sis psac murcia 20 mw (3)

8/17/2019 Sis Psac Murcia 20 Mw (3)

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Draft Report

System Impact Study Report

20 MW Murcia Solar Power Project

Prepared for:

By:

PH Solar Advance Corp.

Blumentritt, Muria, Negros Occidental


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EXECUTIVE SUMMARY

This System Impact Study (SIS) is conducted for the 20 MW Murcia Solar Project of

PH Solar Advance Corp. (PSAC) in Blumentritt, Murcia City, Negros Occidental.

This project will utilize 20 units of 1 MVA grid-tied inverters. The proposed

connection for this project is a tapped connection along Bacolod-NNGPP 138 kV line.

This study was performed in accordance with the Philippines Grid Code (PGC) andNGCP requirements. The purposes of this study are as follows:

1. Analyze the steady-state, stability, and short circuit conditions of the grid with

the project;

2.

Determine any upgrades to the transmission system that would be required to

mitigate any adverse impacts that the project could otherwise pose on thereliability and operating characteristics of the transmission system in

accordance with the PGC, NGCP standards and generally accepted

international transmission utility practices;

3. Determine any upgrades required to mitigate any degradation to transmission

transfer capability; and

4.

Determine any upgrades required to mitigate any degradation to system

dynamic stability.

The primary area of concern of this study is the area around NGCP’s Bacolod

Substation. Generated power from the proposed power plant will be transmitted to

Visayas grid through this substation.

In addition to the standard requirements of the PGC, the ERC had issued Resolution

No. 7 Series of 2013 imposing new requirements for intermittent power plants such as

this project. This proposed power plant should comply with those requirements,


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The project currently has a 120 MW capacity endorsed by the Department of Energy

(DOE) over phases. The developers have since identified suitable land sites and havemade the requisite arrangements with the landowners for long-term leases. Various

irradiation, flood, topography and soil studies have already been conducted with

positive results. In addition many of the local and national approvals and permits

have since been obtained including local LGU endorsements. Technical layouts and

routing plans have also been identified and secured.

Currently there might be some “anticipated constraint” in the submarine

interconnection between Negros and Cebu islands due to various projects being

planned for but many of which may not get implemented. In light of this ‘constraint”

the capacity of the project was reduced to 20 MW for this current phase for ease of

implementation.

This project has been developed and structured to allow for a quick expansion of

another 40 MW in Phase II. The key milestone for this expansion would be the

alleviation of the potential congestion along the Cebu-Panay submarine cable. This

alleviation would be evident when either the submarine cable is reinforced or when the

various other projects included in the base data is formally terminated.

In December 2014, Italy's Prysmian was awarded this US$111 million project by the

NGCP for the design, supply, installation, and commissioning of a submarine power

cable link to connect Negros and Panay islands in the Philippines. The submarine

cable link will back up the existing 138 kV oil filled cable circuit, which is currently

the only connection among the islands. CNP-1 comprises of three HVAC (High Voltage

Alternating Current) 230 kV single core cables with XLPE insulation and single wire

armouring along a 22 km submarine route across the Guimaras Strait. Delivery andcommissioning is scheduled for the first half of 2016. Phase II (40MW) of the solar

plant will be implemented after CNP-1 is commissioned.

In addition, in April 2015 NGCP announced plans to invest P1.6 billion to upgrade a


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Description Phase I

Phase II

(once CNP-1 iscompleted or when

capacity avails

itself)

Size MW 20.00 40.00

TimeFrame 2015/2016 2016/2017

S TEADY S TATE

Steady state thermal and voltage analyses were conducted to examine the comparative

system performance with and without the proposed project. The baseline performance

is based on the system without the proposed project. System performance was re-

evaluated with the project and compared with the baseline system. This approach

exposes the impact of the project on the system utilizing the criteria set by the PGC.

Steady state analysis was evaluated using a scenario where power plants at close

proximity to the project were dispatched to its maximum feasible levels for years 2016

and 2021. Peak load for 2016 and 2021 were respectively, 1,854.8

MW and 2,279.8

MW. Simulation at this dispatch scenario enabled the examination of the transmission

system to reliably operate with the proposed project integrated to the system.

Based on the steady state results the project’s connection to the grid poses nosignificant adverse impact on the reliability and operating characteristics of Visayas

grid. There was no significant voltage or thermal violations of reliability criteria

associated with the entry of the project considering its priority dispatch incentive

under the RE Law


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In all tested fault conditions the project would pose no significant adverse impact on

the stability of the system.

F REQUENCY ASSESSMENT

Frequency assessment showed that the system frequency will not drop as low as 59.4

Hz with the outage of the proposed power plant. Automatic Load Dropping is notexpected during this loss-of-generation scenario.

