Annex H

Power Development Plan

 Annex H Power Development Plan

Annex H POWER DEVELOPMENT PLAN

Table of Contents
Page
H1 Power Supply.................................................................................................. H-1
H1.1 Power Supply System.......................................................................... H-1
H1.1.1 General ................................................................................ H-1
H1.1.2 Luzon Interconnected System (NPC-TRANSCO) .............. H-1
H1.1.3 Meralco Supply System ....................................................... H-1
H1.1.4 Quezelco Supply Area ......................................................... H-2
H1.2 Power Rates in NPC and Meralco Systems ........................................ H-2
H2 Plan Formulation of Agos Hydropower Scheme .......................................... H-4
H2.1 Concept of Power Scheme ................................................................. H-4
H2.2 Alternative Development Plans........................................................... H-4
H2.3 Power Output Calculation .................................................................. H-4
H2.4 Comparison of Alternative Plans ........................................................ H-5
H2.5 Power Output in the Case of Implementation of Laiban Dam ........... H-6
H3 Plan Formulation of Lagundi Hydropower Scheme ................................... H-8
H3.1 Concept of Power Scheme ................................................................. H-8
H3.2 Proposed Development Plan ............................................................... H-8
H3.3 Power Output Calculation................................................................... H-9
H3.4 Assessment of the Proposed Plan ..................................................... H-10
H4 Planning of Transmission Lines and Substations ........................................H-11
H4.1 Existing Transmission Lines and Substations ....................................H-11
H4.2 Power Transmission Plans................................................................. H-12
H5 Preliminary Design of Power Facilities...................................................... H-17
H5.1 Agos Hydropower Station ................................................................. H-17
H5.1.1 Civil Works ....................................................................... H-17
H5.1.2 Generating Equipment ...................................................... H-17
H5.1.3 Switchyard Equipment ...................................................... H-19
H5.2 Substations ........................................................................................ H-20
H5.2.1 Extension of Dolores Substation ....................................... H-20
H5.2.2 Morong Substation ............................................................ H-20
H5.2.3 New Quezeloco Substation ................................................ H-22
H5.3 Receiving Stations ............................................................................. H-23
H6 Construction Cost Estimate......................................................................... H-24
H6.1 Civil Works and Generating Equipment ........................................... H-24
H6.2 Transformers, Switchyard Equipment and Transmission Lines......... H-24

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 Annex H Power Development Plan

List of Tables
Page
Table H2.1 Results of Power Output Calculation at Agos Power Station................ HT-1
Table H3.1 Results of Power Output Calculation at Lagundi Power Station...............HT-3
Table H6.1 Transmission Lines-Unit Construction Cost ..............................................HT-4
Table H6.2 Substation and Switchyard-Unit Construction Cost ..................................HT-5
Table H6.3 Substation, Switchyard and Transmission Lines- Cost Estimate ...............HT-6

List of Figures
Page
Figure H1.1 General Plan of Power Development Schemes Examined in Plan
Formulation Study ....................................................................................HF-1
Figure H2.1 General Layout Plan and Profile of Agos Hydropower Scheme ...............HF-2
Figure H2.2 General Plan of Agos Afterbay Weir .........................................................HF-3
Figure H3.1 General Layout Plan of Lagundi Hydropower Scheme ............................HF-4
Figure H4.1 Power Transmission and Distribution Plan for the Project........................HF-5
Figure H5.1 Plan and Profile of Agos Powerhouse .......................................................HF-6
Figure H5.2 Layout Plan of Switchyard Equipment......................................................HF-7

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 Annex H Power Development Plan

Annex H POWER DEVELOPMENT PLAN

H1 Power Supply
H1.1 Power Supply System
H1.1.1 General
This Study examines two hydropower schemes at a preliminary study level; Agos
scheme and Lagundi scheme. The generated power is planned to supply to either
the NPC Luzon interconnected system or Meralco distribution system.
Main features of the power supply systems are described in the Master Plan
conducted in 2001 (Refer to Section E5 in Part E of Volume III). The Subsections
below present the latest conditions revealed since that time.
H1.1.2 Luzon Interconnected System (NPC-TRANSCO)
National Transmission Corporation (TRANSCO) operates the nation-wide
interconnected system. TRANSCO is a power transmission company established
recently under the umbrella of NPC. TRANSCO is functioning mainly as a bulk
power supplier to power distribution companies and major industrial customers.
The national interconnected system consists of three main grids, namely Luzon,
Visayas and Mindanao grids, of which the hydropower schemes under this Study
will be connected to the Luzon grid..
Peak power demand of the Luzon grid was 5,557 MW in 2000 and is projected to
increase to some 11,841 MW in 2010 (See Table E4.2 in Part E of Volume III),
which is large enough to receive any scale of power from the proposed scheme.
Energy sale of the Luzon grid was 32,593 GWh in 2000 and is foreseen to increase
to 69,458 GWh in 2010.
The nearest substations are Malaya Gas Turbine Plant and Dolores Substation, both
rated at 230 kV (See Figure H1.1 for the locations).
H1.1.3 Meralco Supply System
As a retail power distributor, Manila Electric Company (Meralco) distributes the
power in its franchise area covering, from north to south, Bulacan Province, Metro
Manila, Rizal Province, Cavite Province, southern part of Quezon Province and the
area around Batang Gas City.
The operating statistics of the Meralco system from 1990 to 2001 are shown in
Table E4.5 of Part E in Volume III. The peak power demand and energy sales
were 4,318 MW and 22,689 GWh in 2001, respectively. As of 2001, Meralco
purchases about 90 % of its power from NPC and the rest from the Meralco’s IPPs.
The Meralco system is also large enough to absorb the power from the planned
hydropower schemes in this Study.
The nearest existing substation is the new Teresa Substation, rated at 115/34.5 kV
(See Figure H1.1 for the location). Further, Meralco has a plan of building a new
115 kV substation near Tanay town within a 5-6 year period. Depending on the

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 Annex H Power Development Plan

scale of the proposed hydropower plant, an alternative solution may be to transmit

the power from the proposed plant directly to the Meralco supply system, if this
Tanay new substation is built.
H1.1.4 Quezelco Supply Area
As a retail power distributor, Quezon Electric Company (Quezelco) is supplying
the power to Infanta-General Nakar-Real area.
(1) Present Power Supply and Demand Conditions
A 69 kV transmission line from Kalayaan Power Station (P/S) supplies the power to
a Quezelco’s Substation (S/S) at Infanta. The substation, equipped with a 3.75
MVA, 69kV/13.2kV transformer, is a load end substation with an average load of
2.7 MW and a peak load of 2.9 MW (3.41 MVA @ 85% power factor). The peak
load represents about 90% of Quezelco’s total substation capacity.
At present, Quezelco is concerned that their present capacity of 3.75 MVA will
exceed the demand within one year. For this reason, Quezelco was going to hold a
Planning Workshop on October 9 to 11, 2002 to tackle their power development
program in the next 5 years.
(2) Quezelco S/S Expansion Program
Quezelco has an average load growth rate of 22 % (about 0.366 MW per annum)
with the highest load growth rate of 30.63% occurring in fiscal year 2001-2002. In
this period, the loading to their 3.75 MVA transformer increased from 2.22 to 2.9
MW. Quezelco’s present peak load of 2.9 MW is expected to grow to 7.83 MW
within a five year period (2007) or more, if the average annual growth rate
increases further due to the recently completed 42 km stretch of road from Famy,
Quezon to Infanta town proper.
The proposed Agos hydropower plant is planned to supply its power also to the
Quezelco system. This will contribute to improve the security of power supply in
the area, since the area presently depends solely on supply from a single power
source (Kalayaan P/S) delivered by a single-circuit 69 kV transmission line.

H1.2 Power Rates in NPC and Meralco Systems

The table below shows historical power rates in the NPC and Meralco systems:

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 Annex H Power Development Plan

Historical Power Rates in NPC and Meralco Systems

Year NPC Luzon Grid Meralco Franchise Area Exchange
Power Tariff to Power Tariff to Purchased Power Cost Rate
Consumers Consumers (Purchase from (Peso/US$)
NPC/IPPs)
1995 1.85 - - 25.7
1996 2.08 - - 26.2
1997 2.29 - - 26.5(29.5)
1998 2.77 - - 40.9
1999 2.84 4.01 2.87 40.3(39.1)
2000 3.31 (Mar.-Dec.) 4.70 3.41 50.0(44.2)
2001 3.87 (Jan.-Mar.) 5.67 4.22 51.7
Increase 16.7 % (1999-2001) 18.9 % (1999-2001) 21.3 % (1999-2001)
Rate 13.1 % (1995-2001)
Sources: 1) NPC Annual Reports, 1999 and 2000, NPC
2) Effective Rates for Luzon Grid, March 2000-March 2001, NPC
3) Meralco Annual Reports, 2000 and 2001, Meralco
NPC has no clear-cut criteria for the price of power purchase from the IPPs, which
would, according to NPC, be determined through negotiation on individual project
basis (as of 2001). With the passage of RA9136-Electricity Industry Reform Act of
2001 and its IRR, NPC is bared from incurring obligations to purchase power from
generation companies and other suppliers. Henceforward, TRANSCO is deemed to
be the purchaser of power.
In the financial study for Laiban Dam project conducted in 1997, unit selling price
was assumed as Peso 2.0/kWh (equivalent to US Cent 7.5/kWh in 1997). In the
Master Plan Study in 2001, it was assumed as Peso 2.5/kWh (US Cent 4.8/kWh) by
escalating the rate assumed in the Laiban Dam project at 5 % per annum.
The above table indicates that unit selling price has increased at a high rate during
these 3 years. With the current prices in view, it may still be on a conservative side
to assume that the selling price would not be less than Peso 3.5/kWh (US Cent
6.7/kWh) in the case of selling to NPC-TRANSCO system and Peso 4.0/kWh (US
Cent 7.7/kWh) in the case of Meralco system, respectively, at 2002 price. The
Study was carried out using these rates in assessing the financial viability of the
proposed hydropower development schemes.

