Landsnet’s goal Figure 18.

22

2016

2017

Curtailment due to other systems Curtailment to secondary load customers

23

Impact on security of supply

The underlying cause of many grid disturbances in Iceland’s transmission system can be attributed to the limited capacity of the national network. The 132 kV line from Brennimelur to Hvalfjörður, across the north and east of the country and southwards to Sigalda was constructed almost forty years ago. A summary has been compiled of the number of incidents caused by restrictions to the national network over the last 10 years. Grid disturbances to the Vestur Line, from Hrútatunga to Mjólká, are not included in these figures as the line is unnafected by power fluctuations and stability issues between regions.

Table 4 shows a summary of all curtailments due to faults that can be directly traced to the state of the national network.

These faults would probably not have occurred in a stronger transmission system. These faults are accompanied by a higher percentage of outages than other disturbances to the transmission system as they are often more widespread1).

Curtailments as a result of these faults are often more extensive than those enforced in other grid disturbances and therefore have a greater effect on energy consumers.

A review of individual years shows that a large proportion of these curtailments can be traced to the restrictions of the national network. An estimated 80% of curtailments could be traced to these restrictions in 2014 and 50% in 2008 and 2009. Nine faults were experienced this year, due to the weak national network which subsequently led to 30% of all curtailments to primary load users. Faults caused by the weak national network were five times more likely to cause curtailment within the system in 2017 than other faults.

Year

Number faults

Curtailments

Lost sales

All Other Weak All Weak All Weak faults grid faults grid faults grid LN LN LN Number Number Number MWh MWh MWh MWh

2008

130 114 16 2,242 1,316 0 0

2009

60 56 4 1,824 920 0 0

2010

55 48 7 843 227 0 0

2011

64 63 1 842 0 0 0

2012

108 98 10 5,809 439 0 0

2013

79 70

9 744 167 1,213 314

2014

103

80

23 1,106 840 2,359

94

2015

139

119

20 1,221 283 4,947

64

2016

106 101

5 317 109 729

2017

108

9 1,691

Total

952

99 848

511 16,341

104 16,639 4,812 25,589

7 216

695

Percentage, % 10.9 28.9 2.7 Table 4.

Faults and curtailments that can be traced directly to the weak national network have been assessed alongside the total number of faults and curtailments within the system each year. There have been 950 faults in Landsnet’s transmission system over the last ten years, including faults as a result of grid disturbances in other systems or an average of 95 faults per year. A total of 104 of these faults can be traced to the weak national network.

Figure 19 shows the the percentage of faults traced to the weak national network as well as the overall number of faults and curtailments in the system. The results show that on average, 11% of these faults can be traced to the weak national network as well as 29% of the total number of curtailments. However, these percentages vary between years and have reached up to 80%.

1. Approx. 29% of curtailments to users during this time period can be attributed to these faults as well as 3% of reduced sales to sheddable load users.

24

%

Percentage of faults and curtailments due to weak 132 kV system

100

Number of faults due to weak 132 kV system Curtailment of energy due to weak 132 kV system

90 80 70 60 50 40 30 20 10 0 2008

2009

2010

2011

2012

2013

2014

2015

2016

2017

Figure 19.

25

26

Grid disturbances

A grid disturbance is an unexpected event that can cause automatic or manual disconnection of a unit in the transmission system or in the event of a failed reconnection after a malfunction. Each grid disturbance, therefore, may involve more than one fault. This means that the number of faults will always be equal to or greater than the number of grid disturbances.

Each fault is classified when a grid disturbance is registered e.g. according to type, the unit that caused the failure and the cause. There was an increase in grid disturbances in 2016 and 2017 or a total of 74 disturbances involving 891) faults. The average number of grid disturbances over the last 10 years (compared with a transmission system similar in size) was 64 with an average of 79 faults.

Figure 20 shows the number of grid disturbances in the transmission system over the past 10 years. Disturbances are categorised according to location, i.e. in substations, on lines/cables or whether system faults are involved. Figure 21 shows the division of grid disturbances by cause.

A system disturbance is defined as follows: A forced outage which results from system effects or conditions and is not caused by an event directly associated with the component or unit being reported. If, e.g. voltage fluctuations or deviations in frequency cause units to disconnect from operation or if consumers are disconnected, then the event is a system disturbance. However, Non-selective tripping at customers for these reasons are, however, not considered system malfunctions.

Number of operational disturbances

Number

100 90 80 70 60 50 40 30 20 10 0 2008

2009

2010

2011

2012

Substations

2013

2014

Lines and cables

2015

2016

2017

2016

2017

System faults

Figure 202).

Number of disturbances â&#x20AC;&#x201C; by cause

Number

100 90 80 70 60 50 40 30 20 10 0 2008

2009

2010 Weather

2011

2012

2013

Technical fault

2014 Human error

2015

Other

Figure 213).

1. Of these 89 faults; 5 faults are registered as normal responses from the security systems which are designed to respond in this manner in order to prevent a complete system failure.

2. Table 14 in Appendix 9 shows the data used for the graph.

3. Table 15 in Appendix 9 shows the data used for the graph.

27

Number of faults The total number of faults in 2017 was 891) compared with 84 in the previous year. The following figures show the number of faults over the last 10 years. A comparison is shown according to the different categories.

Number of disturbances in the transmission system

Number

140 120 100 80 60 40 20 0 2008

2009

2010

2011

Substations

2012

2013

2014

Lines and cables

2015

2016

2017

System faults

Figure 222).

Average number

Number of faults in the transmission system by month â&#x20AC;&#x201C; average 10 year total

14

2008-2017 12 10 8 6 4 2 0 Jan

Feb

Mar

Apr

May

Substations

June

July

Aug

Lines and cables

Sep

Oct

Nov

Dec

System faults

Figure 233).

28

1. Of these 89 faults; 5 faults are registered as normal responses from the security systems which are designed to respond in this manner in order to prevent a complete system failure.

2. Table 16 in Appendix 9 shows the data used for the graph.

3. Table 17 in Appendix 9 shows the data used for the graph.

Number of faults in transmission system – by voltage

Number

140 120 100 80 60 40 20 0 2008

2009

2010

2011

220 kV

132 kV

2012

2013

66/33 kV

2014 11 kV

2015

2016

2017

Minus voltage

Figure 241).

Categorisation of faults – by duration

Number

35 Average 2008-2017

2017

30 25 20 15 10 5 0 0-3 min

3-30 min

30-60 min

1-12 hours

12-24 hours

1-7 days

More

Figure 252).