S HORT C IRCUIT

Short-circuit analysis was conducted to determine the impact of the project on the

existing fault current levels in all substations. In this study, it was assumed that fault

duty of the circuit breakers installed in the system are as follows:

Simulation results indicate that the entry of the proposed project will not result to

fault levels beyond the fault duties of the existing circuit breakers.

Volage Level

Rated Short

CircuitCurrent (kA)

69kV 230 kV 40


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TABLE OF CONTENTS

Executive Summary

Steady State

Stability

Frequency Assessment

Short Circuit

Conclusion

1. Background Information ................................................................................................... 9

2. Study Assumptions ......................................................................................................... 11

A. Demand Forecast ..................................................................................................... 11

B. Generation Expansions ................................................................................................ 11

C. Transmission Expansions ......................................................................................... 13

D. Grid Code Requirements ......................................................................................... 14

3. Proposed Connection Arrangement and System Modelling ............................................ 18

4. Load Flow Assessment .................................................................................................... 22

A. Thermal Assessment – Adequacy in Normal Conditions (Peak Conditions) ........... 23

B. Thermal Assessment – Adequacy in Single Outage Conditions (Peak Conditions) ..... 24

C. Voltage Assessment in Normal Conditions (Peak) .................................................. 25

D. Voltage Assessment in Single Outage Condition (Peak Conditions) ....................... 26

5. Fault Level Analysis ....................................................................................................... 28

6. Stability Assessment ....................................................................................................... 29

7. Frequency Assessment .................................................................................................... 32


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LIST OF TABLES

Table 1. Demand Projections for Visayas ............................................................................. 11

Table 2. Generator Capacity Additions for Visayas ............................................................. 12

Table 3. Power Circuit Breaker Fault Duty Rating ............................................................. 14

Table 4. Requirements at Different Frequency Range .......................................................... 16

Table 5. Lumped Generator Specifications ........................................................................... 19

Table 6. Grid Transformer Data ........................................................................................... 20

Table 7. Transmission Line Data .......................................................................................... 20

Table 8. Dynamics Data for 20 MW Lumped Generator Units ............................................ 21

Table 9. Dynamics Data for the Electrical Controls ............................................................. 22

Table 10. 2016 Thermal Assessment (Peak, Normal Loading) ............................................. 23

Table 11. 2021 Thermal Assessment (Peak, Normal Loading) ............................................. 23

Table 12. 2016 Thermal Assessment (Peak, N-1 Loading) ................................................... 24

Table 13. 2021 Thermal Assessment (Peak, N-1 Loading) ................................................... 24

Table 14. 2016 Voltage Assessment (Peak, Normal Loading) ............................................... 25

Table 15. 2021 Voltage Assessment (Peak, Normal Loading) ............................................... 25

Table 16. 2016 Voltage Assessment (Peak, N-1 Loading) ..................................................... 26

Table 17. 2021 Voltage Assessment (Peak, N-1 Loading) ..................................................... 27

Table 18. Short Circuit Rating of Selected Substations in the Grid ..................................... 28

Table 19. Short Circuit MVA at Power Plant 138 kV S/S (Peak Loading) ......................... 28

Table 20. Summary of Dynamic Stability Simulations with Power Plant ............................ 30


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LIST OF FIGURES

Figure 1. Generation Capacity Additions in Visayas ............................................................ 12

Figure 2. Transmission Expansion Projects in Visayas ......................................................... 13

Figure 3. Low Voltage Withstand Capability Requirement for Large Photovoltaic Systems 17

Figure 4. Connection Scheme for the Project ....................................................................... 18

Figure 5. Geographic Location of the Project ....................................................................... 19

Figure 6. Equivalent Model of the Grid in the Vicinity of the Project ................................. 21

Figure 7. Frequency Assessment, 2016 Peak Base Case ....................................................... 32

Figure 8. Frequency Assessment, 2021 Peak Base Case ....................................................... 33


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1. BACKGROUND INFORMATION

PH Solar Advance Corp (PSAC) is a wholly owned Filipino corporation and was set

up to fully focus on developing the Philippine Solar market. The founder, Ms. Maricel

Montfort, a highly successful native of Cadiz and currently residing in Bacolod and

Manila, is a long-standing citizen who has had an extensive working experience abroad

and has returned back to the Philippines to take an active part in improving the lives

of the local Filipinos through various infrastructure projects. Ms. Montfort is

currently active with several large infrastructure and social developments throughout

the Philippines. These include medical facilities, orphanages, water-

treatment/purification projects and land & property investments. Being a very

successful business lady, she is able to fully fund the professional and properdevelopment of these projects.

