Pre-Feasibility Study for
Rural Electrification Program by Renewable Energy
In The Mountainous Region of Northern Samar
in the Philippines
STUDY REPORT
March 2007
Engineering and Consulting Firms Association, Japan
West Japan Engineering Consultants, Inc
This
work
was
subsidized
by
Japan
Keirin
Association through its Promotion funds from
From Manilla
CATARMAN
CATUBIG RIVER
NORTHERN SAMAR
SAMAR ISLAND
LEYTE ISLAND
Location Map
Contents
Executive Summary ························································································································ S-1
Chapter 1
Introduction·················································································································· 1
1.1 Background and Objectives ···························································································· 1
1.2
Scope of Works··············································································································· 2
1.3
Study Area ······················································································································ 2
1.4
Study Schedule ··············································································································· 2
1.5
Study Team Member······································································································· 3
Chapter 2
2.1
Socio-Economic Development in Communities Hosting Renewable energy ················ 4
Economic Development and Energy in the Philippines··················································· 4
2.2 Renewable Energy Development in the Philippines ························································ 5
2.3 Major Issues ··················································································································· 14
2.4
Government Policies and Programs ················································································ 14
2.5
Impact to Host Communities ·························································································· 8
Chapter 3
Rural Electrification ····································································································· 19
3.1 Current Condition of Rural Electrification ······································································ 19
3.2
Promotion Policy of Rural Electrification ······································································· 22
3.3
Issues of Rural Electrification ························································································· 23
3.4
Effects of Rural Electrification ······················································································· 25
Chapter 4
Outline of the Surveyed Area ······················································································· 29
4.1
Outline of Northern Samar Province··············································································· 29
4.2
Electrical Power Situation in Northern Samar Province ·················································· 30
Chapter 5
Pre-Feasibility Study of Rural Electrification by Renewable Energy···························· 34
5.1 Current Situation of Rural Electrification in Coverage Area ··········································· 34
5.2
Assumption of Electric Demand associated with Rural Electrification···························· 41
5.3
Assumption of Electrification associated with Expansion of Distribution Line··············· 46
5.4
Assumption of Electrification Cost by Renewable Energy·············································· 51
5.5
Selection of Candidate Barangays for Electrification by Renewable Energy··················· 60
Chapter 6
6.1
Rural Electrification Plan by Renewable Energy·························································· 61
Potential of Micro Hydro Power Plant ············································································ 61
6.2
Hydro Power Generation Plant at Barangays ·································································· 61
6.3 Micro Hydro Power Plant ······························································································· 62
6.4 Biogas Power Plant········································································································· 66
Chapter 7
Profile of the Project ···································································································· 69
Appendix 1 Schedule for Field Investigation
Appendix 2 Interviewed Persons List
Appendix 3 Photos
Figure List
Fig-5.1
Status of Barangay Electrification in Region VIII ···················································· 35
Fig-5.2
Status of Barangay Electrification in Northern Samar ············································· 36
Fig-5.3
Diagram of Transmission Line in Philippines (Northern Samar Area) ···················· 37
Fig-5.4
Breakdown of Consumer Numbers in NORSAMELCO (as of 2004) ····················· 39
Fig-5.5
Demand Forecast of NORSAMELCO ······································································ 40
Fig-5.6
Assumption of Electric Demand by Rural electrification (daily load curve)··········· 45
Fig-5.7
Expansion Plan of Distribution Line ········································································· 48
Fig-5.8
Outline of 3kW Stirling Engine (ST-5) ····································································· 57
Fig-6.1
Micro Hydro Power Turbine Types ············································································· 63
Fig-6.2
Turbine Selection Diagram·························································································· 64
Fig-6.3
Biogas Generating System··························································································· 68
Table List
Table-1.1
Study Team Members·································································································· 3
Table-2.1
Hydropower Measurable Targets ······································································ 9
Table-2.2
Indicative Hydropower Capacity Addition ······················································ 10
Table-3.1