Number

Number of faults in the transmission system 2017 – by month

16 14 12 10 8 6 4 2 0 Jan

Feb

Mar

Apr

May

Substations

June

July

Aug

Lines and cables

Sep

Oct

Nov

Dec

System faults

Figure 263).

1. Table 18 in Appendix 9 shows the data used for the graph.

2. Table 19 in Appendix 9 shows the data used for the graph.

3. Table 20 in Appendix 9 shows the data used for the graph.

29

Number of faults in the transmission system â&#x20AC;&#x201C; by cause

Number

140 120 100 80 60 40 20 0 2008

2009

2010 Weather

2011

2012

2013

Technical fault

2014

2015

Human error

2016

2017

Other

Figure 271).

Number of faults â&#x20AC;&#x201C; by unit No unit Cables Lines Station, other Thyristor Surge protectors Busbars Circuit breaker Disconnector Control and support systems Transformer

Average 2008-2017

2017

Capacitor 0

10

20

30

40

50 Number

Figure 282).

1. Table 21 in Appendix 9 shows the data used for the graph.

2. Table 22 in Appendix 9 shows the data used for the graph.

30

31

Voltage and frequency quality

Frequency quality 2017 - ratio of measured values

%

40 35 30 25 20 15 10 5 0 49.00

49.20

49.40

49.60

49.80

50.00

50.20

50.40

50.60

50.80

51.00

Hz Figure 29.

Frequency The Regulation on the Quality of Voltage and Security of Electricity permit variations in frequency not exceeding 1% above and below 50 Hz under normal operating conditions.

The mean value of fundamental, measured over 10 seconds must be within the following limits: 50 Hz ± 1 % (i.e. 49.5 – 50.5 Hz) 99.5% of the time 50 Hz +4 / -6 % (i.e. 47 – 52 Hz) 100% of the time Landsnet monitors frequency and voltage quality in the entire transmission system, throughout the year in the company’s energy management system. The system automatically registers frequency values every two seconds. Results for measurements at Geitháls have been processed (Figure 29). The number of measurement values is 3,146,398, the average frequency value is 50.00016 Hz and the standard deviation of measurement values is 0.04427.

Total frequency excursion exceeding the 1% limit in 2017: >50.5 Hz = 14.83 min (0.00283 % of the time) <49.5 Hz min (0.00102 % of the time) Frequency was therefore within the set limit 99.99615% of the time.

Landsnet has set internal goals on frequency quality: To ensure that 99.5% of measurement values are within the limit (50 Hz +/- 0.2 Hz ) every month. A 10-second average value is used.

Frequencies were within these limits for eleven months of the year 2017 with the exception of July. The yearly average was 99.78757%.

Voltage The Regulation on the Quality of Voltage and Security of Electricity No. 1048/2004 stipulates that electricity companies must measure voltage characteristics in accordance with the ÍST EN 50160 standard. Landsnet is under obligation to conduct measurements at 6 delivery points each year. Specific measurements were taken in 2017, using precise quality measuring instruments, at the following delivery points: Akranes: 66 kV Eskifjörður: 66 kV Geiradalur: 132 kV Hamranes: 132 kV Hveragerð: 66 kV Korpa: 132 kV

32

Measurements were taken continuously for at least one week at each location and the relevant quality requirements were fulfilled in each case. Figures 40 to 47 show the voltage values for delivery points in the transmission system. An examination is made of the distribution of 5-minute values in all cases. The measurements are taken from the energy management system.

According to the Regulation, voltage variations must be kept within the permissible limit ±10%. More stringent requirements are made to delivery voltage for power-intensive industries. In these cases, the limits of delivery voltage have been defined as +5%/-9%. These limits are therefore taken into account when the 220kV system is assessed. The results show that values were within the set limits in nearly all cases with the exception of the west of Iceland (Bolungarvík and Ísafjörður). These deviations can all be traced to lack of voltage due to faults or maintenance at the delivery point in question. The 66 kw system in the West Fjords is operated slightly below these limits, in cooperation with Orkubú Vestfjarða.

33

34

35

Appendix 1: About Landsnet

We are a responsible and progressive service company with a powerful team spirit and high level of community awareness. We strive to be at the forefront of the global energy industry.

Role Secure, uninterruptible electricity is one of the pillars of modern society and our role is to ensure the cost-efficient development and operation of the grid and a secure and uninterrupted electricity supply at any given time, within the electricity system.

Our future vision An electrified future, in line with society, is a key principle at the core of our future vision.

Modern societies are increasingly reliant on the secure supply of electricity. We are committed to ensuring the secure supply of electricity for the future and to maintaining a balance between generation and consumption.

We want to achieve a broad consensus in our future endeavours, are committed to considering the needs of society at any given time and to showing responsibility in environmental matters. We are also committed to promoting a healthy market environment within the electricity market and to the efficient use of funds.

Values Our values are responsibility, cooperation and respect and we incorporate these principles, both internally and externally.

They shape our corporate culture, approach and behaviour, supporting professionalism and effective decision-making.

Policy pledges Our policy is based on six key pledges to society. These include the secure supply of electricity, a high quality service and secure transmission system for the future, operations in harmony with society and the environment, efficient operations, informed debate, and targeted management and organisation.

Our promises include: • Secure electricity supply- a high-quality and secure transmission system for the future • In harmony with society and the environment • Efficient use of funds- effective operations • Clear image • Strategic management and organisation • Positive work environment

Organisational chart

President & CEO

Corporate Services & Communications

36

Finance

Technology & Developement

Stakeholder’s Forum

System Operations

Constructions & Grid Services

Appendix 2: Definition of Indexes for Security of Supply

Power Interruption Index This index is the ratio of the aggregate power curtailment and highest load on the system. The following equation applies to this index:

Where: Pi:

Power curtailment in curtailment i [MW]

PMax:

Maximum total feed-in of the year into the transmission system / distribution system [MW].

Average Outage Duration Index-Outage Minutes This index assesses how long the curtailment has prevailed based on energy curtailment and total energy delivery. The following equation applies to this index:

Where: Ei:

Energy curtailment in disturbance i [MWh].

ETotal:

Total energy delivery to customers [MWh].

System Minutes Index that indicates the severity of each case of curtailed energy delivery. The following equation applies to this index:

Where: E:

Energy curtailment in disturbance [MWh].

PMax:

Maximum load on the system, transmission system / distribution system [MW].

37

Power Energy Curtailment Index This index is the ratio of energy curtailment if the load had been unchanged over the whole curtailment period and the total load on the system. The following equation applies to this index:

MW hour / MW year

Where: Pi: Power curtailment MW, in curtailment i.