PSAC has identified Murcia City as a suitable site for the solar power project. Murcia

has a stable climate with adequate sunlight throughout the year and minimal risk of

heavy typhoons or flooding. Land is plentiful and the local government agencies are

supportive of such an initiative. Murcia currently has no power generation facilities

and all power is supplied from NGCP. It is an initiative welcome in the area.

PSAC has been actively developing the project for the last 6 months and focused on

securing the right land location and negotiating with the landowners to ensure terms

and conditions and commercially viable for the project. PSAC has actively engaged

the local LGU's and have planned for CSR activities for the area once the project

moves ahead.

For the land status the following were already accomplished:

a ) Identified and secured approximately 90h with the landowners Many of the


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line has the capacity for this solar plant. The Bacolod NGCP substation is less

than 2 km away and suitable evacuation plan have been developed.

c.) PSAC has engaged professionals to conduct

• Irradiation Studies

• Flood studies

•

Topographical surveys• Soil Studies

• Connection routing and

• Plant layout design

The site has ideal road access and is relatively flat with little flood risk. The

lands will not inconvenience any inhabitants. The landlords have committedto ensure the site will be problem free.

d.) The lands identified are outside the CARP jurisdiction and have obtained

proper legal advice as well as advice from the local LGU's on the proper

procedure to ensure that the site is solar ready.

e.) The land titles have also been checked for any risk of foreclosure or

encumbrances being attached.

f.) PSAC has also ensured that there are no sensitive or endangered trees on the

site and will not need any special approval or process.

Given the extent of the development already completed and other activities ongoing,

PSAC aims to begin construction of the plant in Q2 2015 with a physical completion


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This project proposes to connect to the grid through a tapped connection along

Bacolod- NNGPP 138 kV transmission line. This line is a portion of the 138 kV line

originating from Bacolod Substation to the Northern Negros Geothermal Power Plant.

With a total length of 25.5 km this line is owned by Enegy Development Corporation

(EDC).

The proposed tapping connection would involve construction of approximately 800 m

138 kV transmission line and a take-off substation at the power plant site. Conductors

for this line should be 795 MCM ACSR equipped with appropriate communication

facility to convey revenue meter reading to NGCP’s Bacolod Substation.

2.

STUDY ASSUMPTIONS

A. DEMAND FORECAST

Based on the 2013 Transmission Development Plan (TDP), there would relatively be

a significant increase in demand in Visayas Grid. Table 1 shows the demand

projections for the entire grid. Of greater interest for this proposed project is the

demand in Negros Island where the proposed facility will be injecting its power to the

grid. Bacolod Substation will be the main corridor of this project.

Table 1. Demand Projections for Visayas


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Department of Energy as “Committed”, “Indicative” and “Prospective”. The

generators considered in the study is shown in Figure 1, corresponding table is shown

in Table 2.

Figure 1. Generation Capacity Additions in Visayas

Table 2. Generator Capacity Additions for Visayas


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C. TRANSMISSION EXPANSIONS

Major developments in Negros island included in the 2013 TDP are as follows:

1. Negros-Panay Interconnection Uprating

2. Negros V Transmission Line Project

3. Visayas Substation Expansion I (Kabangkalan 1 x 50 MVA)

4.

Visayas Substation Reliability I (Amlan 1 x 50 MVA, Bacolod 1 x 100 MVA

and Cadiz 1 x 50 MVA)

These proposed developments shown in Figure 2 as well as generation expansions were

included in the base cases and were considered in the assessments.


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D. GRID CODE REQUIREMENTS

The proposed project’s performance was evaluated based on the criteria set by the

Philippine Grid Code, utilizing grid dispatch scenario where power plants near the

project were set at maximum dispatch to reflect the worst impact of the project to the

grid. Steady state voltage and thermal analyses examined system performance without

the proposed project in order to establish a baseline data. System performance was

re-evaluated with the project and compared with the previous baseline performance todemonstrate the impact of the project on area transmission reliability.

The voltage limits adopted in this study were in compliance with the PGC which

requires that during normal and single outage contingency conditions, the voltage

should be within the range of 0.95 to 1.05 per unit. For the thermal limits, normal

thermal ratings shall not be violated under all-lines-in and single outage contingency

conditions. The steady state analysis was performed with both pre-contingency and

post-contingency solution parameters that allow adjustment of load tap-changing

transformers (LTCs), static var devices (SVDs) including switched capacitors and

phase angle regulators (PARs).