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 Annex H Power Development Plan

H2 Plan Formulation of Agos Hydropower Scheme

H2.1 Concept of Power Scheme

Construction of the Agos Dam will provide a potential of hydropower development,
where a head of about 100 m is created. With an effective storage capacity of 409
million m3, Agos Reservoir can yield 62.4 m3/sec of water throughout a year, of
which 34.7 m3/sec (equivalent to 3,000 MLD) is conveyed to Metro Manila for
water supply in the final stage. The remaining 27.7 m3/sec (including 4.35 m3/sec
of river maintenance discharge) can be used for hydropower generation until such
time when further water allocation for water supply purpose is required in the long
future.
A basic principle to be assumed here is that, once hydropower scheme is included
in the Agos Dam development plan, it should be afforded to have a concession
period of at least 25 years for operation. The 25-year period is deemed to be a
minimum period to make the power scheme economically and financially viable.
General plan and profile of the proposed Agos power scheme is shown in Figure
H2.1. The plant will be built at the time of constructing the Agos Dam.

H2.2 Alternative Development Plans

The power supply system, whatever it is NPC-TRANSCO Luzon grid or Meralco
system, can absorb any type of power generation from the proposed Agos scheme.
From the aspect of load characteristics, the system may require the scheme to be
preferably a peaking plant in order to use the merit of hydropower plant. With this
in view, the following four (4) alternative plans were examined:
Formulation of Alternative Plans
Maximum Plant Discharge/1 Need of Afterbay Weir for
Alternative Remarks
(m3/sec) Flow Re-regulation
Equivalent to 6-hour
A 110.8 With Afterbay Weir
peaking operation
Equivalent to 8-hour
B 83.1 With Afterbay Weir
peaking operation
Equivalent to 12-hour
C 55.4 Without Afterbay Weir
semi-peaking operation
Principally, 24-hour
D 27.7/2 No need of Afterbay Weir
base-load operation
Notes: /1; Maximum plant discharge at Rated Water Level (RWL)
/2; Selected through trial calculation so that average turbine flow would be 26.3 m3/sec
Alternative Plans A and B require an afterbay pond for re-regulation of peaking
discharges. An afterbay weir is proposed about 8 km downstream of the Agos Dam
site. A preliminary plan of the afterbay weir is shown in Figure H2.2.

H2.3 Power Output Calculation

Using 31-year hydrological data, power outputs for the four alternative plans were
calculated based on the following criteria:

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 Annex H Power Development Plan

(a) Power output calculation formula:

P= 9.8 xǯx Q x He
where, ǯ: Power generation efficiency, variable by Q and H
Q: Turbine discharge, variable by reservoir water level
He: Effective head, variable by Q

(b) Basic Operating Conditions:

- Full Supply Level (FSL): EL.159.0 m
- Rated Water Level (RWL): EL.152.5 m (Upper 1/4 of darwdown
depth)
- Minimum Operating Level (MOL): EL.133.0 m
- Tailwater Level (TWL): EL.41.8m, EL.41.6m, EL.41.5m, EL.
41.2m in Alt. A, B, C, D,
respectively
(c) Diameters of power waterway were determined for each alternative based
on empirical formulae used in Japan.
(d) A unique aspect in the scheme is a relatively large variation of turbinable
discharge, effective head and generation efficiency, all varying by reservoir
water level. This aspect was taken into account in the calculation as stated
above.
(e) Rated Water Level (RWL) was selected at a water level corresponding to the
upper 1/4 level of the reservoir drawdown depth, i.e. EL. 152.5 m. Design
head of turbine was determined at this hydraulic condition.
The results of calculation are summarized below and the details are given in Table
H2.1:
Results of Power Output Calculation for alternative Development Plans
Installed 90% Annual Energy Generation (GWh) Yearly
Capacity Dependable
Alternative Plant
(MW) Power Output Primary Secondary Total Factor
(MW)
A 103.4 85.9 216.1 253.3 469.4 0.52
B 77.5 64.4 216.0 186.8 402.8 0.59
C 51.5 42.7 215.3 102.9 318.2 0.70
D 25.6 21.1 213.3 0.0 213.3 0.95
Notes: 1. Plant Factor = Total Energy/(Installed Capacity x 24 hrs x 365 days)
2. Dependable power used for economic evaluation is taken at 90 % guaranteed power.

H2.4 Comparison of Alternative Plans

Comparison of 4 alternative plans is primarily based on economic evaluation.
Economic benefit was taken from alternative thermal power cost. The result is
summarized below:

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 Annex H Power Development Plan

Comparison of Economic Viability of Alternative Developme nt Plans

(Monetary Unit: US$ Million)
/2
/1 NPV of Cost NPV of Benefit/3 Net Benefit
Alternative Construction Cost EIRR (%)
(C) (B) (B-C)
A 159.0 120.9 120.0 -0.9 11.8
B 139.4 98.6 98.6 -7.3 10.3
C 81.2 68.8 68.8 6.3 14.6
D 58.5 40.1 40.1 -4.9 9.6
Notes: /1 The above costs show economic costs based on 2002 market prices, covering the
costs of intake, waterway, powerhouse, generating equipment, switchyard, afterbay
weir (for Alternative A and B), transmission line and substation.
/2 Annual O&M cost at 0.5 % of civil works capital cost and 2.5 % of
electrical/mechanical works capital cost
/3 As the alternative thermal costs, costs of combined-cycle plant are assumed as
follows (See Section E5 in Part-E of Volume III):
- kW Value: Capital Cost = US$ 700/kW, Fixed O&M Cost = US$ 28.65/kW
- kWh Value: US$ 0.0217/kWh
- Adjustment Factor: 1.279 for kW value and 1.061 for kWh value
4) Economic costs and benefits are discounted at 12 % per annum.
5) Abbreviations NPV: Net Present Value
EIRR: Economic Internal Rate of Return

Since the Agos power scheme is proposed to be implemented under a BOT contract,
the most important evaluation factor is the financial viability. Hence, the
comparison was also made from financial aspect. The result is shown below:
Comparison of Financial Viability of Alternative Development Plans
Construction Cost
Alternative FIRR (%) ROE (%) WACC (%)
(US$ million)
A 239.7 22.6 32.8 15.8
B 210.2 21.4 30.7 15.1
C 121.9 25.6 38.5 17.9
D 87.8 19.5 28.3 14.3
Notes: 1) The above financial costs are based on 2002 market prices, covering costs of
intake, waterway, powerhouse, switchyard, afterbay weir (for Alt. A and B),
transmission line and substation. The costs are escalated at 2 % per annum
for F/C portion and 3 % for L/C portion, respectively
2) Annual O&M cost at 0.5 % of civil works capital cost and 2.5 % of
electrical/mechanical works capital cost
3) VAT of 10% is applied.
4) Unit power selling price is assumed to be Peso 3.5/kWh at 2002 price, which is
escalated at 3 % per annum
4) Discounted at 12 %
5) Abbreviations FIRR : Financial Rate of Return
WACC : Weighted Average Cost of Capital
ROE : Return of Equity
As indicated in the tables above, the Alternative Development Plan C is found to be
the most attractive from both economic and financial viewpoints. Therefore, the
Alternative Development Plan C is selected as the most viable development scale
for the Agos power scheme.

H2.5 Power Output in the Case of Implementation of Laiban Dam

MWSS contemplates the implementation of Laiban Dam either prior to or after the
Agos Dam. In this case, a 1,830 MLD (21.2 m3/sec) of water is conveyed to Metro

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 Annex H Power Development Plan

Manila being taken upstream of the Agos Dam. This implies the reduction of inflow
to the Agos reservoir and accordingly the available discharges for power
generation.
Power output of Alternative Plan C for the case after the completion of Laiban Dam
was calculated as shown in the table below:
Power Output in the Case of Implementation of Laiban Dam
Phase Water Supply Water Supply Discharge Annual Energy production (GWh)
from Laiban from Agos Available for
Dam Dam Power Primary Secondary Total
(m3/sec) (m3/sec) (m3/sec)
Case-1 21.2 17.35
24.0 192.03 96.17 288.20
(1,830MLD) (1,500MLD)
Case-2 21.2 34.7
6.5 52.73 28.43 81.16
(1,830MLD) (3,000MLD)
Note: Installed Capacity: 51.5 MW (Alternative Plan C)
Case-1: Water supply meeting the demand level of around Year 2025
Case-2: Additional water supply of 1,500 MLD at Agos (in the case of future expansion)
As shown above, energy production at the Agos power plant is much reduced,
particularly in the case water supply from Agos Dam is expanded to 3,000 MLD.
Nevertheless, even under this condition, the plant can be operated at a reduced
capacity as a base-load plant (25.6 MW) or as a semi-peaking plant (51.5 MW
peak) by using the residual discharges including the river maintenance flow of 4.35
m3/sec.

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 Annex H Power Development Plan

H3 Plan Formulation of Lagundi Hydropower Scheme

H3.1 Concept of Power Scheme
Construction of Lagundi power plant is conceivable at the downstream end of No.1
Tunnel to harness the head available between Agos Reservoir and the power plant.
The proposed plan, however, has the following constraints due to the particular
nature of the scheme:
(a) Power generation has to be made using the predetermined discharges
delivered according to water supply demand. The discharge is supposed to
fluctuate daily in a range ofr of the daily average discharge. This
means that the plant cannot yield a constant rate of power, though it is
basically a 24-hour generation plant.
(b) No.1 Tunnel has a length of 27 km, where loss head is quite large in the
order of 30 m at the maximum discharge. The effective head is almost nil
under the conditions of MOL (minimum operating level) in the reservoir
and the maximum discharge in the tunnel (42 m3/sec by 2 tunnels).
Moreover, power generation is not possible when the effective head is less
than 65 % of the turbine design head due to the characteristics of the turbine.
These imply that there would be interruption of power generation for certain
periods in the dry season when the reservoir water level becomes low.
Owing to the above two constraints, the attractiveness of the Lagundi power
scheme is supposed to be limited. Nevertheless, studies described below were made
to examine any possibility of justifying the scheme.
General layout plan of the proposed Lagundi Power plant is shown in Figure H3.1.
The plant will be constructed when the 2nd tunnel of Tunnel No.1 is built at the
Stage 2-2 of the Project implementation.