1999 – 2006 Implementation Plans of O-Ilaw Program and ER Program ··············· 20
Table-3.2
Electrification Level by Region (As of 31, October 2006) ······································ 21
Table-3.3
Barangay Electrification Level by Franchise Holder (As of October 2006) ··········· 21
Table-3.4
Rural Electrification by Method (1999 – 2002) ························································ 25
Table-4.1
Electricity Demand ······························································································· 31
Table-4.2
Annual Power Purchase ······················································································ 32
Table-4.3
Supply – Demand Profile ····················································································· 32
Table-4.4
Level of Electrification ························································································· 33
Table-5.1
Status of Barangay Electrification in Region VIII ···················································· 35
Table-5.2
Status of Barangay Electrification in Northern Samar ············································· 36
Table-5.3
Outline of NORSAMELCO (As of 2006 Oct.)························································· 38
Table-5.4
Energy Distribution of NORSAMELCO(2004) ······················································· 39
Table-5.5
Electric Tariff of NORSAMELCO(2004) ································································· 39
Table-5.6
Income Statement of NORSAMELCO(2004) ·························································· 40
Table-5.7
NORSAMELCO Development Plan ········································································· 41
Table-5.8(1) Current Situation of Electrification of Barangays in Catubig ·································· 43
Table-5.8(2) Current Situation of Electrification of Barangays in Las Navas ······························ 44
Table-5.9
Assumption of Electric Demand by Rural electrification········································· 45
Table-5.10 Electrification Plan of Barangay ··············································································· 46
Table-5.11 Number of Household and Distance of Distribution Line ········································ 48
Table-5.12 Electrification Cost by Expansion of Distribution Line ··········································· 50
Table-5.13 Electrification Cost by Each Method of Power Generation ····································· 53
Table-5.14 CDM Project by Usage of Biogas in Philippines (Registered CDM Project)·········· 54
Table-5.15 Current Situation of Firming of Livestock and Poultry in Catubig ·························· 55
Table-5.16 Specification of Stirling Engine ················································································ 58
Table-5.17 Assumed Amount of Rice Chaff for Generating ······················································· 58
Table-6.1
Potential of Micro Hydro Power at Catubig Service Area············································ 61
Table-6.2
Basic Specification of Hybrid Power Generating at Each Barangay ···························· 65
Table-6.3
Basic Specification of Biogas Power Generation························································· 67
Table-6.4
Comparison of Biogas Generating in Philippines and Japan········································ 68
Abbreviations
・DOE；Department of Energy
・NPC；National Power Corporation
・NPC-SPUG；National Power Corporation Small Power Utilities Group
・NIA；National Irrigation Administration
・PNOC；Philippine National Oil Corporation
・PNOC-EDC；Philippine National Oil Corporation-Energy Development Corporation
・TRANSCO；Transmission Company
・NEA；National Electrification Administration
・PSALM；Power Sector Assets and Liabilities Management Corporation
・ERC；Energy Regulatory Commission
・EPIRA；Electric Power Industry Reform Act
・PEP；Philippine Energy Plan
・WESM；Wholesale Electricity Spot Market
・IPP；Independent Power Producer
・NEDA；National Economic and Development Authority
・NORSAMELCO；Northern Samar Electric Cooperative, Inc.
・SIDC；Sorosoro Ibaba Development Cooperative
・LGU；Local Government Unit
・NGO；Non Government Organization
・DILG；Department of Interior and Local Government
・ER；Energy Regulation
・RWMHEE；Reforestation and Watershed Management, Health and Environment Enhancement
・REC；Rural Electrification Cooperative
・BAPA；Barangay Alternative Power Association
・LUWAS；Local Unit Water and Sanitation Systems
・RAIC；Regional Agri-Industrial Center
・PDIP；Provincial Development Investment Program
・PDMP；Provincial Development Management Plan
・PDC；Provincial Development Council
・RPS；Renewables Portfolio Standard
・JICA；Japan International Cooperation Agency
・JBIC；Japan Bank For International Cooperation
Executive Summary
To sustain the government’s efforts in providing a better quality of life to the Filipino
people, the eradication of poverty remains a top national concern and a big challenge to the
present administration in the Philippines. The Philippine government set plans that would attain
its target of completing the energization of all barangays by year 2008.
The Northern Samar province in the Eastern Visayas region, which is the study area for this
feasibility study on rural electrification, is one of the underdeveloped areas in the Philippines.
Its per capita income level is less than 50% of the average per capita income level in the
Philippines. Since the electrification rate of households in the northern mountainous area is only
less than 20%, it has targeted to increase the electrification rate in order to boost the growth of
agricultural activity and the development of the tourism industry.
JBIC has decided to fund the Exclusive Agricultural Development Project in the Catubig
watershed area in the municipalities of Catubig and Las Navas in Northern Samar. This project
aims to increase agricultural productivity, particularly of rice and other crops, increase the
income of residents and improve health and sanitary conditions.
This will be addressed by the
development of an agricultural infrastructure centered on an irrigation system. This project will
commence in 2007 and will be completed in 2008.