Ti: Duration of curtailment, hours.

PMax: Maximum load (one hour average) of feed-in, MW.

Power Supply Average Curtailment per Disturbance This index is an indication of the average curtailment of each disturbance. The following equation applies to this index:

MW / disturbance

Where: Pi: Load curtailment, MW, in disturbance i.

N: No. of disturbances.

Index of Reliability Index that shows the reliability of the system as a proportion of the number of hours during the year.

Where: Duration of outage is defined according to the Average Outage Duration Index, outage minutes.

38

Appendix 3: Definition of Incident Classification Scale The highest severity is read from # 1 and down to # 18 according to ENTSO-E1).

Transmission system incident classification scale (partially modelled on ENTSO-E Incident classification scale) Green (Scale 0) Anomaly

Yellow (Scale 1) Noteworthy incident

Incidents Classification

#9 L1

Outage of 5-15% of total power (ex. 110-330 MW)

LNFD0

Outage of < 2.5% of distribution utilities’ primary load (ex. < 9 MW)

LNFD1

Outage of 2.5 - 7.5% of distribution utilities’ primary load (ex. 9-27 MW)

LNFS0

Outage of < 5% of load to major users (ex. 80 MW)

LNFS1

Outage of 5 - 15% of load to major users (ex. 80-240 MW)

#18 T0

Outages or disconnections of units in the 220 kV system, without loss of transmission capabilities

#11 T1

Outage or disconnections of units affecting important areas (island operations, main 132 kV line outage)

#19 G0

Outage of generation which is <= the biggest generating unit in the system (each generator in Kárahnjúkar is 115MW)

#12 G1

Outage of generation which is > than the largest generating unit in the system (each generator in Kárahnjúkar is 115MW)

#21 OR0

Lack of >20% of defined reserves for 15-30 minutes

#15 OR1

Lack of >20% of defined reserves

#16 LT1

State estimator or substation out of commission for over 30 minutes

#14 OV1

Voltage standards continuously outside 0.9-1.1 p.u. for > 15 minutes at 110-300 kV

#10 F1

Δf is 0.25-0.5 Hz continuously for 20 minutes or Δf 0.5-1.2 Hz/without warning Δf >1.2 Hz for 10 minutes

#20 OV0

Voltage standards continuously outside 0.9-1.1 p.u. for 5 - 15 minutes at 110-300 kV

#17 F0

Continuous Δf 0.1-0.25 Hz for 20 minutes or continuous Δf 0.25-1.2 Hz for 10 minutes

Red (Scale 2) Extensive incident

Black (Scale 3) Major incident

#2 L2

Outage of 15-70% of total load (ex. 330-1500 MW)

#1 OB3

LNÁL2

>25% curtailment to one or more aluminum plants for an hour or more

>25% curtailment to LN- one or more aluminium ÁL3 plants for two hours or more

LNFD2

Outage of 7.5-35% of distribution utilities’ primary load (ex. 27-126 MW)

LNFD3

Outage of >7.5% of distribution utilities’ primary load for >5 hours (ex. > 27MW)

LNFS2

Outage of 15-70% of load to major users (ex. 240-1120 MW)

LNFS3

Outage of >15% of load to major users for >5 hours (ex. >240 MW)

#5 G2

Outage of generation which is >= the largest power plant in the system (Kárahnjúkar is 690 MW)

#8 LT2

EMS/Scada out for over 30 minutes

#3 F2

Continuous Δf 0.5-1.2 Hz/without warning Δf >1.2 Hz for 20 minutes

Total system failure

Scale 1. www.entsoe.eu.

39

1977 / 2006

BH1 2014 Búðarháls-HR1 (Langalda)

Búrfell Line 1

BU1 1969 Búrfell-Írafoss

Búrfell Line 2

BU2 1973 Búrfell-Kolviðarhóll

Búrfell Line 3 (partly built for 400 kV)

BU3 1992/1998 Búrfell-Hamranes

Fljótsdalur Line 3 (built for 400 kV)

FL3 2007

Fljótsdalur-Reyðarfjörður

49

Fljótsdalur Line 4 (built for 400 kV)

FL4 2007 Fljótsdalur-Reyðarfjörður

53

Geitháls-Brennimelur

58.6 5.6 60.8 86 119.07 0.07

Hamranes Line 1

HN1 1969 Geitháls-Hamranes

15.1

Hamranes Line 2

HN2 1969 Geitháls-Hamranes

15.1

Hrauneyjafoss Line 1

HR1 1982 Hrauneyjafoss-Sultartangi

19.5

Ísal Line 1

IS1 1969 Hamranes-Ísal

2.4

Ísal Line 2

IS2 1969 Hamranes-Ísal

2.4

Járnblendi Line 1

JA1 1978 Brennimelur-Járnblendivk

4.5 17.3

Kolviðarhóll Line 1

KH1 1973 Kolviðarhóll-Geitháls

Krafla Line 4

KR4 2017 Krafla-Þeistareykir

33

Norðurál Line 1

NA1 1998 Brennimelur-Norðurál

4.2

Norðurál Line 2

NA2 1998 Brennimelur-Norðurál

4

Sigalda Line 2

SI2 1982 Sigalda-Hrauneyjafoss

8.6 36.8

Sigalda Line 3

SI3 1975/2015 Sigalda-Búrfell

Sog Line 3

SO3 1969 Írafoss-Geitháls

35.8

Sultartangi Line 1

SU1 1982 Sultartangi-Brennimelur

121.6

Sultartangi Line 2

SU2 1999 Sultartangi-Búrfell

12.5

Sultartangi Line 3 (built for 400 kV)

SU3 2006 Sultartangi-Brennimelur

119

Vatnsfell Line 1

VF1 2001 Vatnsfell-Sigalda

5.8

Þeistareykir Line 1

TR1 2017 Þeistareykir-Bakki

40

Of which undergr. [km]

BR1

Búðarháls Line 1

Length [km]

First year in service

Brennimelur Line 1

Name

220

Voltage [kV]