For short circuit studies, resulting three phase fault should not exceed the levels shown

in Table 3. These ratings are the standard fault duty rating of circuit breakers

connected to the grid.

Voltage Level

Rated Short Circuit Current

(kA)

69kV 230 kV 40

Table 3. Power Circuit Breaker Fault Duty Rating


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1. The Grid remains stable after any Single Outage Contingency for all forecasted

Load conditions; and

2.

The Grid remains controllable after a Multiple Outage Contingency. In the

case of Grid separation, no total blackout should occur in any Island Grid.

In this study however, only stability under single outage contingency conditions were

evaluated.

Applied faults were cleared (normal clearing) in compliance with the requirements of

the PGC Section 4.5.2.3 as follows:

1. 85 ms for 500 kV;

2. 100 ms for 230 kV and 138 kV; and

3. 120 ms for voltages less than 138 kV

Delayed clearing were simulated in accordance with the requirements of the PGC

which states:

“The circuit breaker fail protection shall be designed to initiate the tripping ofall the necessary electrically-adjacent circuit breakers and to interrupt the fault

current within the next 50 milliseconds, in the event that the primary protection

system fails to interrupt the fault current within the prescribed Fault Clearance

Time”

In addition to the standard PGC requirements, the Energy Regulatory Commission(ERC) had issued Resolution No. 7 series of 2013 entitled “Resolution Adopting and

Approving Addendum to Amendment No. 1 of the Philippine Grid Code, Establishing

the Connection and Operational Requirements for Variable Renewable Energy (VRE)

Generating Facilities”. Under Article II Section 2 of this addendum, additional


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Generating Limit Power Output

The proposed power plant should continuously supply active and reactive power

depending on the availability of primary source within the frequency range of 59.7-

60.3 Hz. It should be capable of interchanging reactive power at connection point

within ±5% voltage variation. Outside this range and up to ±10% voltage variation,

a reduction in active and/or reactive power may be allowed up to 5% of the generator’s

declared data.

Frequency Withstand Capability

Table 4 shows the allowable power plant frequency response.

Reactive Power Capability

Table 4. Requirements at Different Frequency Range


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Performance during Network Disturbances

The allowable voltage ride-through for the power plant is shown in Figure 3.

Voltage Control System

The proposed power plant shall be capable of contributing voltage control bycontinuous regulation of the reactive power supplied to the grid under power factor

control mode wherein power factor is maintained at the connection point or voltage

control mode wherein voltage at the high voltage busbar of the proposed power plant

is maintained at a constant set-point.

Figure 3. Low Voltage Withstand Capability Requirement for Large PhotovoltaicSystems


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Power Quality

With the proposed power plant connected to the system and under normal operating

state, the Flicker Severity and Total Harmonic Distortion at the connection point shall

not exceed the values prescribed by the PGC

The proposed power plant will demonstrate compliance with these requirements

through testing to be conducted pursuant to Section 3.2.3.

3. PROPOSED CONNECTION ARRANGEMENT AND SYSTEM

MODELLING

In Figure 4 is shown the proposed connection for the project. This connection consistsof 138 kV transmission line “tapped” along Bacolod-NNGPP 138 kV line. The

project’s geographic location is shown in Figure 5.

Proposed Plant


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The technical specifications used to model the proposed connection assets of PSAC

solar power plant project are shown in Table 5 to Table 7.

Power

Capability

(MW)

Reactive Capability at

Full Dispatch (MVAR)Remarks

Table 5. Lumped Generator Specifications

Figure 5. Geographic Location of the Project

Power Plant Location

/Service Area

Tapping Point

Existing NGCP Bacolod-

NNGPP 138 kV Line

Take-off Substation


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The grid model or base cases used in this study for years 2016 and 2021 were provided

by NGCP. Both base cases were derived from the Transmission Development Plan

and considered transmission line and generator expansion plans for the period covered.

The scenario represented was peak loading condition, maximizing dispatch of power

plants in the vicinity of the project. Off-peak scenarios were not considered in the

assessment since the proposed power plant is not expected to operate during off-peak.

To reflect the priority dispatch scenario in the model, dispatch of conventional

synchronous machines in Negros area were slightly reduced. In actual application,

these conventional plants’ dispatch will vary due to the intermittence of the proposed

Description Tap RatioPresent

Tap

MVA

Rating

Tap

StepsR (pu)

X (pu)

based on

System

MVA

Generator

Transformers

13.8/138

D/YCenter 25 5 0 0.415600

Line Name Type LengthRate

(MVA)R (pu) X (pu) B (pu)

PSAC take-off –

138 kV tapping

138 kV, 795

MCMACSR

5 km 196 0.001924 0.013080 0.000114

138 kV tapping-

NNGPP

138 kV, 795

MCM

ACSR

20.5 km 196 0.007886 0.053630 0.000466

Table 6. Grid Transformer Data

Table 7. Transmission Line Data


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The 20 MW generator was modeled as lumped unit using “PVGU1” in the dynamic

stability study while the electrical controls was modelled as “PVEU1”. Parameters

for the models are shown in Table 8 and Table 9 respectively. Other system dynamics

data were provided by NGCP.