H3.2 Proposed Development Plan

As shown in Figure G2.1, there are two (2) alternative plans with regard to the
layout of the downstream part of Tunnel No.1. One is with the Lagundi power plant
and the other without the plant.
In the case of the former plan, additional facilities specifically required for the
construction of the power plant are the incremental lengths of Tunnels No.1 and
No.2, surge tanks, penstocks, a powerhouse, a switchyard and a transmission line to
a substation at the water treatment plant. The cost thereof should be born by the
Lagundi power scheme. Provision of valve houses is common to both the
alternative plans.
With regard to power generation, no alternative plan is conceivable since both the
discharges and operating heads are the given conditions determined by water
supply scheme. Basic features of the proposed plan are as follows:

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 Annex H Power Development Plan

- Daily average discharge: 34.7 m3/sec (3,000 MLD for water supply), at the
final stage of water supply project
- Maximum discharge: 42.1 m3/sec (1.21 times the average discharge,
corresponding to day peak discharge for water
supply)
- Turbinable Head: 65-125 % of turbine design head (corresponding to
EL.145.0-159.0 m in terms of the reservoir water
level)

H3.3 Power Output Calculation

Using 31-year hydrological data, power outputs for the four alternative plans were
calculated based on the following criteria:
(a) Power output calculation formula: See Subsection H2.3 above
(b) Basic Operating Conditions: as shown in the table below:

Item Power Operating Condition

Full Supply Level (FSL) EL.159.0 m (correspond to turbinable head 125 %)
Rated Water Level (RWL) EL.153.2 m (correspond to turbinable head 100 %)
Operational Low Water Level EL.145.0 m (correspond to turbinable head 65 %)
Minimum Reservoir Level (MOL) EL.133.0 m (No power generation)
Tailwater Level (TWL) EL.99.5 m
(c) A unique aspect in this scheme is that effective head, and accordingly power
output varies greatly by discharge. A trial calculation revealed that larger
power output is available under the flow condition at daily average
discharge, rather than at the maximum discharge as shown in the table
below:
Power Output by Daily Average Discharge to be Conveyed to Metro Manila
Discharge Loss Head Effective Head at RWL Power Output
34.7 m3/sec 22.0 m 31.7 m 9.3 MW
42.1 m3/sec 31.9 m 21.8 m 6.4 MW

This suggests that installed capacity of the plant should better be determined
at the daily average discharge for water supply (34.7 m3/sec), which is
regarded as the maximum plant discharge for the power scheme. In this case,
discharges larger than 34.7 m3/sec will be released through by-pass valves.
(d) At present stage, the exact features of daily fluctuation of discharges for
water supply are not known. Hence, the power output calculation was made
assuming the discharge to be constant at the rate of daily average discharge.
Instead, energy production was assessed to be 80 % of the calculated figure
in order to incorporate the loss of energy production due to by-passing of
flow larger than 34.7 m3/sec.
The result of power output calculation is shown below:

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 Annex H Power Development Plan

Calculated Power/Energy Production of Lagundi Power Plants

Item Power/Energy Production
- Installed capacity 10.6 MW
- 90 % dependable power output 5.65 MW
- Annual Energy Production 78.0 GWh (regarded all as primary energy)
- Interruption of power generation 92 % of time

The details of the calculation are presented in Table H3.1.

H3.4 Assessment of the Proposed Plan

The viability of the scheme was assessed through financial analysis under the
following conditions:
(a) Construction costs cover the incremental lengths of Tunnel No.1 and
No.2, surge tanks, penstocks, powerhouse, generating equipment, a
switchyard and transmission line, estimated at US$ 20.1 million
equivalent
(b) Annual O&M costs at 0.5 % of civil works capital cost and 2.5 % of
electrical and mechanical works capital cost
(c) Power revenue is Peso 3.5/kWh at 2002 price, which is escalated at 3 %
per annum in the cash flow analysis.
The results of the financial analysis show that net return becomes negative value at
U$ 29.4 million in the present worth and a FIRR of 5.3 %. Relatively low figures of
the both items are due to high burden of costs for waterway and low energy
production due to large head loss in the waterway.
The results suggest that the scheme is not justifiable from the financial viewpoint.
Further, the relatively long interruption of power generation makes the
attractiveness of the scheme lesser.
Hence, the Lagundi power scheme was ruled out from the plan formulation of the
Project.

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 Annex H Power Development Plan

H4 Planning of Transmission Lines and Substations

H4.1 Existing Transmission Lines and Substations
(1) Malaya Substation
TRANSCO Malaya Substation (S/S) is situated in the complex of Malaya
Gas-Turbine Power Station (P/S), which is now privatized and owned by Kephilco,
a Korean firm. The location is shown in Figure H1.1.
Malaya S/S is a 230 kV switching facility, and it has no 69 kV bus. Malaya S/S is
directly connected to Dolores S/S via the existing 230 kV double circuits, bundle of
4 x 795 ACSR conductors, with a total length of 39 km. There are now two 230 kV
feeders available at Malaya S/S, as the Malaya Gas Turbine P/S is no longer
allowed by the government to operate due to its high operating cost.
Malaya S/S can accommodate one additional bay to receive a 230 kV double circuit
transmission line from the proposed Agos power plant. However, Figure H1.1
shows that Malaya S/S is not an ideal interconnecting point for the Agos power
station as it is farther than Dolores S/S.
(2) Dolores S/S
Dolores S/S can accommodate one additional bay to introduce the 230 kV double
circuit transmission line from the proposed Agos power plant, but like Malaya S/S,
it has no 69 kV bus. Dolores S/S has an old substation site adjacent to the Dolores
S/S. The old substation site has an enough area to accommodate a 2 to 3 bay 230
kV 1-1/2 breaker scheme substation. The additional feeder bay will be provided in
the old substation area. Since the ground level of old substation site is a few meter
higher than the present Dolores S/S area, the work will require the excavation of a
part of the old substation site.
(3) TRANSCO Trunk Transmission Lines
Both the Malaya S/S and Dolores S/S could properly convey to Manila the
additional power coming from the proposed Agos power plant through the existing
transmission lines. In the area, the backup 500kV transmission lines to San Jose
Del Monte, Bulacan, is now fully operational. This makes, in the section between
Malaya and Dolores, the reduction of load for the existing 4 x 795 ACSR, 39 km
double-circuit 230kV Malaya-Dolores transmission line. Based on recent load flow
studies, the load of Malaya-Dolores line is now only 150 MW (about 175 MVA),
which is far below its rated capacity of 1,320 MVA.
(4) Meralco New Teresa S/S
New Teresa S/S is a Meralco 115 kV switching station connected to 115 kV Malaya
S/S by a double circuit transmission line and to 115 kV Dolores S/S by a single
circuit transmission line. It has no 69 kV bus and the only available tapping point
for the proposed Water Treatment Plant S/S is 34.5 kV bus. The 34.5 kV bus is
connected by an 8.3 MVA 115/34.5/13.8 kV three winding transformer. The 8.3
MVA transformer is serving several municipalities around New Teresa S/S. This

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 Annex H Power Development Plan

S/S has no sufficient space for accommodating an additional double-circuit

incoming line.
No attempt was made to determine the loading of the 115 kV transmission lines
since Dolores S/S is a better alternative.
(5) Quezelco Substation
The existing 3.75 MVA 69 kV Quezelco S/S is a far contrast from its main property
as it was erected in an area of only 450 m2. It is not possible to expand this
existing substation to accommodate an additional 69 kV feeder from the proposed
Agos power plant because of the very limited space and further it is located in a
residential area with all surrounding lots already occupied.
On one hand, Quezelco has its main office and stockyard of 2 ha area, situated
about 8 km from the existing 69 kV substation. Quezelco agreed to relocate the
existing substation to their 2 ha property, provided Agos power project (Stage 2-1
project) would fund the procurement and installation of all 69 kV equipment and
accessories for the new switching facilities.
A 69 kV transmission line from Agos power plant must therefore consider the new
site for Quezelco S/S.

H4.2 Power Transmission Plans

(1) Main Receiving Substation
Comparing the existing substations as stated above, this Study assumes that main
receiving substation is Dolores Substation in consideration of the following:
- Dolores S/S presently functions as a key substation for the supply network
in the area
- It is proximity to the Morong Water Treatment Plant (WTP), where a local
substation for the distribution of power to various waterway facilities is
proposed
As stated in the foregoing Section H1.1, Meralco has a plan of constructing a new
substation near Tanay town in the Municipality of Tanay within 5-6 years. Taking a
merit of proximity to the Agos site, this Tanay S/S may be an alternative tapping
point for receiving the power from the Agos power plant. Nevertheless, this
alternative plan is regarded as a plan to be further studied in the subsequent stage.
In the present Study stage, the assumption of the Dolores S/S is more conservative
in terms of estimating the project cost.
(2) Power Supply to Waterway Facilities
Water supply project envisages the construction of various waterway facilities
needing the supply of power for operating the plant and equipment. The major
facilities are (i) Kaliwa Low Dam and Intake, (ii) Morong Water treatment Plant
(WTP), (iii) a Valve House at bifurcation of waterways to Antipolo and Tayatay,
(iv) Antipolo Pump Station, (v) Antipolo Service Reservoirs and (vi) Taytay

H-12
 Annex H Power Development Plan

Service Reservoirs. Power requirement at these facilities is roughly estimated as

follows:
Power Requirement at Waterway Facilities
Power Required (kW)
Facility
Stage 1 Final Stage
Kaliwa Low Dam 20 30
Morong Water Treatment Plant 1,200 3,600
Valve House at Bifurcation Point 10 20
Antipolo Pump Station 2,500 13,500
Antipolo Service Reservoir 10 20
Taytay Service Reservoir 40 120
Total 3,780 17,290
Power transmission plan shown in (3) below will take into account the supply of
power to these facilities.
(3) Power Transmission Plan
The proposed project envisages the implementation in three (3) stages.
- Stage 1: Construction of Kaliwa Low Dam and 1st Kaliwa-Taytay Waterway:
At this stage, power for waterway facilities will be supplied from the
existing Dolores S/S.
- Stage 2-1: Construction of Agos Dam with Agos power plant: Power from the
Agos power plant will be interconnected to the Luzon Grid as well
as to the power supply system for waterway facilities. Power will
also be sent to Quezelco S/S in Infanta.
- Stage 2-2: Construction of 2nd Kaliwa-Taytay Waterway
Following the above overall schedule, the implementation of power transmission
and distribution facilities is proposed as shown in Figure H4.1 in the form of main
single line diagram. The Figure shows the proposed power transmission system at
the respective stages of the implementation as described hereunder.
Stage 1:
The Stage 1 requires the construction of the following power transmission facilities
for power supply to the water treatment plant, pump station and other water service
facilities.
(a) Extension of the existing Dolores S/S for additional 230 kV bays to
introduce a 230 kV double-circuit transmission line described in (b)
below.
(b) Construction of a 15.6 km long 230 kV double-circuit transmission line
between the existing Dolores S/S and a new 230 kV substation described
in (c) below.
(c) Construction of a new 230 kV substation at the Morong Water Treatment
Plant (hereinafter referred to as “Morong S/S”).
The Morong S/S will be developed in stage-wise to meet expansion plan
of the waterway facilities. In Stage 1, the following equipment will be