KKS code

Connected substations

Appendix 4: Landsnet’s transmission lines at year-end 2017

28.3 Total 220 kV

917.9

0.07

132

Blanda Line 1

BL1 1977/1991 Blanda-Laxárvatn

32.7

Blanda Line 2

BL2 1977/1991 Blanda-Varmahlíð

32.4

Eyvindará Line 1

EY1 1977 Hryggstekkur-Eyvindará

27.5

Fitjar Line 1

MF1 1991 Rauðimelur-Fitjar

6.8

Fitjar Line 2

FI2 2015 Fitjar-Stakkur

8.5 8.5

Fljótsdalur Line 2

FL2 1978 Fljótsdalur-Hryggstekkur

Geiradalur Line 1

GE1 1980 Glerárskógar-Geiradalur

46.7

Glerárskógar Line 1

GL1 1983 Hrútatunga-Glerárskógar

33.5

Hafnarfjörður Line 1

HF1 1989 Hamranes-Öldugata

Höfn Line 1

HA1 1987/2014 Hólar-Höfn

Hnoðraholt Line 1

AD7 1990 Hamranes-Hnoðraholt

9.7 2

25 7

4 4 7 1.5

Hólar Line 1

HO1 1981 Teigarhorn-Hólar

75.1

Hrútatunga Line 1

HT1 1976 Vatnshamrar-Hrútatunga

77.1

Korpa Line 1

KO1 1974 Geitháls-Korpa

Krafla Line 1

KR1 1977 Krafla-Rangárvellir

Krafla Line 2

KR2 1978 Krafla-Fljótsdalur

Laxárvatn Line 1

LV1 1976 Hrútatunga-Laxárvatn

72.7

Mjólká Line 1

MJ1 1981 Geiradalur-Mjólká

80.8

6 0.3 82.1 123.2 0.1

Nesjavellir Line 1

NE1 1998 Nesjavellir-Korpa

32 16

Nesjavellir Line 2

NE2 2010 Nesjavellir-Geitháls

25 25

Prestbakki Line 1

PB1 1984 Hólar-Prestbakki

171.4

Rangárvellir Line 1

RA1 1974 Rangárvellir-Varmahlíð

87.5

Rangárvellir Line 2

RA2 2009 Rangárvellir-Krossanes

4.5 4.4

Rauðimelur Line 1

RM1 2006 Reykjanes-Rauðimelur

15

Rauðavatn Line 1

RV1 1953 Geitháls-A12

Sigalda Line 4

SI4 1984 Sigalda-Prestbakki

78.1

Sog Line 2

SO2 1953 Írafoss-Geitháls

44.4

3 1

2005

Of which undergr. [km]

SR1

Length [km]

First year in service

Stuðlar Line 1

Connected substations

KKS code

Name

Voltage [kV]

Hryggstekkur-Stuðlar

16

16

Suðurnes Line 1

SN1 1991 Hamranes-Fitjar

Svartsengi Line 1

SM1 1991 Svartsengi-Rauðimelur

4.9

Teigarhorn Line 1

TE1 1981 Hryggstekkur-Teigarhorn

49.7

Vatnshamrar Line 1

VA1 1977 Vatnshamrar-Brennimelur

30.7 0.1

20.2

Total 132 kV 66

1333.2

85.8

Akranes Line 1

AK1 1996 Brennimelur-Akranes

18.5 18.5

Andakíll Line 1

AN1 1966 Andakílsvirkjun-Akranes

Bolungarvík Line 1

BV1 1979/2014 Breiðidalur-Bolungarvík

17.1 1

Bolungarvík Line 2

BV2 2010/2014 Ísafjörður-Bolungarvík

15.3 15.3 36.4 0.8

34.85 1.3

Breiðidalur Line 1

BD1 1975 Mjólká-Breiðidalur

Dalvík Line 1

DA1 1982 Rangárvellir-Dalvík

39 0.1

Eskifjörður Line 1

ES1 2001 Eyvindará-Eskifjörður

29.1 0.3

Fáskrúðsfjörður Line 1

FA1 1989 Stuðlar-Fáskrúðsfjörður

16.8

Flúðir Line 1

FU1 1978 Búrfell-Flúðir

27.4 0.6

Grundarfjörður Line 1

GF1 1985 Vogaskeið-Grundarfjörður

35.4

Hella Line 1

HE1 1995 Flúðir-Hella

34.4 1.7

Hella Line 2

HE2 2015 Hella-Hvolsvöllur

Hveragerði Line 1

HG1 1982 Ljósafoss-Hveragerði

15.4 0.1

Hvolsvöllur Line 1

HV1 1972 Búrfell-Hvolsvöllur

45.1 0.25

Ísafjörður Line 1

IF1 1959/2014 Breiðidalur-Ísafjörður

Kópasker Line 1

KS1 1983 Laxá-Kópasker

Lagarfoss Line 1

LF1 1971 Lagarfoss-Eyvindará

Laxá Line 1

LA1 1953 Laxá-Rangárvellir

Ljósafoss Line 1

LJ1 2002 Ljósafoss-Írafoss

0.6 0.6

Neskaupstaður Line 1

NK1 1985 Eskifjörður-Neskaupstaður

18.2 1.9

Ólafsvík Line 1

OL1 1978 Vegamót-Ólafsvík

48.8

Rimakot Line 1

RI1 1988 Hvolsvöllur-Rimakot

22.2 0.1

Sauðárkrókur Line 1

SA1 1974 Varmahlíð-Sauðárkrókur

21.8

Selfoss Line 1

SE1 1981 Ljósafoss-Selfoss

20.3 2.7

Selfoss Line 2

SE2 1947 Selfoss-Hella

32 0.7

Selfoss Line 3

SE3 2016 Selfoss-Þorlákshöfn

28 28

Seyðisfjörður Line 1

SF1 1996 Eyvindará-Seyðisfjörður

19.8

13 13

13 3 83.3 0.1 28 6 58.4 0.7

Steingrímsstöð Line 1

ST1 2003 Steingrímsstöð-Ljósafoss

3.4 1

Stuðlar Line 2

SR2 1983 Stuðlar-Eskifjörður

18.2 2.4

Tálknafjörður Line 1

TA1 1985 Mjólká-Keldeyri

45.1

Vatnshamrar Line 2

VA2 1974 Andakílsvirkjun-Vatnshamrar

Vegamót Line 1

VE1 1974 Vatnshamrar-Vegamót

Vestmannaeyjar Line 3 (sub-sea cable)

VM3 2013 Vestmannaeyjar-Rimakot

Vogaskeið Line 1

VS1 1974 Vegamót-Vogaskeið

2 0.2 63.8 16 16 24.8

Vopnafjörður Line 1

VP1 1980 Lagarfoss-Vopnafjörður

Þeistareykir Line 2

TR2 2013 Þeistareykir-KS1 (Höfuðreiðarmúli)