It is envisioned that there will be an
improvement in the quality of life of the people belonging to the poor sector upon the
development of the base infrastructure. Moreover, the acceleration of rural electrification is also
expected.
This study covers the feasibility of rural electrification by renewable energy, such as micro
hydro power supplied from the potential of the Catubig River and irrigation facilities and
biomass power energy supplied from agricultural products.
The increase in agricultural
products is an expected outcome of the Exclusive Agricultural Development Project in the
Catubig watershed area.
As a result of this study total construction cost of rural electrification by hybrid system
between micro hydro power for the base load and biogas power for the peak load is estimated as
most competitive other than the cost of other alternatives such like expansion of distribution line
to the beneficiary, soro micro hydro power, soro biogas power and rice chaff power.
- S-1 -
Chapter 1 Introduction
1.1
Background and Objectives
To sustain the government’s efforts in providing a better quality of life to the Filipino
people, the eradication of poverty remains a top national concern and a big challenge to the
present administration in the Philippines. The Philippine government set plans that would attain
its target of completing the energization of all barangays by year 2008.
Two-thirds of the poverty group, which comprises about 40% of the population in the
Philippines, are engaged in the farming and fishing industries. Realization of rural
electrification is expected to bridge the gap between the rich and the poor, help eradicate
poverty in rural areas, provide a better quality of life and produce new sources of income.
The Northern Samar province in the Eastern Visayas region, which is the study area for
this feasibility study on rural electrification, is one of the underdeveloped areas in the
Philippines. Its per capita income level is less than 50% of the average per capita income level
in the Philippines. Since the electrification rate of households in the northern mountainous area
is only less than 20%, it has targeted to increase the electrification rate in order to boost the
growth of agricultural activity and the development of the tourism industry.
The main industry in this province is agriculture, with major crops including rice, corn,
coconut, banana and cassava. Although agriculture is the province’s main income source,
self-sufficiency in rice has not been attained. Therefore, rice has been imported from the
adjoining Leyte province.
Poor health and sanitary conditions, including that of the rural sewerage systems, have
brought some diseases to the residents, thereby contributing to the slow progress in the province.
Furthermore, since the roads in this area are unpaved, agricultural products can not be easily
transported during the rainy season. These factors contribute to the low income level in the
province.
JBIC has decided to fund the Exclusive Agricultural Development Project in the
Catubig watershed area in the municipalities of Catubig and Las Navas in Northern Samar. This
project aims to increase agricultural productivity, particularly of rice and other crops, increase
the income of residents and improve health and sanitary conditions.
-1-
This will be addressed by
the development of an agricultural infrastructure centered on an irrigation system. This project
will commence in 2007 and will be completed in 2008.
It is envisioned that there will be an
improvement in the quality of life of the people belonging to the poor sector upon the
development of the base infrastructure. Moreover, the acceleration of rural electrification is also
expected.
This study covers the feasibility of rural electrification by renewable energy, such as
micro hydro power supplied from the potential of the Catubig River and irrigation facilities and
biomass power energy supplied from agricultural products.
The increase in agricultural
products is an expected outcome of the Exclusive Agricultural Development Project in the
Catubig watershed area.
1.2
Scope of Work
This study covers the feasibility of a scheme for implementation of this project, site
survey and collection of data on the following:
1.3
z
Site Survey at Power Plant site
z
Present condition and action assignment of rural electrification
z
Feasibility study of rural electrification by renewable energy
Study Area
This study was conducted in the municipalities of Catubig and Las Navas, which are
located in the Northern Samar province, the mountainous region of north Samar Island.
To gather more information on case examples for renewable energy generation, the
study team visited a biogas power plant site, which is currently undergoing construction in the
Batangas province, and an existing micro hydro power plant in the Laguna province.
1.4
Study Schedule
Two site surveys were conducted for this study. The first survey was conducted to have
a meeting, gather information and collect data from the concerned government units and branch
offices during the period October 10, 2006 to October 14, 2006.
-2-
The second survey was conducted to have a meeting with concerned government
officials and visit the proposed site and some unenergized barangays in Northern Samar, the
existing micro hydro power plant in Laguna and the biogas power plant site in Batangas.
This
second survey was carried out from December 3, 2006 until December 12, 2006. The detailed
schedule of the site surveys is shown in the attached documents.
1.5
Study Team Member
Members of this study are listed below.