H-13
 Annex H Power Development Plan

installed in the Morong S/S:

- One 230/34.5/13.8 kV, 12.5/10/2.5 MVA step-down transformer
- One 13.8/0.48 kV station-service transformer
- 230 kV switchgear for a step-down transformer primary circuit and two
transmission line circuits
- 34.5 kV switchgear for a step-down transformer secondary circuit and a
distribution line circuit
- 13.8 kV switchgear for a step-down transformer tertiary circuit, three
distribution line circuits and a station-service transformer circuit
- One lot of low voltage switchgear
- Control and protection equipment for the above equipment
The proposed step-down transformer will have a sufficient capacity to
supply power to the various waterway facilities to be developed at the
Stage 2-1.
(d) Construction of the following 34.5 kV distribution lines
- 34.5 kV distribution line of 5.8 km long between Morong S/S and
Antipolo Pump Station
- 34.5 kV distribution line of 2.0 km long between Antipolo Pump
Station and Antipolo Service Reservoirs
(e) Construction of the following 13.8 kV distribution lines
- 13.8 kV distribution line of 30.6 km long between Morong S/S and
Kaliwa Low Dam
- 13.8 kV distribution line of 4.7 km long between Morong S/S and Valve
House
- 13.8 kV distribution line of 6.5 km long between Valve House and
Taytay Service Reservoir
Stage 2-1:
Agos Hydropower Plant will be developed in Stage 2-1.
The Agos P/S will be interconnected with the Luzon Grid at Morong S/S via 230
kV double-circuit transmission line as well as Quezelco Substation in Infanta via 69
kV single-circuit transmission line.
The development of the Agos P/S requires the construction of the following power
transmission facilities.
(a) Construction of Agos Switchyard to arrange the following equipment.
- 230 kV switchgear for two generator transformer circuits, a transformer
primary circuit and two transmission line circuits

H-14
 Annex H Power Development Plan

- One 230/69/13.8 kV, 12.5/10/2.5 MVA step-down transformer

- 69 kV switchgear for a step-down transformer secondary circuit
- 13.8 kV switchgear for a step-down transformer tertiary circuit
(b) Construction of a 230 kV double-circuit transmission line of 37.0 km
long between Agos P/S and Morong S/S.
(c) Extension of the Morong S/S for additional 230 kV bays to introduce a
230 kV double-circuit transmission line described in (b) above.
(d) Construction of a 69 kV single-circuit transmission line of 14.0 km long
between Agos P/S and Quezelco S/S in Infanta.
(e) Construction of the New Quezelco S/S to introduce a 69 kV single-circuit
transmission line from the Agos P/S. After completion of the New
Quezelco S/S, all functions of the existing Quezelco S/S are to be
transferred to the New S/S.
Stage 2-2:
The Stage 2-2 requires extension of the Morong S/S to increase the power supply
capacity to meet the expansion plan of the water treatment plant, pump station and
other water service facilities.
The extension of the Morong S/S will be carried out for the following additional
equipment.
(a) One 230/34.5/13.8 kV, 12.5/10/2.5 MVA step-down transformer
(b) 230 kV switchgear for the primary circuit of additional step-down
transformer
(c) 34.5 kV switchgear for the secondary circuit of additional step-down
transformer
(d) 13.8 kV switchgear for the tertiary circuit of additional step-down
transformer
(e) Control and protection equipment for the above additional equipment
(4) Concepts of the Proposed Transmission Plan
Figure H4.1 shows the least cost solution for the interconnection of the proposed
hydroelectric plants to the Luzon Grid. Aside from its lower cost, this scheme was
selected because of its simplicity and reliability to provide continuous power
supply to various facilities inside the waterway complex. The advantages derived
from the scheme shown are summarized as follows:
(a) Two separate power sources are available for the power supply to the
waterway facilities, i.e. from Dolores S/S and Agos power plant.
Continuous supply to the waterway facilities is assured even when either
one power source is out of service.
(b) The system is not dependent on New Teresa S/S, which is a switching

H-15
 Annex H Power Development Plan

station. At this station, only available interconnecting point is either to its

34.5 kV or 13.8 kV bus, which is supplied by a single 8.3 MVA
115/34.5/13.5 kV distribution transformer.
(c) Only three metering systems are required for simplifying tariff
computation. They are between Agos power plant and Dolores S/S, and
between Agos power plant and Infanta Quezelco S/S. Dolores S/S was
selected as the tapping point for Agos 230 kV transmission lines, since it
is nearer than Malaya S/S as shown in Figure H1.1, which depicts all the
proposed transmission and distribution line routes.
(d) The 230 kV S/S at the Morong Water Treatment Plant is convenient not
only for power distribution to the various water service facilities but also
for interconnection between Agos P/S and Luzon Grid.
(e) Less costly as compared with the other alternative interconnection
schemes examined earlier in this study.

H-16
 Annex H Power Development Plan

H5 Preliminary Design of Power Facilities

H5.1 Agos Hydropower Station
H5.1.1 Civil Works
The general layout plan and profile of the proposed Agos powerhouse are shown in
Figure F4.3 in Annex F of Volume V and Figure H5.1, respectively. This
Subsection H5.1.1 summarizes the civil works required for constrcution of the
Agos hydropower station, while Annex F of this Volume V discusses the
comparison study of the alternative power waterway routes as well as the
dimensions of the proposed structures for the Agos power station.
(1) Power Intake
Power intake and associated waterway are built on the left bank. The intake will
feed the maximum plant discharge of 55.4 m3/sec, which includes the minimum
river maintenance discharge of 4.35 m3/sec to be released to the downstream reach.
The intake is of a lateral vermouth type with sill elevation at EL.120 m. The inlet
openings are equipped with screens, but no raking devices are provided since it is
deep from the reservoir operating levels. A closure gate is provided in a shaft built
at some 148 m from the intake.
(2) Power Waterway
Water is to be fed into a power waterway of 755m in total length. It comprises
intake structure, concrete-lined headrace tunnel of 5.9m in diameter and 535m long
in the upstream part and a steel-lined penstock of 5.4m in diameter and 212m long.
In view of a moderate length of the waterway, no surge tank is provided.
(3) Powerhouse
Powerhouse is of conventional type above-ground construction with dimensions of
roughly 48m wide, 34m long and 47m high. It accommodates two units of turbines
and generators with a total installed capacity of 51.5 MW. Two generator
transformers are installed at the outside behind the powerhouse.
(4) Switchyard
A switchyard is built at the toe of dam at EL.55 m. The switchyard is of
conventional, outdoor open type bus-and-switch arrangement for 230 kV
switchgear, a 230/69/13.8 kV transformer, 69 kV switchgear and 13.8 kV
switchgear. The switchyard has three outgoing feeders, that is, a 230 kV
double-circuit transmission line to the Morong S/S, a 69 kV single-circuit
transmission line to the New Quezelco S/S and a 13.8 kV distribution line to the
After Bay. The required area of land is roughly 100 m by 150 m.
H5.1.2 Generating Equipment
(1) Operating Conditions
As described in the foregoing Section H2.3, the operating conditions for the
generating equipment are summarized below:

H-17
 Annex H Power Development Plan

(a) Rated water level of Agos reservoir: EL. 152.5 m

(b) Maximum plant discharge: 55.4 m3/sec
(c) Tailrace water level at maximum plant discharge: EL. 41.5 m
(d) Rated head: 111.0 m
(2) Number of Units
Two units layout was selected to provide flexibility and redundancy in operation of
the generating equipment in preparation for unit shutdown due to unforeseeable
accident and periodical maintenance.
(3) Type of Turbine and Generator
Vertical-shaft Francis turbine is an optimum type of hydraulic turbine for rated head
of 111.0 m and unit discharge of 27.2 m3/s.
The generator is of vertical-shaft synchronous alternator with salient pole revolving
field. Both semi-umbrella type and suspended type are applicable to the generator
for rated output of 29.6 MVA and rated rotational speed of 400 rpm. As a result of
comparative study, semi-umbrella type is selected because it is advantageous to
plant civil work design due to smaller dimensions and lower lifting height.
(4) Principal Features of Generating Equipment
Principal features of the generating equipment are summarized as follows:
(a) Number of units : 2
(b) Hydraulic turbines
- Type : Vertical-shaft Francis turbine
- Rated unit discharge : 27.2 m3/s
- Rated output : 27,400 kW
- Rated speed : 400 rpm
(c) Generators
- Type : Vertical-shaft, semi-umbrella type,
synchronous alternator
- Rated output : 29,600 kVA
- Rated voltage : 11 kV
- Rated frequency : 60 Hz
- Rated power factor : 0.9 lagging
(d) Generator transformers
- Type : Three-phase, oil-immersed, ONAF,
with off-circuit tap changer
- Rated power : 29,600 kVA
- Rated voltage ratio : 11/230 kV