Þorlákshöfn Line 1

TO1 1991 Hveragerði-Þorlákhöfn

Húsavíkur Line 1

HU1 1948 Laxá-Húsavík

26 0.1 16 16

58 0.15 11 11 19.3 0.1

Total 66 kV 33

Vestmannaeyjar Line 1 (sub-sea cable)

VM1 1962 Vestmannaeyjar-Rimakot

Vestmannaeyjar Line 2 (sub-sea cable)

VM2 1978 Vestmannaeyjar-Rimakot

Energy terms/abbreviations kV=kilovolt kW=kilowatt MW=megawatt=1000 kW kWh=kilowatt hour MWh=megawatt hour=1000 kWh GWh=gigawatt hour=1000 MWh

1033.8

127.5

16 15

Total 33 kV

58

Total 3343

31 244.4

41

42

Number of transformers

No. of switchyard bays

First year in service

Co-owner

Voltage [kV]

KKS code

Substations

Appendix 5: Landsnet’s substations at year-end 2017

Aðveitustöð 12 / Substation 12

A12

OR 132

Akranes

AKR OR 66 2016 4

Andakíll

AND OR 66 1974 3

0

Ásbrú

ASB 33 2011 8

0

2006 1

0 0

Bakki

BAK 220/33 2017 3/4

2

Blanda

BLA

0

Bolungarvík

BOL 66/11 2014 3/8

0

Breiðidalur

BRD OV 66 1979 4

0

Brennimelur

BRE

Búðarháls

BUD 220 2013 2

0 0

LV

RA

132 1991 5

220/132/66 1978 9/4/3

Búrfell

BUR

Dalvík

DAL RA 66 1981 1

0

Eskifjörður

ESK RA 66 1993 5

0

Eyvindará

EYV RA 132/66 1975 1/5

1

Fáskrúðsfjörður

FAS RA 66 1998 3

0

Fitjar

FIT HS 132 1990 5

0

Fljótsdalur

FLJ 220/132 2007 10/4

2

Flúðir

FLU RA 66 1995 3

0

Geiradalur

GED

0

Geitháls

GEH

220/132 1969 7/9

2

Glerárskógar

GLE

132 1980 3

0

OV

RA

220/66 1999 8/4

3

132 1983 3

Grundarfjörður

GRU RA 66 2017 3

Hamranes

HAM 220/132 1989 7/8

0 2

Hella

HLA RA 66 1995 4

0

Hnoðraholt

HNO OR 132 1990 2

0

Hólar

HOL

0

Hrauneyjafoss Hrútatunga

RA

132 1984 5

HRA

LV

220 1981 5

0

HRU

RA

132 1980 4

0

Hryggstekkur

HRY

RA

132 1978 6/5

Húsavík

HUS RA 33 1978 2

0

Hveragerði

HVE RA 66 1983 3

0

Hvolsvöllur

HVO RA 66 1995 4

0

Írafoss

IRA

Ísafjörður

ISA OV 66 2014 4

0 0

LV

220/132 1953 3/6

1

2

Keldeyri

KEL OV 66 1979 2

Klafastaðir

KLA 220/16 2013 1/4

1

Kolviðarhóll

KOL 220 2006 7

0

Korpa

KOR

Kópasker

KOP RA 66 1980 1

OR

LV

132 1976 6

Krafla

KRA

Lagarfoss

LAG RA 66 2007 5

Laxá

LAX

66/33 2003 6/1

1

Laxárvatn

LAV

132 1977 3

0

Lindarbrekka

LIN RA 66 1985 1

0

Ljósafoss

LJO

LV

66 1937 6

0

Mjólká

MJO

OV

132/66 1980 2/5

Nesjavellir

NES OR 132 1998 6

Neskaupstaður

NKS RA 66 1994 3

0

Ólafsvík

OLA RA 66 1980 1

0 0

RA

220/132 2017/1977 3/4

0 0 1 0

2 0

Prestbakki

PRB

RA

132 1984 3

Rangárvellir

RAN

RA

132/66 1974 8/7

Rauðimelur

RAU 132 2006 3

0

Reykjanes

REY HS 132 2006 3

0

2

Number of transformers

No. of switchyard bays

First year in service

Voltage [kV]

KKS code

RIM RA 66/33 1990 2/5

1

Sauðárkrókur

SAU RA 66 1977 3

0

Co-owner

Substations Rimakot

Selfoss

SEL RA 66 2005 5

0

Seyðisfjörður

SEY RA 66 1957 2

0

Sigalda

SIG

Silfurstjarnan

SIL RA 66 1992 1

LV

220/132 1977 7/1

1 0

Stakkur

STA 132 2016 3

1

Steingrímsstöð

STE

0

Stuðlar

STU RA 132/66 1980 3/5

2

Sultartangi

SUL

0

LV

66 1959 1

220 1999 6

Svartsengi

SVA HS 132 1997 4

0

Teigarhorn

TEH

RA

132 2005 3

0

Varmahlíð

VAR

RA

132/66 1977 3/1

1

Vatnsfell

VAF

220 2001 2

0

Vatnshamrar

VAT

132/66 1976 4/6

Vegamót

VEG RA 66 1975 4

0

Vestmannaeyjar

VEM HS 66/33 2017/2002 1/2

0

Vogaskeið

VOG RA 66 1975 3

0

Vopnafjörður

VOP RA 66 1982 1

0

RA

2

Þeistareykir

THR 220/66 2017/2013 5/1

1

Þorlákshöfn

TOR RA 66 1991 3

0

Öldugata

OLD 132 1989 3

0

RA=RARIK (Iceland State Electricity) OV=Westfjord Power Company HS=Sudurnes Regional Heating LV=Landsvirkjun OR=Reykjavík Energy

43

Appendix 6: Indices for sheddable load and average curtailment load The National Energy Authority now requires the measurement these indices which have no specific objectives.

Power Energy Curtailment Index The Power Energy Curtailment Index measures curtailed energy delivery, which is the ratio of energy curtailment if the power had been unchanged during the entire curtailment period and the total power in the system.

Power Energy Curtailment Index

MWh/MW year

3.0

SSO 2.5

2.0

1.5

1.0

0.5

0.0 2008

2009

2010

2011

2012

Landsnet’s system

2013

2014

2015

2016

2017

Landsnet’s system and others

Figure 301).

Power Supply Average Curtailment per Disturbance The Power Supply Average Curtailment per Disturbance Index measures the average curtailment of load, which is an indicator of the average curtailment in each disturbance.