Table-1.1
No
Study Team Member
Name
Specialty
1
Takatoshi Nagao
Project Manager, Project Implementation Plan
2
Masahiko
Kaneko
Study of Renewable Energy
3
Yusuke Inoue
Electric Power Facility Plan
4
Kei Katayama
Rural Electrification Plan
5
Hiroki Aso
Regional Development Plan
-3-
Chapter 2
Socio-economic Development in Communities Hosting
Renewable Energy
2.1
Economic Development and Energy in the Philippines
The link between energy and the economy has never been more evident than now when
energy-related events tend to impact on a country’s economic performance.
An increase in
prices of oil, for example, is bound to immediately affect the prices of basic commodities and
utilities such as water and electricity.
The trickling effect goes on a wider scale as oil is a
primary input to run our transport facilities. Electricity is also a basic requirement to sustain our
industrial, commercial, and to a certain extent, agricultural activities. There is no doubt,
therefore, that energy is a fundamental tool in any country’s development and a priori in the
improvement of the people’s quality of life. Being aware of this fact, the government ensures
that energy development is preceded by a rationalized and integrated energy-environment and
economic planning approach.
The Philippine Energy Plan (PEP), which has a revolving time frame of ten years, is
guided and remains consistent with national development plans such as the Medium-Term
Philippine Development Plan (MTPDP) and Medium-Term Philippine Investment Plan
(MTPIP).
It is also cognizant of the country’s commitment to international agreements such as
the UN Convention on Climate Change, the Kyoto Protocol and more recently, the
Johannesburg Plan of Action for Sustainable Development. The PEP, with the most recent
edition being the 2006 PEP Update, is annually modified by the Department of Energy (DOE)
and its attached agencies to integrate vital developments in the global and domestic economy.
Thus, any PEP update carefully considers macro-economic planning set by the relevant
government agencies in the Philippines such as the National Economic and Development
Authority (NEDA) for the Gross Domestic Product, Gross National Product and Gross Value
Added rates; National Statistics Office for the population growth and the Central Bank of the
Philippines for the foreign exchange rates.
On the other hand, crude oil prices are taken from
international benchmarks.
Such is the link between energy and the economy that the Arroyo administration has
included energy independence as one of the components in its Five-Point Reform Package
together with macro-economic stability, good governance, job creation and social development.
With Philippine prospects for growth pegged at 5.5 percent in the next three years, all sectors in
government including energy are called upon to contribute their respective shares in ensuring
-4-
the country’s sustainable growth.
The DOE, the country’s energy policy making body,
commits to this over-arching goal as affirmed in its mission statement, to wit: “improving the
quality of life of the Filipino by formulating and implementing policies and programs to ensure
sustainable, stable, secure, sufficient, accessible and reasonably-priced energy.”
These are fleshed out in the two major goals as outlined in the Philippine Energy Plan
2005-2014 and affirmed in the 2006 PEP Update, to wit:
attaining energy independence or a
sustained self-sufficiency level of 60 percent by year 2010 and beyond; and, promoting the
effective implementation of power sector reforms to bring about fair and reasonable energy
prices in a competitive environment.
In realizing the 60 percent self-sufficiency goal, the energy sector has laid out plans that
will accelerate the exploration, development and utilization of indigenous energy resources,
intensify renewable energy development; increase the use of alternative fuels; and, enhance
energy efficiency and conservation measures.
In the context of the study, the discussion will focus on the strategy of intensifying
renewable energy development. Anchored on the government’s Renewable Energy Policy
Framework (REPF) 2003-2013, the goal is to double the capacity share of renewable energy
sources within the REPF time frame through the following specific objectives:
a) Be the number one geothermal producer in the world
b) Double hydro capacity by 2013
c) Be the number one wind energy producer in Southeast Asia
d) Become the solar manufacturing hub in Southeast Asia
e) Expand contribution of biomass, solar, and ocean energy by 131 MW
2.2
Renewable Energy Development in the Philippines
Hydropower
Hydro energy, as defined in the REPF, is generated from the movement of masses of
water.
Hydroelectric power plants convert energy contained in flowing water, such as rivers
and streams, into electricity.
They are classified according to various capacities as follows: a)
-5-
micro-hydro – 1 to 100 kW; b) mini-hydro – 101 kW to 10 MW; and c) large hydro- more than
10 MW.
Hydropower generation started in the country in the early 1900s in the northern
mountains of Luzon. This was followed by the construction of the Botocan hydroelectric plant
in Laguna in the 1930s but which was commissioned only during the 1940s as a result of the
war that crippled operations in the country.
During the same decade and the 1950s, more
hydroelectric plants were commissioned by the state-owned National Power Corporation (NPC).