Figure 6. Equivalent Model of the Grid in the Vicinity of the Project

Table 8. Dynamics Data for 20 MW Lumped Generator Units


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4. LOAD FLOW ASSESSMENT

The results of the simulation for thermal adequacy are presented in Sections 4.A. and

4.B. while that for the voltages are shown in Sections 4.C. and 4.D.

Under normal loading conditions, considering the priority dispatch of intermittent RE

Generators, thermal loading of elements in the grid will remain within PGC required

limits. The number of grid loading violations during single-outage contingency

Table 9. Dynamics Data for the Electrical Controls


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A. THERMAL ASSESSMENT – ADEQUACY IN NORMAL CONDITIONS

(PEAK CONDITIONS)

The results of the simulations are given in Table 10 and Table 11 for the 2016 and

2021 base cases respectively.

Monitored ElementMVA

Rating

Peak Load Condition

Without

Murcia Solar

With

Murcia Solar

MVA % MVA %

1 Solar_Tap - Bacolod 138 kV Line 196 N/A 20.15 10.28

2 Bacolod-E. B. Magalona (1) 138 kV Line 196 20.23 10.32 20.34 10.38

3 Bacolod-E. B. Magalona (2) 138 kV Line 392 34.57 8.82 34.62 8.834 Kabankalan-Bacolod 138 kV Line 196 10.68 5.45 19.95 10.18

5 Amlan-Mabinay 138 kV Line 196 15.37 7.84 24.65 12.58

6 Amlan-Amlan SP 138 kV Line 196 132.92 67.82 152.52 77.82

7 Amlan SP - Pondol 138 kV Line 196 91.11 46.48 99.66 50.85

8 Samboan-Pondol 138 kV Line 108.04 91.31 84.51 99.89 92.46

9 E. B. Magalona (1)-Btc Viejo 138 kV Line 108 49.51 45.84 49.24 45.59

10 Btc Viejo-Dingle 138 kV Line 196 47.4 24.18 47.39 24.1811 Btc Viejo-Conception 138 kV Line 392 95.43 24.34 95.39 24.33

Monitored Element

MVA

Rating

Peak Load Condition

Without

Murcia Solar

With

Murcia Solar

MVA % MVA %

1 Solar_Tap - Bacolod 138 kV Line 196 N/A 20.15 10.28


3 Bacolod-E. B. Magalona (2) 138 kV Line 392 49 46 12 62 49 51 12 63

Table 10. 2016 Thermal Assessment (Peak, Normal Loading)

Table 11. 2021 Thermal Assessment (Peak, Normal Loading)


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B. THERMAL ASSESSMENT – ADEQUACY IN SINGLE OUTAGE

CONDITIONS (PEAK CONDITIONS)

Thermal N-1 adequacy assessments are given in and Table 12 and Table 13 for 2016

and 2021 base cases. The quantity of grid loading violations during this contingency

conditions essentially remained the same.


Rating

Peak Load Condition

Without

Murcia Solar

With

Murcia Solar

MVA % MVA %

1 Solar_Tap - Bacolod 138 kV Line 196 Single Circuit Single Circuit2 Bacolod-E. B. Magalona (1) 138 kV Line 196 85.03 43.38 85.03 43.38


4 Kabankalan-Bacolod 138 kV Line 196 51.14 26.09 61.12 31.18

5 Amlan-Mabinay 138 kV Line 196 55.26 28.19 64.93 33.13

6 Amlan-Amlan SP 138 kV Line 196 Single Circuit Single Circuit

7 Amlan SP - Pondol 138 kV Line 196 177.28 90.45 193.81 98.88

8 Samboan-Pondol 138 kV Line 108.04 178.36 165.09 194.95 180.449 E. B. Magalona (1)-Btc Viejo 138 kV Line 108 98.21 90.94 97.79 90.55

10 Btc Viejo-Dingle 138 kV Line 196 94.75 48.34 95.99 48.97

11 Btc Viejo-Conception 138 kV Line 392 190.33 48.55 190.28 48.54


Rating

Peak Load Condition

Without

Murcia Solar

With

Murcia Solar

MVA % MVA %

Table 12. 2016 Thermal Assessment (Peak, N-1 Loading)

Table 13. 2021 Thermal Assessment (Peak, N-1 Loading)


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C. VOLTAGE ASSESSMENT IN NORMAL CONDITIONS (PEAK)

Voltage assessment conducted on the system indicated that the entry of the project

will not contribute to voltage violations during normal loading conditions. Table 14

and Table 15 present the results of voltage assessment for the 2016 and 2021 base cases

respectively.