H-18
 Annex H Power Development Plan

H5.1.3 Switchyard Equipment

The switchyard is of conventional, outdoor open type bus-and-switch arrangement.
Figure H5.2 shows a preliminary layout plan of the switchyard equipment.
(1) Main Bus Connections
The 230 kV main bus employs a breaker-and-a-half scheme (one and a half
breakers per circuit) that is the same scheme as the existing 230 kV substations of
the Luzon Grid. Meanwhile, the 69 kV and 13.8 kV buses employ a single-bus
scheme.
(2) Principal Features of Switchyard Equipment
The principal features of the switchyard equipment are summarized below:
(a) Step-down Transformer
- Type : Three-phase, oil-immersed, ONAN,
with on-load tap changer
- Rated power : 12,500/10,000/2,500 kVA
- Rated voltage ratio : 230/69/13.8 kV
- Rated frequency : 60 Hz
(b) 230 kV Switchgear
- Type : Outdoor use, conventional type
- Highest system voltage : 245 kV
- Rated insulation level
Lightning impulse : 950 kV
Power-frequency : 395 kV
- Rated frequency : 60 Hz
(c) 69 kV Switchgear
- Type : Outdoor use, conventional type
- Highest system voltage : 72.5 kV
- Rated insulation level
Lightning impulse : 325 kV
Power-frequency : 140 kV
- Rated frequency : 60 Hz
(d) 13.8 kV Switchgear
- Type : Outdoor use, conventional type
- Highest system voltage : 15 kV
- Rated insulation level
Full-wave lightning impulse : 110 kV
Power-frequency : 50 kV
- Rated frequency : 60 Hz

H-19
 Annex H Power Development Plan

H5.2 Substations
H5.2.1 Extension of Dolores Substation
(1) Layout
The existing 230 kV Dolores S/S is of conventional, outdoor open type
bus-and-switch arrangement and its 230 kV main bus employs a breaker-and-a-half
scheme (one and a half breakers per circuit).
The Dolores S/S is extended for additional 230 kV bay with three circuit breakers,
which is arranged for a breaker-and-a-half scheme, to introduce a 230 kV
double-circuit transmission line coming from the Morong S/S.
(2) Principal Features of Equipment for Substation Extension
Principal features of the equipment for substation extension are summarized as
follows:
(a) 230 kV Switchgear
- Type : Outdoor use, conventional type
- Highest system voltage : 245 kV
- Rated insulation level
Lightning impulse : 950 kV
Power-frequency : 395 kV
- Rated frequency : 60 Hz
H5.2.2 Morong Substation
(1) Layout
The Morong S/S is designed for conventional, outdoor open type bus-and-switch
arrangement and the required area of land is roughly 100 m by 150 m to arrange
two 230/34.5/13.8 kV transformers, six 230 kV circuits, three 34.5 kV circuits, six
13.8 kV circuits and one 13.8/0.48 kV station-service transformer, as shown in
Figure H4.1.
(2) Main Bus Connections
The 230 kV main bus employs a breaker-and-a-half scheme (one and a half
breakers per circuit) that is the same scheme as the existing 230 kV substations of
the Luzon Grid. Meanwhile, the 34.5 kV and 13.8 kV buses employ a single-bus
scheme.
(3) Development Plan
The Morong S/S is developed in the following three stages.
(a) In Stage 1
- One 230/34.5/13.8 kV, 12.5/10/2.5 MVA step-down transformer
- One 13.8/0.48 kV station-service transformer

H-20
 Annex H Power Development Plan

- 230 kV switchgear for a step-down transformer primary circuit and two

transmission line circuits towards Dolores S/S
- 34.5 kV switchgear for a step-down transformer secondary circuit and a
distribution line circuit
- 13.8 kV switchgear for a step-down transformer tertiary circuit, three
distribution line circuits and a station-service transformer circuit
- One lot of low voltage switchgear
- Control and protection equipment for the above equipment
(b) In Stage 2-1
- Extension of 230 kV bay to arrange 230 kV switchgear for two
transmission line circuits towards Agos P/S.
(c) In Stage 2-2
- Additional installation of one 230/34.5/13.8 kV, 12.5/10/2.5 MVA
step-down transformer
- Additional installation of 230 kV switchgear for an additional
step-down transformer primary circuit
- Additional installation of 34.5 kV switchgear for an additional
step-down transformer secondary circuit
- Additional installation of 13.8 kV switchgear for an additional
step-down transformer tertiary circuit
- Control and protection equipment for the above equipment
(3) Principal Features of Substation Equipment
Principal features of the substation equipment are summarized as follows:
(a) Step-down Transformer
- Type : Three-phase, oil-immersed, ONAN,
with on-load tap changer
- Rated power : 12,500/10,000/2,500 kVA
- Rated voltage ratio : 230/34.5/13.8 kV
- Rated frequency : 60 Hz
(b) 230 kV Switchgear
- Type : Outdoor use, conventional type
- Highest system voltage : 245 kV
- Rated insulation level
Lightning impulse : 950 kV
Power-frequency : 395 kV
- Rated frequency : 60 Hz

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 Annex H Power Development Plan

(c) 34.5 kV Switchgear

- Type : Outdoor use, conventional type
- Highest system voltage : 38 kV
- Rated insulation level
Lightning impulse : 150 kV
Power-frequency : 70 kV
- Rated frequency : 60 Hz
(d) 13.8 kV Switchgear
- Type : Outdoor use, conventional type
- Highest system voltage : 15 kV
- Rated insulation level
Full-wave lightning impulse: 110 kV
Power-frequency : 50 kV
- Rated frequency : 60 Hz
H5.2.3 New Quezeloco Substation
(1) Layout
The New Quezelco S/S is designed for conventional, outdoor open type
bus-and-switch arrangement and the area of land is about 2 hectare which is
sufficient to arrange one 69/13.8 kV transformer, 69 kV switchgear and 13.8 kV
switchgear. In addition to the existing 69 kV transmission line, another 69 kV
transmission line coming from the Agos P/S is connected to this new substation.
(2) Main Bus Connections
The 69 kV and 13.8 kV buses employ a single-bus scheme.
(3) Principal Features of Substation Equipment
Principal features of the substation equipment are summarized as follows:
(a) Step-down Transformer
- Type : Three-phase, oil-immersed, ONAN,
with on-load tap changer
- Rated power : 5,000 kVA
- Rated voltage ratio : 69/13.8 kV
- Rated frequency : 60 Hz
(b) 69 kV Switchgear
- Type : Outdoor use, conventional type
- Highest system voltage : 72.5 kV

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 Annex H Power Development Plan

- Rated insulation level

Lightning impulse : 325 kV
Power-frequency : 140 kV
- Rated frequency : 60 Hz
(c) 13.8 kV Switchgear
- Type : Outdoor use, conventional type
- Highest system voltage : 15 kV
- Rated insulation level
Full-wave lightning impulse: 110 kV
Power-frequency : 50 kV
- Rated frequency : 60 Hz

H5.3 Receiving Stations

Receiving Stations are required at the end of the 34.5 kV and 13.8 kV distribution
lines to the various waterway facilities for power supply to the loads. Each
receiving station is equipped with 34.5 kV or 13.8 kV switchgear, a step-down
transformer and low voltage switchgear. 6.6 kV or 3.3 kV switchgear is also
required at the Antipolo pump station for power supply to the pumps.
The step-down transformer is of three-phase, oil-immersed, outdoor-use type with
off-circuit tap-changer. The 34.5 kV and 13.8 kV switchgear is of outdoor-use,
metal-enclosed type.
Transformer ratings of the proposed receiving stations are summarized below:
Transformer ratings of the proposed receiving station
Receiving Station Transformer Capacity Voltage Ratio
Kaliwa Low Dam 50 kVA 13.8/0.48 kV
Valve House 31.5 kVA 13.8/0.48 kV
Antipolo Pump Station
- In Stage 1 10,000 kVA 34.5/6.6 (3.3) kV
100 kVA 6.6 (3.3)/0.48 kV
- In State 2-2 10,000 kVA 34.5/6.6 (3.3) kV
Antipolo Service Reservoirs 31.5 kVA 34.5/0.48 kV
Taytay Service Reservoirs 160 kVA 13.8/0.48 kV
After Bay 31.5 kVA 13.8/0.48 kV

H-23
 Annex H Power Development Plan

H6 Construction Cost Estimate

H6.1 Civil Works and Generating Equipment
Cost of civil works and generating equipment is shown in Annex J.

H6.2 Transformers, Switchyard Equipment and Transmission Lines

Construction cost of transformers, switchyard equipment and transmission lines
was estimated in consideration of current prices in NPC projects. Tables H6.1 and
H6.2 show the unit construction costs of transmission lines and substation/
switchyard equipment, respectively. Table H6.3 summarizes the estimated
construction cost of the staged implementations.

H-24
 Table H2.1 Result of Power Output Calculation at Agos Power Station (1/2)