MW/fault

Power Supply Average Curtailment per Disturbance

90

SMA

80 70 60 50 40 30 20 10 0

2008

2009

2010

2011

2012

Landsnet’s system

2013

44

2015

Landsnet’s system and others Figure 312)

1. Table 23 in Appendix 9 shows the data used for the graph.

2. Table 24 in Appendix 9 shows the data used for the graph.

2014

2016

2017

Appendix 7: Grid disturbances and faults

Figure 32: Shows the average number of curtailments over a ten year period. Categorised by system component and within a set timeframe.

Average number of curtailment events 2008-2017 â&#x20AC;&#x201C; by duration Number 60 50 40 30 20 10 0 0-3 min

3-30 min

30-60 min Substations

1-12 hours

12-24 hours

Lines and cables

1-7 days

More

System failures

Figure 32.

Faults in Substations There were 54 faults in substations in 2017. Figure 33 shows the causes of faults in substations compared with the 10-year average. Figure 34 shows faults in substations categorised by stations as well as the 10-year average for comparison.

Number 40

Number of faults in substations â&#x20AC;&#x201C; by cause

35 Average 2008-2017

2017

30 25 20 15 10 5 0 External influence

Technical fault

Human error

Weather

User system

Unknown

Figure 331).

1. Table 25 in Appendix 9 shows the data used for the graph.

45

Faults categorised – by station Mjólká Fljótsdalur Sigalda - substation Brennimelur Eyvindará Hryggstekkur Blanda - substation Stuðlar Hamranes Eskifjörður Rangárvellir Geitháls Vatnshamrar Rimakot Flúðir Hólar Breiðidalur Vegamót Vestmannaeyjar Vogaskeið Stakkur Fitjar Írafoss - substation Hvolsvöllur Þeistarreykir Glerárskógar Akranes Öldugata Kolviðarhóll Steingrímsstöð - substation Hrauneyjarfoss - substation Búrfell - substation System disturbions Prestbakki Laxá - substation Krafla - substation Sauðárkrókur Varmahlíð Klafastaðir Ljósafoss - substation Hella Vopnafjörður Lagarfoss Neskaupstaður Fáskrúðsfjörður Teigarhorn Kópasker Hrútatunga Bolungarvík Ísafjörður Grundarfjörður Reykjanes Korpa - substation Selfoss Þorlákshöfn Sultartangi - substation Seyðisfjörður Bakki Silfurstjarnan Lindarbrekka Húsavík Bjarnarflag - substation Dalvík Laxárvatn Keldeyri Geiradalur Andakíll Ólafsvík Ásbrú Rauðimelur Svartsengi Hnoðraholt A12 Nesjavellir Hveragerði Búðarháls Vatnsfell - substation

Average 2008-2017

0

0.5

1

1.5

2

2.5

3

3.5

2017

4

4.5 Number

Figure 34.

46

Faults in Lines and Cables There were 32 faults in overhead lines and cables in 2017, compared with 46 faults in the previous year. These faults are divided between operating voltage (see Figure 35). Figure 36 shows the cause of line faults in 2017 including the the 10year average.

Figures 37 to 39 show the average number of faults per year for every 100 km (for 220, 132 and 66 KW lines) over the past 10 years.

Number of faults on lines and cables per 100 km and per year

Number

16 15 14 13 12 11 10 9 8 7 6 5 4 3 2 1 0 2008

2009

2010 2011 33 kV

2012 66 kV

2013 2014 2015 132 kV 220 kV

2016

2017

Figure 351).

Number of faults on lines and cables â&#x20AC;&#x201C; by cause

Number

40 Average 2008-2017

2017

35 30 25 20 15 10 5 0 External influence

Technical fault

Human error

Weather

User system

Unknown

Figure 362).

1. Table 26 in Appendix 9 shows the data used for the graph.

2. Table 27 in Appendix 9 shows the data used for the graph.

47

Average number of faults per year on 220 kV lines per 100 km – 2008-2017 NA1, NA2 KH1 HR1 BU1 BU2 BR1 HN1, HN2 SO3 BU3 FL3 SU3 SU1 VF1 SU2 SI3 SI2 JA1 IS1, IS2 FL4 BH1 0

0.2

0.4

0.6

0.8

1

1.2

1.4

1.6

1.8

2

Average number / 100 km / year

Figure 37.

Average number of faults per year on 132 kV lines per 100 km – 2008-2017 VA1 MJ1 FL2 GE1 HA1 GL1 SI4 SO2 HT1 SN1 SR1 NE1 TE1 LV1 PB1 KR2 KR1 NE2 EY1 RA1 BL2 SM1 RV1 RM1 RA2 MF1 KO1 HO1 HF1 FI2 BL1 AD7

0

2

4

6

8

10

12

14

Average number / 100 km / year

Figure 38.

48

Average number of faults per year on 66 kV lines per 100 km â&#x20AC;&#x201C; 2008-2017 BV1 HE2 TA1 SE2 VA2 IF1 LA1 FU1 GF1 OL1 SA1 BD1 SF1 FA1 AN1 RI1 HV1 VP1 KS1 HG1 NK1 SE1 ES1 BV2 VM3 SR2 TO1 VE1 VS1 LF1 TR2 ST1 SE3 LJ1 HE1 DA1 AK1

0

5

10

15

20

25

30

Average number / 100 km / year

Figure 39.

49

Appendix 8: Voltage quality Quality of voltage supply National network 132 kV

Quality of voltage supply 220 kV 70000

40000

60000

35000

50000

30000

GED GLE HOL HRU HRY LAV PRE TEH VAR

25000

40000

20000

BRE_AT

30000

HAM_AT

15000

FJA_AT

20000

10000

FJA_BT

10000

5000

0

0 144

146

142

140

138

136

134

132

130

128

126

124

122

120

118

234

232

230

228

226

222

224

220

218

216

214

212

210

208

204

206

202

200

Figure 40.

Figure 41.

Quality of voltage supply Southwest Region 132 kV

Quality of voltage supply West Region 66 kV 50000

40000

45000

35000

40000

30000

35000

25000

30000

20000 15000

FIT

25000

GEH

20000

HAM

10000

KOR

15000

OLD

10000

5000

SVA

5000

0

AND BRE GRU OLA VAT VEG VOG

0 146

144

142

140

138

134

136

132

130

128

124

126

122

118

120

59 60

Figure 42.

61 62 63 64 65 66 67 68 69 70

71

72 73

Figure 43.

Quality of voltage supply West Fjords 66 kV

Quality of voltage supply North Region 66 kV

70000

120000

60000

100000

50000

DAL

80000

LAX

40000

RAN

60000 30000

SIS

BOL

KOP

BRD

20000

LIN

40000

SAU

ISA

20000

KEL

10000

MJO

0

0 59 60 61 62 63 64 65 66 67 68 69 70 Figure 44.