Monitored Substations

Peak Load Condition

Without

Murcia Solar

With

Murcia Solar

(kV) (p.u.) (kV) (p.u.)

4 SOLAR_TAP 138.00 N/A 140.06 1.0149

227601 COLON 138.00 136.70 0.9906 136.54 0.9894227700 SAMBOAN 138.00 137.03 0.9930 136.56 0.9896

235500 BACOLOD 69.000 70.449 1.0210 70.3938 1.0202

235501 BACOLOD 69.000 70.449 1.0210 70.3938 1.0202

237100 PONDOL 138.00 138.36 1.0026 138.11 1.0008

237101 PONDOL 138.00 138.37 1.0027 138.12 1.0009

237200 AMLAN HI 138.00 137.90 0.9993 137.67 0.9976

237201 AMLAN SP 138.00 137.90 0.9993 137.67 0.9976237300 MAB HI 138.00 138.79 1.0057 138.54 1.0039

237400 KABANKAL 138.00 139.30 1.0094 139.09 1.0079

237500 BACOLOD 138.00 140.15 1.0156 140.06 1.0149

237800 EBMAG1 138.00 140.88 1.0209 140.82 1.0204

237801 EBMAG2 138.00 141.05 1.0221 140.98 1.0216

247100 BTC VIEJ 138.00 141.19 1.0231 141.12 1.0226

247200 DINGLE 138.00 140.03 1.0147 139.99 1.0144247700 CNCPCION 138.00 141.49 1.0253 141.46 1.0251

Table 14. 2016 Voltage Assessment (Peak, Normal Loading)

Table 15. 2021 Voltage Assessment (Peak, Normal Loading)


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235540 FRST FRM 69.000 138.25 1.0018 1.0004 138.06

235850 MURCIA 69.000 137.70 0.9978 0.9965 137.52

235855 SLY ABS 69.000 137.70 0.9978 0.9965 137.52237100 PONDOL 138.00 138.26 1.0019 1.0006 138.08

237201 AMLAN SP 138.00 138.54 1.0039 1.0028 138.39

237400 KABANKAL 138.00 138.97 1.0070 1.0065 138.90

237500 BACOLOD 138.00 140.25 1.0163 1.0159 140.19

237800 EBMAG1 138.00 140.83 1.0205 1.0202 140.79

237801 EBMAG2 138.00 141.11 1.0225 1.0223 141.08

247100 BTC VIEJ 138.00 139.37 1.0099 1.0097 139.34247200 DINGLE 138.00 142.49 1.0325 1.0324 142.47

D. VOLTAGE ASSESSMENT IN SINGLE OUTAGE CONDITION (PEAK

CONDITIONS)

Results of voltage assessment during contingency conditions are shown in Table 16

and Table 17 for the 2016 and 2021 base cases respectively. No deviations from the

PGC prescribed limits are expected upon the entry of the proposed project to the grid.


Peak Load Condition

Without

Murcia Solar

With

Murcia Solar

(min) (max) (min) (max)

10 SOLARHIGH 69.000 N/A 0.9911 1.0249

227601 COLON 138.00 0.9752 0.9962 0.9737 0.9948227700 SAMBOAN 138.00 0.9711 1.0034 0.9661 1.0024

235501 BACOLOD 69.000 0.9967 1.0323 0.9952 1.0309

235510 BRGS-TAP 69.000 0.9967 1.0323 0.9952 1.0309

235520 VIEW-TAP 69.000 0.9892 1.0063 0.9848 1.0065

Table 16. 2016 Voltage Assessment (Peak, N-1 Loading)


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Peak Load ConditionWithout

Murcia Solar

With

Murcia Solar

(min) (max) (min) (max)