Peak Power Operation Hour : 6-hour

Reservoir Water Level (El.m) Plant Discharge (m3/sec) Power Output (MW) Energy Generation (GWh)
Year
Maximum Minimum Average Maximum Average Maximum Average Primary Secondary Total
1950 159.0 146.0 154.3 110.8 107.7 103.4 101.2 221.6 318.6 540.2
1951 159.0 151.4 156.7 110.8 107.1 103.3 103.1 225.7 246.8 472.5
1952 159.0 145.2 155.5 110.8 107.2 103.3 101.8 223.6 285.9 509.5
1953 159.0 144.4 154.3 110.8 107.9 103.4 101.4 222.1 254.0 476.2
1954 159.0 133.0 147.9 110.8 99.7 103.3 88.7 193.9 197.7 391.5
1955 159.0 143.0 153.0 110.8 108.2 103.4 100.4 219.9 175.8 395.7
1956 159.0 159.0 159.0 105.3 105.3 103.3 103.3 226.8 489.7 716.5
1957 159.0 133.0 145.3 110.8 105.7 103.3 91.1 199.2 66.2 265.4
1958 159.0 159.0 159.0 105.3 105.3 103.3 103.3 226.2 192.9 419.1
1959 159.0 136.5 149.3 110.8 108.4 103.3 96.6 211.5 206.4 417.9
1960 159.0 154.9 158.2 108.8 105.9 103.4 103.3 226.8 403.3 630.1
1961 159.0 158.4 159.0 105.9 105.4 103.4 103.3 226.2 360.5 586.7
1962 159.0 149.9 157.4 110.8 106.4 103.4 103.0 225.7 325.3 551.0
1963 159.0 149.7 156.7 110.8 106.9 103.3 102.8 225.1 275.3 500.4
1964 159.0 156.0 158.5 107.8 105.7 103.3 103.3 226.8 402.1 628.9
1965 159.0 141.8 151.8 110.8 108.3 103.3 99.2 217.1 203.7 420.8
1966 159.0 133.0 149.5 110.8 106.8 103.3 95.7 209.6 145.9 355.5
1967 159.0 152.4 157.6 110.8 106.5 103.4 103.2 226.1 197.7 423.8
1968 159.0 146.3 155.5 110.8 107.4 103.3 102.1 224.3 275.2 499.5
1969 159.0 133.0 143.3 110.8 89.6 103.3 76.9 167.7 68.7 236.4
1970 159.0 133.0 148.0 110.8 90.1 103.4 81.8 178.6 195.4 374.0
1971 159.0 156.6 158.6 107.3 105.6 103.3 103.3 226.2 536.0 762.2
1972 159.0 158.4 158.9 105.9 105.4 103.4 103.3 226.9 376.8 603.6
1973 159.0 142.9 153.5 110.8 108.1 103.3 100.8 220.7 161.7 382.4
1977 159.0 147.9 156.6 110.8 107.0 103.3 102.8 225.2 303.4 528.6
1978 159.0 133.0 150.9 110.8 104.7 103.3 95.5 208.9 193.9 402.9
1984 159.0 138.5 151.2 110.8 108.3 103.4 98.6 216.6 191.6 408.2
1985 159.0 136.7 153.2 110.8 108.0 103.4 100.4 219.9 192.9 412.8
1986 159.0 137.1 153.1 110.8 107.7 103.3 99.9 218.8 226.4 445.2
1987 159.0 133.0 147.9 110.8 100.5 103.3 88.7 193.8 151.4 345.2
1988 159.0 137.8 151.7 110.8 108.1 103.4 98.9 217.2 231.5 448.7
159.0 133.0 153.7 110.8 105.3 103.4 98.6 216.1 253.3 469.4

Peak Power Operation Hour : 8-hour

Reservoir Water Level (El.m) Plant Discharge (m3/sec) Power Output (MW) Energy Generation (GWh)
Year
Maximum Minimum Average Maximum Average Maximum Average Primary Secondary Total
1950 159.0 146.0 154.3 83.1 80.8 77.5 75.8 221.5 225.0 446.5
1951 159.0 151.4 156.7 83.1 80.3 77.4 77.2 225.6 198.6 424.2
1952 159.0 145.2 155.5 83.1 80.4 77.4 76.3 223.5 218.1 441.6
1953 159.0 144.4 154.3 83.1 80.9 77.5 76.0 222.0 186.7 408.7
1954 159.0 133.0 147.9 83.1 74.7 77.4 66.5 193.7 139.9 333.6
1955 159.0 143.0 153.0 83.1 81.2 77.5 75.3 219.8 118.8 338.5
1956 159.0 159.0 159.0 79.0 79.0 77.4 77.4 226.7 359.3 586.0
1957 159.0 133.0 145.3 83.1 79.3 77.4 68.2 199.1 47.0 246.0
1958 159.0 159.0 159.0 79.0 79.0 77.4 77.4 226.1 155.2 381.2
1959 159.0 136.5 149.3 83.1 81.3 77.4 72.4 211.4 148.7 360.1
1960 159.0 154.9 158.2 81.6 79.5 77.5 77.4 226.7 271.2 497.9
1961 159.0 158.4 159.0 79.4 79.0 77.5 77.4 226.1 291.1 517.2
1962 159.0 149.9 157.4 83.1 79.8 77.5 77.2 225.5 238.4 464.0
1963 159.0 149.7 156.7 83.1 80.2 77.4 77.0 225.0 226.8 451.8
1964 159.0 156.0 158.5 80.9 79.3 77.4 77.4 226.7 318.7 545.4
1965 159.0 141.8 151.8 83.1 81.2 77.4 74.3 217.0 151.8 368.7
1966 159.0 133.0 149.5 83.1 80.1 77.5 71.8 209.4 108.1 317.5
1967 159.0 152.4 157.6 83.1 79.9 77.5 77.4 226.0 140.7 366.7
1968 159.0 146.3 155.5 83.1 80.5 77.4 76.5 224.1 200.2 424.2
1969 159.0 133.0 143.3 83.1 67.2 77.4 57.6 167.6 49.5 217.1
1970 159.0 133.0 148.0 83.1 67.6 77.5 61.3 178.4 138.3 316.7
1971 159.0 156.6 158.6 80.5 79.2 77.4 77.4 226.1 366.1 592.1
1972 159.0 158.4 158.9 79.4 79.1 77.5 77.4 226.8 262.6 489.3
1973 159.0 142.9 153.5 83.1 81.1 77.5 75.5 220.6 123.8 344.4
1977 159.0 147.9 156.6 83.1 80.2 77.4 77.1 225.1 231.6 456.7
1978 159.0 133.0 150.9 83.1 78.5 77.4 71.6 208.8 136.9 345.7
1984 159.0 138.5 151.2 83.1 81.3 77.5 73.9 216.4 134.6 351.0
1985 159.0 136.7 153.2 83.1 81.0 77.5 75.3 219.8 135.9 355.6
1986 159.0 137.1 153.1 83.1 80.8 77.4 74.9 218.6 177.4 396.0
1987 159.0 133.0 147.9 83.1 75.3 77.4 66.5 193.6 112.9 306.5
1988 159.0 137.8 151.7 83.1 81.1 77.5 74.1 217.0 178.0 395.0
159.0 133.0 153.7 83.1 79.0 77.5 73.9 216.0 186.8 402.8

HT-1
 Table H2.1 Result of Power Output Calculation at Agos Power Station (2/2)
Peak Power Operation Hour : 12-hour
Reservoir Water Level (El.m) Plant Discharge (m3/sec) Power Output (MW) Energy Generation (GWh)
Year
Maximum Minimum Average Maximum Average Maximum Average Primary Secondary Total
1950 159.0 146.0 154.3 55.4 53.8 51.5 50.4 220.8 112.1 332.9
1951 159.0 151.4 156.7 55.4 53.5 51.5 51.3 224.9 104.9 329.8
1952 159.0 145.2 155.5 55.4 53.6 51.5 50.7 222.8 114.2 337.0
1953 159.0 144.4 154.3 55.4 53.9 51.5 50.5 221.3 93.0 314.3
1954 159.0 133.0 147.9 55.4 49.8 51.5 44.2 193.1 74.5 267.6
1955 159.0 143.0 153.0 55.4 54.1 51.5 50.0 219.1 61.7 280.8
1956 159.0 159.0 159.0 52.6 52.6 51.5 51.5 226.0 201.4 427.3
1957 159.0 133.0 145.3 55.4 52.9 51.5 45.3 198.4 27.7 226.1
1958 159.0 159.0 159.0 52.6 52.6 51.5 51.5 225.4 116.8 342.2
1959 159.0 136.5 149.3 55.4 54.2 51.5 48.1 210.7 87.5 298.2
1960 159.0 154.9 158.2 54.4 53.0 51.5 51.5 226.0 139.1 365.1
1961 159.0 158.4 159.0 52.9 52.7 51.5 51.5 225.4 163.9 389.3
1962 159.0 149.9 157.4 55.4 53.2 51.5 51.3 224.8 126.2 351.0
1963 159.0 149.7 156.7 55.4 53.4 51.5 51.2 224.3 124.3 348.6
1964 159.0 156.0 158.5 53.9 52.8 51.5 51.5 226.0 167.3 393.3
1965 159.0 141.8 151.8 55.4 54.1 51.5 49.4 216.3 77.3 293.6
1966 159.0 133.0 149.5 55.4 53.4 51.5 47.7 208.7 65.9 274.6
1967 159.0 152.4 157.6 55.4 53.2 51.5 51.4 225.3 83.5 308.8
1968 159.0 146.3 155.5 55.4 53.7 51.5 50.9 223.4 121.2 344.5
1969 159.0 133.0 143.3 55.4 44.8 51.5 38.3 167.0 30.2 197.2
1970 159.0 133.0 148.0 55.4 45.1 51.5 40.8 177.8 75.8 253.6
1971 159.0 156.6 158.6 53.7 52.8 51.5 51.5 225.4 187.9 413.3
1972 159.0 158.4 158.9 53.0 52.7 51.5 51.5 226.1 138.5 364.5
1973 159.0 142.9 153.5 55.4 54.0 51.5 50.2 219.8 79.4 299.2
1977 159.0 147.9 156.7 55.4 53.5 51.5 51.2 224.4 130.6 355.0
1978 159.0 133.0 150.9 55.4 52.3 51.5 47.6 208.2 78.8 287.0
1984 159.0 138.6 151.2 55.4 54.2 51.5 49.1 215.7 75.8 291.5
1985 159.0 136.7 153.2 55.4 54.0 51.5 50.0 219.1 75.8 294.8
1986 159.0 137.1 153.1 55.4 53.8 51.5 49.8 217.9 94.7 312.6
1987 159.0 133.0 147.9 55.4 50.2 51.5 44.2 193.0 66.9 259.9
1988 159.0 137.8 151.7 55.4 54.0 51.5 49.2 216.3 93.7 310.0
159.0 133.0 153.7 55.4 52.6 51.5 49.1 215.3 102.9 318.2