71

72 73

59 60 Figure 45.

61 62 63 64 65 66 67 68 69 70

71

72 73

71

72 73

Quality of voltage supply South Region 66 kV

Quality of voltage supply East Region 66 kV 90000

60000

80000 50000

70000 60000

ESK

50000

EYV FAS

40000

HLA HVE

30000

HVO

LAG

30000

NKS

20000

SEY STU

10000

LJO

20000

RIM SEL

10000

TOR

VOP

0

0 59 60 Figure 46.

50

FLU

40000

61 62 63 64 65 66 67 68 69 70

71

59 60

72 73 Figure 47.

61 62 63 64 65 66 67 68 69 70

Appendix 9: Tables and graphs Year

Index Index

Year

Landsnet

Other systems

Landsnet Landsnet and

Ratio other systems Ratio

2008

2.04 0.25

2009

0.37 0.64

2008

0.99987 0.99986

2010

0.54 0.55

2009

0.99994 0.99989

2011

0.42 0.06

2010

0.99998 0.99995

2012

0.81 0.12

2011

0.99995 0.99995

2013

0.60 0.23

2012

0.99966 0.99965

2014

1.16 0.72

2013

0.99997 0.99996

2015

0.81 0.39

2014

0.99996 0.99994

2016

0.37 0.17

2015

0.99995 0.99993

2017

0.93 0.22

2016

0.99999 0.99998

2017

0.99992 0.99991 General primary load

Table 5. Index of Reliability (AS).

Data for Figure 4.

Year

Landsnet

Other systems

2008

66.9 9.0

2009

31.8 28.3

2010

10.3 17.1

2011

26.7 0.5

2012

180.4 3.3

2013

18.3 4.6

2014

23.0 11.0

2015

25.4 10.8

2016

5.1 4.4

2017

42.5 5.6

Table 6. Outage minutes due to grid disturbances Data for Figure 5.

Year

Table 8. Power Interruption Index (SRA).

Data for Figure 8.

Major users Distribution systems LN Other systems LN Other systems

2008

69.3 11.2 57.3 0.1

2009

4.6 34.8 149.0 0.4

2010

3.6 20.7 40.0 1.3

2011

10.9 0.2 96.6 1.6

2012

107.1 3.3 503.8 3.6

2013

5.6 4.2 74.8 6.2

2014

23.4 12.3 21.0 5.0

2015

19.8 10.3 48.9 13.0

2016

2.5 5.5 16.3 0.0

2017

47.0 5.5 23.8 5.7

Region 2017 Average 2013-2017 Capital

8.44 1.91

Suรฐurnes

66.41 20.54

South

79.37 47.68

West

0.37 39.76

West Fjords

41.63

Northwest

62.76 46.35

Northeast

21.53 54.09

East

77.52 69.47

Total general primary load

30.99

589.11

45.83

Table 9. Outage minutes for general primary load.

Data for Figure 9.

Total primary load Region

2017

Average

2013-2017 Capital

5.76 1.15

Suรฐurnes

446.49 89.42

South

79.37 47.68

West

12.74 11.74

West Fjords

93.27

Northwest

166.87 67.17

Northeast

11.85 61.59

East

90.98 33.27

Total primary load

42.45

599.44

22.83

Table 10. Outage minutes for total primary load.

Data for Figure 10.

Table 7. Outage minutes by users.

Data for Figure 6 and Figure 7.

51

Year

Weather Technical Human error Other Total Curtailm. Curtailm. Curtailm. Curtailm. Curtailm.

MWh MWh MWh MWh MWh

Year Substations Lines and System Total

Number cables faults Number

Number Number

2008 42.3

3.6

20.1

0.9 66.9

2008

28 49 1 78

2009 28.1

2.2

1.5

0.0 31.8

2009

11 33 0 44

2010 2.5 6.9 0.9 2.5 12.7

2010

8 21 0 29

2011 16.1 1.6

9.0 0.2 26.9

2011

17 33 0 50

2012 178.2 2.2

0.0

2012

11 70 0 81

2013 15.4 0.0

2.8 3.5 21.7

2013

6 42 0 48

2014 3.8 7.9 10.9 8.7 31.4

2014

15 49 4 68

2015 5.4 18.3 0.6 6.0 30.2

2015

22 68 5 95

2016 2.1

0.2 3.6 7.5

2016

22 45 4 71

2017 4.3 8.8 29.3 5.4 47.8

2017

36 32 6 74

1.7

2.4 182.8

Table 11. Outage minutes by cause.

Data for Figure 11.

Table 14. The number of grid disturbances by subsystem.

Data for Figure 20.

Substations Overhead lines System faults and cables

Year

Duration of A verage No. in Average No. in Average No. in curtailment 2008- 2017 2008- 2017 2008- 2017

2017 2017 2017

Weather Technical Human error Other Total Number Number Number Number Number

2008 35

30

9

4

78

2009 26

9

6

3

44

8

3

5 29

0-3 mín

3.5

6

11

0

0.7

1

2010 13

3-30 mín

15.5

30

33.1

10

5.2

16

2011 24 14

8

4 50

30-60 mín

3.8

7

6.9

5

1.2

1

2012 67

5

2

7 81

1-12 klst 5.6 8 9.9 12 1.3 10

2013 34

1

8

5 48

12-24 klst 0 0 1.9 0 0 0

2014 40

11

6

11 68

1-7 dagar 0.1 0 2.3 0 0 0

2015 58

18

7

12 95

Longer 0 0 0.1 0 0 0

2016 31 20

5

15 71

2017 20 26

18 10 74

Table 12. The number of curtailment events by duration.

Data for Figure 12.

Year

Table 15. The number of grid disturbances by cause.

Data for Figure 21.

Category 0 Category 1 Category 2 Category 3 Total.

Number Number Number Number Number

Year Substations Lines and System Total

Number cables faults Number

Number Number

2008 44

6

2

0 52

2009 23

7

1

0

2010 18

3

0

0 21

2008

37 60 15 112

2011 22

4

0

0 26

2009

20 34 2 56

2012 42

9

4

0 55

2010

9 20 12 41

2013 27

4

1

0 32

2011

20 33 2 55

2014 44

5

0

0 49

2012

16 71 7 94

2015 39

6

0

0 45

2013

10 41 0 51

2016 33

2

0

0 35

2014

15 49 18 82

2017 29

9

1

0 39

2015

25 70 26 121

Table 13. Classification of disturbances by system minutes in 2007-2017.