10 SOLARHIGH 69.000 N/A 0.9590 1.0163

227601 COLON 138.00 0.9983 1.0112 0.9970 1.0106

227700 SAMBOAN 138.00 0.9755 1.0028 0.9710 1.0022

235501 BACOLOD 69.000 0.9560 1.0220 0.9549 1.0207

235510 BRGS-TAP 69.000 0.9560 1.0220 0.9549 1.0207

235520 VIEW-TAP 69.000 0.9876 1.0051 0.9864 1.0044

235540 FRST FRM 69.000 0.9867 1.0051 0.9855 1.0044

235850 MURCIA 69.000 0.9867 1.0009 0.9855 1.0001

235855 SLY ABS 69.000 0.9867 1.0009 0.9855 1.0001

237100 PONDOL 138.00 0.9849 1.0091 0.9834 1.0081

237201 AMLAN SP 138.00 0.9783 1.0142 0.9769 1.0133

237400 KABANKAL 138.00 0.9600 1.0175 0.9590 1.0162

237500 BACOLOD 138.00 0.9878 1.0271 0.9873 1.0268

237800 EBMAG1 138.00 0.9614 1.0271 0.9604 1.0262

237801 EBMAG2 138.00 1.0055 1.0288 1.0051 1.0280

247100 BTC VIEJ 138.00 0.9979 1.0156 0.9981 1.0153

247200 DINGLE 138.00 1.0222 1.0363 1.0220 1.0358

Table 17. 2021 Voltage Assessment (Peak, N-1 Loading)


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5. FAULT LEVEL ANALYSIS

The fault current assessment determined the fault level at various buses/substations

in the grid in the vicinity of the proposed power plant. The entry of the proposed

project would not result to fault current exceeding the allowable levels. The resulting

short circuit currents are shown in Table 18. Table 19 shows the short circuit MVA

at the power plant substation.

Substation

Short Circuit @ Peak Load in Amperes

Without

Murcia Solar

With

Murcia Solar

2016 2021 2016 2021

2 [SOLARMID 13.800] N/A 8,146.70 7,940.10

3 [SOLAR_HI 138.00] N/A 6,382.80 6,321.40

4 [SOLAR_TAP 138.00] N/A 6,607.50 6,547.80

237500 [BACOLOD 138.00] 7,426.00 8,070.30 7,977.40 7,964.90

237800 [EBMAG1 138.00] 6,397.60 6,533.80 6,501.80 6,433.00

237801 [EBMAG2 138.00] 9,310.00 9,748.00 9,607.20 9,614.40

235501 [BACOLOD 69.000] 9,406.00 9,763.00 9,668.60 9,605.10

237400 [KABANKAL 138.00] 5,609.10 5,627.30 5,634.80 5,554.40

237300 [MAB HI 138.00] 5,648.20 5,602.60 5,625.80 5,538.10

237200 [AMLAN HI 138.00] 8,224.50 8,157.60 8,169.70 8,085.00

237201 [AMLAN SP 138.00] 8,224.50 8,157.60 8,169.70 8,085.00

247100 [BTC VIEJ 138.00] 9,843.20 10,315.00 10,150.80 10,176.40

247700 [CNCPCION 138.00] 9,598.50 9,862.20 9,689.40 9,741.80

247200 [DINGLE 138.00] 10,750.70 10,909.00 10,726.70 10,736.40

Table 18. Short Circuit Rating of Selected Substations in the Grid

Table 19. Short Circuit MVA at Power Plant 138 kV S/S (Peak Loading)


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6. STABILITY ASSESSMENT

Stability analysis assessed the impact of the project to the transient stability

performance of the grid. The analysis was based on the assumptions and methodology

described in the previous sections. The stability plots are included in the Appendices.

The 3-phase faults were applied on transmission line segments followed by

tripping/outage of the segments at normal and delayed clearing times.

The segments where faults were applied are as follows:

1. Fault at Solar Hi-Bacolod 138 kV Line with Tripping

2. Fault at Bacolod-EBMAG1 138 kV Line with Tripping

3.

Fault at Bacolod-EBMAG2 138 kV Line with Tripping4. Fault at Bacolod-Kabankalan 138 kV Line with Tripping

5. Fault at Bacolod 138/69 kV Transformer (T2) with Tripping

6.

Fault at Bacolod-BRGS TAP 69 kV Line with Tripping

7. Fault at Bacolod 138/69 kV Transformer (T1) with Tripping

8. Fault at Kabankalan-Mabinay HI 138 kV Line with Tripping

9.

Fault at Amlan HI-Mabinay HI 138 kV Line with Tripping

Bus faults applied to the system are as follows:

1. Bus Fault at NPHS_HI 138 kV Bus (3)

2. Bus Fault at BACOLOD 138 kV Bus (237500)

3.

Bus Fault at EBMAG1 138 kV Bus (237800)

4. Bus Fault at EBMAG2 138 kV Bus (237801)

5.

Bus Fault at KABANKAL 138 kV Bus (237400)

6 Bus Fault at MAB HI 138 kV Bus (237300)


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In general, the results of the simulation indicated acceptable response of the system

parameters with the proposed facility integrated, damping mostly within the first ten

(10) seconds after the application of fault.