Peak Power Operation Hour : 24-hour

Reservoir Water Level (El.m) Plant Discharge (m3/sec) Power Output (MW) Energy Generation (GWh)
Year
Maximum Minimum Average Maximum Average Maximum Average Primary Secondary Total
1950 159.0 146.0 154.3 27.7 26.9 25.5 25.0 218.8 0.0 218.8
1951 159.0 151.4 156.7 27.7 26.8 25.5 25.4 222.9 0.0 222.9
1952 159.0 145.2 155.5 27.7 26.8 25.5 25.1 220.8 0.0 220.8
1953 159.0 144.4 154.3 27.7 27.0 25.5 25.0 219.3 0.0 219.3
1954 159.0 133.0 147.9 27.7 24.9 25.5 21.9 191.2 0.0 191.2
1955 159.0 143.0 153.0 27.7 27.0 25.5 24.8 217.0 0.0 217.0
1956 159.0 159.0 159.0 26.3 26.3 25.5 25.5 224.0 0.0 224.0
1957 159.0 133.0 145.3 27.7 26.4 25.5 22.5 196.5 0.0 196.5
1958 159.0 159.0 159.0 26.3 26.3 25.5 25.5 223.4 0.0 223.4
1959 159.0 136.5 149.3 27.7 27.1 25.5 23.8 208.7 0.0 208.7
1960 159.0 154.9 158.2 27.2 26.5 25.5 25.5 224.0 0.0 224.0
1961 159.0 158.4 159.0 26.5 26.3 25.5 25.5 223.5 0.0 223.5
1962 159.0 149.9 157.4 27.7 26.6 25.5 25.4 222.9 0.0 222.9
1963 159.0 149.7 156.7 27.7 26.7 25.5 25.4 222.3 0.0 222.3
1964 159.0 156.0 158.5 26.9 26.4 25.5 25.5 224.0 0.0 224.0
1965 159.0 141.8 151.8 27.7 27.1 25.5 24.5 214.3 0.0 214.3
1966 159.0 133.0 149.5 27.7 26.7 25.5 23.6 206.8 0.0 206.8
1967 159.0 152.4 157.6 27.7 26.6 25.5 25.5 223.3 0.0 223.3
1968 159.0 146.3 155.5 27.7 26.8 25.5 25.2 221.4 0.0 221.4
1969 159.0 133.0 143.3 27.7 22.4 25.5 19.0 165.5 0.0 165.5
1970 159.0 133.0 148.0 27.7 22.5 25.5 20.2 176.2 0.0 176.2
1971 159.0 156.6 158.6 26.8 26.4 25.5 25.5 223.5 0.0 223.5
1972 159.0 158.4 158.9 26.5 26.3 25.5 25.5 224.2 0.0 224.2
1973 159.0 142.9 153.5 27.7 27.0 25.5 24.9 217.8 0.0 217.8
1977 159.0 147.9 156.7 27.7 26.7 25.5 25.4 222.4 0.0 222.4
1978 159.0 133.0 150.9 27.7 26.2 25.5 23.6 206.3 0.0 206.3
1984 159.0 138.6 151.2 27.7 27.1 25.5 24.3 213.7 0.0 213.7
1985 159.0 136.7 153.2 27.7 27.0 25.5 24.8 217.1 0.0 217.1
1986 159.0 137.1 153.1 27.7 26.9 25.5 24.7 215.9 0.0 215.9
1987 159.0 133.0 147.9 27.7 25.1 25.5 21.9 191.2 0.0 191.2
1988 159.0 137.8 151.7 27.7 27.0 25.5 24.4 214.3 0.0 214.3
159.0 133.0 153.7 27.7 26.3 25.5 24.3 213.3 0.0 213.3

HT-2
 Table H3.1 Result of Power Output Calculation at Lagundi Power Station

Reservoir Water Level (El.m) 3

Plant Discharge (m /sec) Power Output (MW) Energy
Year Generation
Maximum Minimum Average Maximum Average Maximum Average (GWh)
1950 159.0 146.0 154.3 34.7 30.9 10.6 9.4 82.6
1951 159.0 151.4 156.7 34.7 30.1 10.6 10.2 88.9
1952 159.0 145.2 155.5 34.7 30.3 10.6 9.8 85.7
1953 159.0 144.4 154.3 34.7 31.2 10.6 9.5 82.9
1954 159.0 133.0 147.9 34.7 32.2 10.6 6.7 58.3
1955 159.0 143.0 153.0 34.7 31.5 10.6 9.1 79.6
1956 159.0 159.0 159.0 28.2 28.2 10.6 10.6 93.1
1957 159.0 133.0 145.3 34.7 33.3 10.6 5.6 48.5
1958 159.0 159.0 159.0 28.2 28.2 10.6 10.6 92.8
1959 159.0 136.5 149.3 34.7 31.8 10.6 6.8 59.8
1960 159.0 154.9 158.2 31.5 28.8 10.6 10.5 92.1
1961 159.0 158.4 159.0 28.6 28.3 10.6 10.6 92.7
1962 159.0 149.9 157.4 34.7 29.4 10.6 10.3 90.2
1963 159.0 149.7 156.7 34.7 30.0 10.6 10.1 88.4
1964 159.0 156.0 158.5 30.5 28.6 10.6 10.5 92.6
1965 159.0 141.8 151.8 34.7 31.6 10.6 8.7 76.3
1966 159.0 133.0 149.5 34.7 31.9 10.6 7.0 61.3
1967 159.0 152.4 157.6 33.8 29.4 10.6 10.3 90.6
1968 159.0 146.3 155.5 34.7 30.5 10.6 9.8 85.9
1969 159.0 133.0 143.3 34.7 33.2 10.6 4.5 38.9
1970 159.0 133.0 148.0 34.7 32.0 10.6 6.8 59.3
1971 159.0 156.6 158.6 30.0 28.5 10.6 10.6 92.5
1972 159.0 158.4 158.9 28.6 28.3 10.6 10.6 93.1
1973 159.0 142.9 153.5 34.7 31.4 10.6 9.2 80.9
1977 159.0 147.9 156.6 34.7 29.9 10.6 10.1 88.5
1978 159.0 133.0 150.9 34.7 31.3 10.6 7.8 68.1
1984 159.0 138.5 151.2 34.7 31.7 10.6 8.1 71.4
1985 159.0 136.7 153.2 34.7 31.2 10.6 8.8 77.0
1986 159.0 137.1 153.1 34.7 30.9 10.6 8.7 76.3
1987 159.0 133.0 147.9 34.7 32.1 10.6 6.6 58.0
1988 159.0 137.8 151.7 34.7 31.4 10.6 8.3 72.7
159.0 133.0 153.7 34.7 30.6 10.6 8.9 78.0

HT-3
 Table H6.1 Transmission Lines - Unit Construction Cost

Description Forex (US$) Local (PhP) Total (Php)

Transmission Line Equipment

- 230 kV, ST-DC, 1-795 MCM, ACSR
Complete with Line Hardware 190,471 1,551,040 11,455,532
- 69 kV, WP-SC, 1-336.4 MCM, ACSR
Complete with Line Hardware 23,723 270,707 1,504,303
- 13.8 kV, WP-SC, 1-336.4 MCM, ACSR
Complete with Line Hardware 16,212 157,000 1,000,024

Transmission Line Right of Way Cost/Km

230 kV, ST-DC T/L Route P85.00/sq. meter 1,190,000 1,190,000
230 kV T/L ST-DC Clearing Cost 59,500 59,500
1,249,500 1,249,500
69 kV, WP-SC T/L Route P110.00/sq. meter 770,000 770,000
69 kV T/L WP-SC Clearing Cost 38,500 38,500
808,500 808,500
13.8 kV, WP-SC T/L Route P110.00/sq. meter 550,000 550,000
13.8 kV T/L ST-DC Clearing Cost 27,500 27,500
577,500 577,500

Transmission Line (T/L) Circuits:

Voltage Transmission Line Type Rating
230 kV DC-ST, 1-795 MCM Conductor 358.6 MVA/Ckt.
69 kV SC-WP, 336.4 MCM Conductor 53.9 MVA
13.8 kV SC-WP, 336.4 MCM Conductor 10.4 MVA

Notes:
ST-SC - Steel Tower, Single Circuit Transmission Line
ST-SC - Steel Tower, Double Circuit Transmission Line
WP-SC - Wood Pole, Single Circuit Transmission Line
The indication 1-795 MCM, ACSR refers to the type of conductor
ACSR - Aluminum Cable Steel Reinforced

HT-4
 Table H6.2 Substation and Switchyard - Unit Construction Cost

Description Forex ($) Local (P) Total Php

Substation & Switchyard Equipment

(1) 230 kV
- 230 kV PCB, Outdoor Type, 3000A, 40kA 71,150 129,493 3,829,293
- Spare Parts & Special Tools /Bay 36,430 0 1,894,360
- Disconnect Switches & Line Materials /Bay 17,500 31,850 941,850
- Complete 1-Bay 230 kV Substation (3PCB's) 267,380 486,632 14,390,392
- Complete 1-Bay 230 kV Substation (2PCB's) 196,230 357,139 10,561,099
- Complete 2-Bay 230 kV Substation (6PCB's) 321,310 584,784 17,292,904
- 50 MVA, 13.8kV/230kV Gen. Transformer 2,982,506 4,652,709 159,743,021
- 15 MVA, 230kV/69kV Transformer 894,751 1,395,812 47,922,864
- 7 MVA, 13.8kV/69kV Gen. Transformer 370,281 491,327 19,745,939
- 5 MVA, 69kV/13.8 transformer 253,512 1,581,920 14,764,544
- 2 MVA, 69kV/13.8 transformer 105,509 140,379 5,626,847
- 1.5 MVA, 13.8kV/4.16kV transformer 168,830 224,606 9,003,766
- 1 MVA, 13.8kV/4.16kV Sta. Transformer 50,703 316,384 2,952,940
- 750 KVA, 13.8kV/480 Volts Sta. Transformer 39,548 246,880 2,303,376

(2) 69 kV
- 69 kV PCB, Outdoor Type, 1200A, 37kA 42,998 78,256 2,314,152
- Disconnect Switches & Line Materials /Feeder 3,200 16,640 183,040
- Complete 2 Feeder 69 kV Substation 92,396 240,230 5,044,822
- Complete 3 Feeder 69 kV Substation 138,594 266,655 7,473,543
- Complete 4 Feeder 69 kV Substation 184,792 336,321 9,945,505
- Complete 5 Feeder 69 kV Substation 230,990 420,402 12,431,882

(3) 13.8 kV
- 13.8 kV PCB, Outdoor Type, 1200A, 37kA 18,700 34,034 1,006,434
- Disconnect Switches & Line Materials /Feeder 1,600 8,320 91,520
- Complete 2 Feeder 13.8 kV Substation 40,600 105,560 2,216,760
- Complete 3 Feeder 13.8 kV Substation 60,900 117,172 3,283,972
- Complete 4 Feeder 13.8 kV Substation 81,200 147,784 4,370,184