Data for Figure 13.

2016

22 46 16 84

2017

45 32 12 89

31

Table 16. The number of faults in the transmission system by subsystem.

Data for Figure 22.

52

Month Substations Lines and System Total

Number cables faults Number

Number Number

Month Substations Lines and System Total

Number cables faults Number

Number Number

Jan

3.6 7.0 2.2 12.8

Jan

5 1 1 7

Feb

2.1 4.9 1.7 8.7

Feb

4 6 2 12

March

2.5 6.4 1.2 10.1

March

5 4 0 9

Apr

0.6 3.4 0.8 4.8

Apr

3 5 0 8

May

1.2 1.6 0.7 3.5

May

5 6 3 14

June

1.5 1.5 0.9 3.9

June

4 2 1 7

July

1.0 0.7 0.9 2.6

July

4 0 0 4

Aug

1.6 0.8 0.8 3.2

Aug

3 0 1 4

Sep

1.1 2.7 0.4 4.2

Sep

3 1 1 5

Oct

2.6 3.2 0.6 6.4

Oct

3 1 0 4

Nov

1.9 4.9 0.2 7.0

Nov

7 4 1 12

Dec

2.3 8.5 0.6 11.4

Dec

1 2 0 3

Table 17. The number of faults in the transmission system by months â&#x20AC;&#x201C; average of past ten years. Data for Figure 23.

Year 220 kV 132 kV 66/ 11 kV Without Total 33 kV voltage

No. No. No. No. No. No. 2008

25 29 57 1

0 112

2009

6 16 35 0 0 57

2010

7 13 21 0 0 41

2011

7 17 31 0 0 55

2012

8 26 60 0 0 94

2013

2 19 30 0 0 51

2014

9 34 37 0 2 82

2015

13 51 53 0 4 121

2016

9 29 42 0 4 84

2017

15 33 36 1

4 89

Table 18. The number of faults in the transmission system by voltage level.

Data for Figure 24.

Duration Average Total

2008-2017 2017 No./year 0-3 min

6.1

3

3-30 min

25.7

27

30-60 min

8.5

16

1-12 hours

22.7

30

12-24 hours

5.8

3

1-7 days

7.9

8

Longer 1.9 2 Table 19. Classification of faults by duration.

Data for Figure 25.

Table 20. The number of faults in the transmission system by months in 2017.

Data for Figure 26.

Year

Weather Technical Human error Other Total Number Number Number Number Number

2008 46

51

11

4 112

2009 26

20

8

3

2010 13 20

3

5 41

2011 24 19

8

4 55

2012 67

18

2

7 94

2013 34

4

8

5 51

2014 40 25

6

11 82

2015 59

43

7

12 121

2016 31 32

6

15 84

2017 20

18 10 89

41

57

Table 21. The number of faults in the transmission system by cause.

Data for Figure 27.

Component type

Average 2008-2017 2017 Number Number

Capacitors

1.5 3

Power transformers

2.6

6

Control and support systems

21

32

Disconnectors

0.3 2

Circuit breakers

3.8

5

Bus bars

0.3

0

Surge protectors

0

0

Thyristors

0 0

Station. other

2

6

44.6

31

Overhead lines Cables No unit

1 1 3.6

3

Table 22. The number of faults in the transmission system by component type.

Data for Figure 28.

53

Year Index Index

Landsnet Landsnet and

MWh/MW year other systems

MWh/MW year 2008 0.97 1.10 2009 0.50 0.92 2010

0.15 0.42

2011

0.49 0.49

2012

2.73 2.78

2013

0.52 0.59

2014

0.91 1.52

2015

2.59 2.76

2016

0.40 0.47

2017

0.65 0.76

Table 23. Power Energy Curtailment Index (SSO).

Data for Figure 30 in Appendix 6.

Year Index Index

Landsnet Landsnet and

MW disturbance other systems

MW disturbance

220 kV 132 kV 66 kV 33 kV No/ No/ No/ No/ 100 km 100 km 100 km 100 km

2008

0.47 1.27 4.06 1.77

2009

0.00 1.03 2.08 1.77

2010

0.35 0.32 1.35 0.00

2011

0.24 0.87 2.08 0.00

2012

0.35 1.11 4.78 14.16

2013

0.00 1.14 2.53 1.37

2014

0.12 1.51 2.75 1.37

2015

0.47 2.19 3.66 1.37

2016

0.23 1.35 2.56 0.00

2017

0.23 0.30 2.56 0.00

Table 26. Number of faults in overhead lines and cables per 100km per year.

Data for Figure 35 in Appendix 7.

Cause

Average 2008-2017 2017 Number Number

External influence

5.6

8

2008

80.76 81.43

Technical 4.9 4

2009

24.79 63.46

Human error

2010

36.05 75.27

Weather 34.5 19

2011

30.61 32.92

Userâ&#x20AC;&#x2122;s system

2012

28.16 30.61

Unknown 0.3

2013

33.99 44.01

Total

2014

41.48 51.58

2015

29.82 37.79

2016

19.70 26.04

2017

48.61 52.46

Table 24. Power Supply Average Curtailment per Disturbance Index (SMA).

Data for Figure 31 in Appendix 6.

Cause

Average 2008-2017 2017 Number Number

External influence

0.2

1

Technical 22.3 37 Human error

6.9

15

Weather 1.5 1 Userâ&#x20AC;&#x2122;s system

0.9

0

Unknown 0.1 0 Total

31.9 54

Table 25. Number of faults in substations by cause.

Data for Figure 33 in Appendix 7.

54

Year

0.3

0

0

0 1

45.6 32

Table 278. Number of faults in overhead lines and cables by cause.

Data for Figure 36 in Appendix 7.

Reliability of Supply and Quality of Delivered Electricity Performance Report 2017 Authors: Kjartan Sigurjónsson, Daniel Leó Ólason, Kristveig Þorbergsdóttir, Jón Vilhjálmsson (Efla Consulting Engineers), Kolbrún Reinholdsdóttir (Efla Consulting Engineers) and Ingvar Baldursson (Efla Consulting Engineers) Project managers: Kjartan Sigurjónsson og Daniel Leó Ólason Abstract: The Performance Report is a summary of information on the Icelandic transmission system, including statistics and a ten-year comparison. The Report assesses Landsnet’s performance with regard to the quality and secure delivery of electricity.

Translation: Hulda Kristín Jónsdóttir Supervision and layout: Athygli Photos: Landsnet Graphics: Effekt Landsnet –Report no. 18029 November 2018

55

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