The summary of dynamic stability simulations is shown in Table 20.

Applied Fault

Status of Grid

2016 Base Case 2021 Base Case

Normal

Clearing

Delayed

Clearing

Normal

Clearing

Delayed

Clearing

BUS FAULTS

1.

Bus Fault at NPHS_HI 138 kV Bus (3) Stable Stable Stable Stable

2. Bus Fault at BACOLOD 138 kV Bus (237500) Stable Stable Stable Stable

3.

Bus Fault at EBMAG1 138 kV Bus (237800) Stable Stable Stable Stable

4. Bus Fault at EBMAG2 138 kV Bus (237801) Stable Stable Stable Stable

5. Bus Fault at KABANKAL 138 kV Bus (237400) Stable Stable Stable Stable

6.

Bus Fault at MAB HI 138 kV Bus (237300) Stable Stable Stable Stable

7. Bus Fault at AMLAN SP 138 kV Bus (237201) Stable Stable Stable Stable

8.

Bus Fault at DINGLE 138 kV Bus (247200) Stable Stable Stable Stable

LINE FAULTS

1. Fault at Solar Hi-Bacolod 138 kV Line with TrippingStable Stable Stable Stable

2 F lt t B l d EBMAG1 138 kV Li ith T i i

Table 20. Summary of Dynamic Stability Simulations with Power Plant


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6. Fault at Bacolod-BRGS TAP 69 kV Line with

Tripping Stable Stable Stable Stable

7.

Fault at Bacolod 138/69 kV Transformer (T1) with


8.

Fault at Kabankalan-Mabinay HI 138 kV Line with


9.

Fault at Amlan HI-Mabinay HI 138 kV Line with



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7. FREQUENCY ASSESSMENT

Frequency assessment evaluates if the outage of the proposed power plant will not

cause the frequency to drop below 59.4 Hz frequency limit set by PGC. For 2016 and

2021 base cases, the frequency will not fall as low as 59.4 Hz. The outage of the

proposed power plant will not result to Automatic Load Dropping (ALD). Figure 7

and Figure 8 shows the results of frequency assessments for 2016 and 2021 base cases

respectively.

Figure 7 Frequency Assessment 2016 Peak Base Case


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Figure 8. Frequency Assessment, 2021 Peak Base Case


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8. SUMMARY AND CONCLUSIONS

This study was conducted to assess the impact of the proposed 20 MW Murcia Solar

Project on the reliability, stability and operating characteristics of the Visayas Grid.

Steady state, stability and short-circuit conditions were analyzed. Proposed

connection for this project is a “tapped” connection along Bacolod-NNGPP 138 kV

transmission line.

Steady state assessment with the project in-service showed no significant voltage or

thermal violations of reliability criteria. Considering the priority dispatch of

intermittent RE Generators, thermal loading of elements in the grid will remain within

PGC required limits.

Short circuit analyses concluded that the project did not alter adversely the short

circuit duties of the baseline system.

Transient stability assessment simulated a set of faults. None of the faults tested

showed unstable response of the system with the project integrated.

Frequency assessment showed that the system frequency will not drop as low as 59.4

Hz with the outage of the proposed power plant. Automatic Load Dropping is not

expected during this loss-of-generation scenario.

As a general conclusion, this System Impact Study revealed that the addition of

PHSAC’s Phase I, the 20 MW Murcia Solar Power Project has no significant impact

on the reliability, stability and operating characteristics of the Visayas power

transmission system.

The proposed power plant could be safely and reliably integrated to Visayas grid.

Phase II 40MW of PHSAC project will be implemented once CNP-1 is commissioned

h th i it i th id h th j t f ll t i t d W


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APPENDICES


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Appendix A

2016 Bus Fault Normal Clearing


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Appendix B

2016 Bus Fault Delayed Clearing


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Appendix C

2016 Line Fault Normal Clearing


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Appendix D


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2016 Line Fault Delayed Clearing


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Appendix E



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Appendix F

2021 Bus Fault Delayed Clearing


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Appendix G

2021 Line Fault Normal Clearing


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Appendix H

2021 Line Fault Delayed Clearing


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Appendix I

Power Flow Plots


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2016 Peak Base Case, Normal Loading, Without the Proposed Plant


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2016 Peak Base Case, Normal Loading, With the Proposed Plant


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2021 Peak Base Case, Normal Loading, Without the Proposed Plant


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2021 Peak Base Case, Normal Loading, With the Proposed Plant


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sis psac murcia 20 mw (3)

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