Note: Substation (S/S) and Swichyard (S/Y) Electrical Equipment:

Voltage Specification and Rating
230 kV PCB, Live Tank Outdoor Type, 300 Amps. Type, 40 kA
69 kV PCB, Circuit Breaker, Outdoor Type, 37 kA
13.8 kV Generator Circuit Breaker, 3000 Amps. Type, 40 kA
13.8/230 kV 50 MVA Generator Transformer
13.8/230 kV 7 MVA Generator Transformer

HT-5
 Table H6.3 Substation, Switchyards and Transmission Lines - Cost Estimate (1/3)

A. STAGE 1: POWER SUPPLY TO WATERWAY FACILITIES

1-A. Transmission Lines

Transmission Lines Length Forex ($) Local (Php) Total (PhP)
- Dolores S/S to WTP
15.6 Kms, 69 kV, WP-SC 15.6 370,079 4,223,029 23,467,127
Right-of-Way and Clearing Cost 12,612,600 12,612,600
- WTP to Kaliwa Low Dam
30.6 Kms, 69 kV, WP-SC 30.6 725,924 8,283,634 46,031,672
Right-of-Way and Clearing Cost 24,740,100 24,740,100
- WTP to Valve House
6.7 Kms, 13.8 kV, WP-SC 6.7 108,620 1,051,900 6,700,161
Right-of-Way and Clearing Cost 3,869,250 3,869,250
- Valve House to Taytay S/R
6.5 Kms, 13.8 kV, WP-SC 6.5 105,378 1,020,500 6,500,156
Right-of-Way and Clearing Cost 3,753,750 3,753,750
- WTP to Antipolo P/S
7.5 Kms, 13.8 kV, WP-SC 7.5 121,590 1,177,500 7,500,180
Right-of-Way and Clearing Cost 4,331,250 4,331,250
- Antipolo P/S to Antipolo S/R
2 Kms, 13.8 kV, WP-SC 6.5 105,378 1,020,500 6,500,156
Right-of-Way and Clearing Cost 3,753,750 3,753,750
- Antipolo S/R to Taytay S/R (Tie Line)
6 Kms, 13.8 kV, WP-SC 6 97,272 942,000 6,000,144
Right-of-Way and Clearing Cost 3,465,000 3,465,000

Total Transmission Line Cost 1,634,241 74,244,763 159,225,295

1-B. Switching Facilities

Water Treatment Plant Forex ($) Local (Php) TOTAL (PhP)
- 5 MVA, 69kV/13.8kV X'fmer 253,512 1,581,920 14,764,544
- Radial Substation with 3 x 69kV Feeders 138,594 266,655 7,473,543
- Radial Substation with 3 x 13.8kV Feeders 60,900 117,172 3,283,972
WTP Receiving Facilities Total 453,006 1,965,746 25,522,058

Kaliwa Low Dam/Water Intake Forex ($) Local (Php) TOTAL (PhP)
- 1 x 2 MVA, 69kV/13.8kV X'fmer 105,509 140,379 5,626,847
- Radial Substation with 3 x 69kV Feeders 60,900 117,172 3,283,972
Kaliwa Low Dam Receiving Facilities Total 166,409 257,551 8,910,819

Dolores S/S Forex ($) Local (Php) TOTAL (PhP)

- 1 Bay 230 Kv Substation (3PCB's) 267,380 486,632 14,390,392
- 1 x 15 MVA, 230kV/69kV X'fmer 894,751 1,395,812 47,922,864
Dolores S/S Equipment Cost 1,162,131 1,882,444 62,313,256

(to be continued)

HT-6
 Table H6.3 Substation, Switchyards and Transmission Lines - Cost Estimate (2/3)

Valve House Forex ($) Local (Php) Total (PhP)

- Radial Substation with 3 x 13.8kV Feeders 60,900 117,172 3,283,972
Valve House Receiving Facilities Total 60,900 117,172 3,283,972

Taytay S/R Forex ($) Local (Php) TOTAL (PhP)

- Radial Substation with 4 x 13.8kV Feeders 81,200 147,784 4,370,184
Taytay S/R Receiving Facilities Total 81,200 147,784 4,370,184

Antipolo P/S Forex ($) Local (Php) TOTAL (PhP)

- Radial Substation with 3 x 13.8kV Feeders 60,900 117,172 3,283,972
Antipolo P/S Receiving Facilities Total 60,900 117,172 3,283,972

Antipolo S/R Forex ($) Local (Php) TOTAL (PhP)

- Radial Substation with 4 x 13.8kV Feeders 81,200 147,784 4,370,184
Antipolo P/S Receiving Facilities Total 81,200 147,784 4,370,184

Stage 1 Total Project Cost Forex ($) Local (Php) TOTAL (PhP)
1-A. Total Transmission Line Cost 1,634,241 74,244,763 159,225,295
1-B. Switching Facilities
Water Treatment Plant 453,006 1,965,746 25,522,058
Kaliwa Low Dam 166,409 257,551 8,910,819
Dolores S/S Equipment Cost 1,162,131 1,882,444 62,313,256
Valve House 60,900 117,172 3,283,972
Taytay S/R 81,200 147,784 4,370,184
Antipolo P/S 60,900 117,172 3,283,972
Antipolo S/R 81,200 147,784 4,370,184
Total 3,699,987 78,880,415 271,279,739

B. STAGE 2-1: AGOS HEP INTERCONNECTION SYSTEM

2.A. Agos Switchyard Equipment Forex ($) Local (Php) Total (PhP)
- 2 x 50 MVA, 13.8kV/230kV Gen. X'former 5,965,012 9,305,419 319,486,043
- 15 MVA, 230kV/69kV X'former* 0 1,395,812 1,395,812
- Transport of 15 MVA 230/69 kV X'former
from Dolores S/S to Agos HEP 0 75,000 75,000
- Installation Cost of 15 MVA 230/69 kV
x'former at Dolores 930,540 930,540
- 2 x 1.5 MVA, 13.8kV/4.16kV Sta. X'former 337,660 449,212 18,007,532
- 3 Bay 230 Kv Substation (8PCB's) 517,540 941,923 27,854,003
- Radial Substation with 5 x 69kV Feeders 230,990 420,402 12,431,882
- Radial Substation with 3 x 13.8kV Feeders 60,900 117,172 3,283,972
Total Agos Switchyard Equipment Cost 7,112,102 13,635,479 383,464,783

2.B. Afterweir Bay Switching Facilities Forex ($) Local (Php) TOTAL (PhP)
- Radial Substation with 3 x 13.8kV Feeders 60,900 117,172 3,283,972
Antipolo P/S Receiving Facilities Total 60,900 117,172 3,283,972

(to be continued)

HT-7
 Table H6.3 Substation, Switchyards and Transmission Lines - Cost Estimate (3/3)

2-C. Transmission Lines

Transmission Lines Length Forex ($) Local (Php) Total (PhP)
- Agos HEP to Dolores S/S
50.6 Kms, 230 kV, ST-DC 50.6 9,637,833 78,482,624 579,649,919
Right-of-Way and Clearing Cost 63,224,700 63,224,700
- Agos HEP to Kaliwa Low Dam
7.6 Kms, 69 kV, WP-SC 7.6 180,295 2,057,373 11,432,703
Right-of-Way and Clearing Cost 6,144,600 6,144,600

- Agos HEP to Afterweir Bay

3.5 Kms, 13.8 kV, WP-SC 3.5 56,742 549,500 3,500,084
Right-of-Way and Clearing Cost 2,021,250 2,021,250
- Agos HEP to Quezelco S/S**
7.6 Kms, 69 kV, WP-SC 7.6 0 2,057,373 2,057,373
Right-of-Way and Clearing Cost 6,144,600 6,144,600
- Cost of retiring 13.5 Kms of the
15.6 Kms, 69 kV, T/L, WPSC,
Dolores S/S to WTP 13.5 0 1,388,727 1,388,727
Total Transmission Line Cost 9,874,869 162,070,747 675,563,956
*This 15 MVA transformer is initially installed at Dolores S/S

**Installation cost only. Materials shall come from the 13.5 Kms part
of 15.5 Kms Dolores S/S to WTP T/L

Stage 2 Total Project Cost Forex ($) Local (Php) Total (PhP)
2.A. Agos Switchyard Equipment 7,112,102 13,635,479 383,464,783
2.B. Afterweir Bay Switching Facilities 60,900 117,172 3,283,972
2-C. Transmission Lines 9,874,869 162,070,747 675,563,956
Total 17,047,871 175,823,398 1,062,312,711

C. STAGE 3: Lagundi Hydro-Electric

3.A. Lagundi Switchyard Equipment Forex ($) Local (Php) Total (PhP)
- 2 x 7 MVA, 13.8kV/230kV Gen. X'former 740,562 982,654 39,491,878
- 2 x 750 KVA, 13.8kV/480 Volts Sta. X'former 79,096 493,760 4,606,752
- Radial Substation with 3 x 69kV Feeders 138,594 266,655 7,473,543
Total Agos Switchyard Equipment Cost 958,252 1,743,069 51,572,173

3-B. Transmission Lines

Transmission Lines Length Forex ($) Local (Php) Total (PhP)
- WTP to Lagundi HEP***
2 Kms, 69 kV, WP-SC 2 0 541,414 541,414
Right-of-Way and Clearing Cost 1,617,000 1,617,000
Total Transmission Line Cost 0 2,158,414 2,158,414

***Note: Line Materials shall come from the retired 15.6 Kms of 69 kV Dolores S/S to WTP T/L

Stage 3 Total Project Cost Forex ($) Local (Php) Total (PhP)
3.A. Lagundi Switchyard Equipment 958,252 1,743,069 51,572,173
3-B. Transmission Lines 0 2,158,414 2,158,414
Total 958,252 3,901,483 53,730,587

Cost of Entire Project Forex ($) Local (Php) Total (PhP)

Stage 1 Total Project Cost 3,699,987 78,880,415 271,279,739

Stage 2-1 Total Project Cost 17,047,871 175,823,398 1,062,312,711

Stage -22 Total Project Cost 958,252 3,901,483 53,730,587

Grand Total 21,706,110 258,605,296 1,387,323,037

HT-8