Below is a listing of the early hydro power projects built by the NPC, the Manila Electric
Company (MERALCO), the country’s largest electric utility provider, and some private
institutions, such as the Villa Escudero Plantation and Resort (Tiaong, Quezon ) and Camp John
Hay Development Corporation (Baguio City):
a)
Early Micro-hydros
1)
VILLA ESCUDERO HP
Operator/Owner
:
Villa Escudero Plantations
& Resort
Capacity
:
75 kW
Year of Operation
:
1937
Operator/Owner
:
PHILPODECO
Capacity
:
80 kW
Year of Operation
:
1939
2.)
CALIBATO HP
-6-
b)
Early Mini-hydros
1)
Operator/Owner
:
John Hay Development Corp.
Capacity
:
560 kW
Year of Operation
:
1913
Operator/Owner
:
PHILPODECO
Capacity
:
650 kW
Year of Operation
:
1928
2)
3)
c)
CAMP JOHN HAY MHP
BALOGBOG MHP
PALACPAQUIN MHP
Operator/Owner
:
PHILPODECO
Capacity
:
400 kW
Year of Operation
:
1937
Operator/Owner
:
MERALCO /NPC (1979)
Capacity
:
16.96 MW
Year of Operation
:
1930
Operator/Owner
:
NPC
Capacity
:
32.0 MW
Initial Year of Operation
:
1941
Complete Operation
:
1950
Large Hydros
1)
2)
BOTOCAN HP
CALIRAYA HP
-7-
Current Situation
In accordance with the
REPF goals, the Philippines seeks to double its existing
hydropower capacity from 2,518 MW in 2002 to 5,468 MW in 2013 through indicative capacity
addition of 2,950 MW.
Performance Assessment
In the country’s quest for alternative clean sources of energy and correspondingly
reduced dependence on imported fuels, hydropower generation presents a vital option. In 2004,
hydropower resources contributed 15.9 percent to the country’s total power generation with the
commissioning of the 345-MW San Roque Hydropower plant in Pangasinan and 350-MW
Kalayaan 3 and 4 in Laguna.
of fuel oil (MMBFOE).
Fuel oil displacement of the sector reached 14.8 million barrels
Currently, the country has 134 hydropower plants in operation,
broken down into 21 large hydropower plants, 52 mini-hydropower plants and 61
micro-hydropower plants.
-8-
Measurable Sectoral Targets
By 2014, the hydropower sector targets a cumulative installed capacity of 3,991 MW
from hydropower resources, as outlined in the Philippine Energy Plan update 2006 (Table-2.1).
This corresponds to about 780 MW of additional capacity from the current capacity of 3,219.1
MW, and is much smaller that the target capacity addition as defined in the REPF.
Generation
of electricity will reach 14,741 GWh by 2014, thereby displacing 25.4 MMBFOE.
Table-2.1
Installed
capacity
(MW )
Luzon
Visayas
Mindanao
Gross
Generation
(GWh)
Luzon
Visayas
Mindanao
Total Imported Fuel
Oil Displacement
(in MMBFOE)
Hydropower Measurable Targets
2005
3,219.1
2006
3,219.1
2010
3,219.1
2014
3,991.1
2,209.8
11.61
997.65
8,374
2,209.8
11.61
997.65
8,563
2,209.8
11.61
997.65
12,996
2,509.8
61.61
1,427.65
14,741
4,422
35
3,917
14.44
4,611
35
3,917
14.76
8,896
35
4,065
22.41
8,819
188
5,734
25.42
Indicative Projects
Potential sites for mini and micro-hydro projects are evenly distributed in all the
country’s administrative regions.
These were identified by the DOE, NPC and the National
Electrification Administration (NEA). In 1995, the DOE conducted a water resource inventory
study to validate NEA’s and NPC’s identified potential sites for promotion to private investors.
Meanwhile, a study conducted by the United States Renewable Energy Laboratory (US-NREL)
likewise revealed that micro-hydro potential sites are well distributed all over the country.
The
study gained the support of the local government units (LGUs), non-government organizations
(NGOs), electric cooperatives (ECs) and the state-university based Affiliated Non-Conventional
Energy Centers (ANECs) by also conducting local identification projects.
-9-
Table-2.2
Indicative Hydropower Capacity Addition
Potential
Region
Project
Location
Capacity (MW)
CAR Pasil HEP
Kalinga
22.0
Talubin MHP
Mt. Province
5.6
Can-eo MHP
Mt. Province
5.9
Agbulu HEP*
Apayao
360.0
Nalatang HEP*
Benguet
75.0
Binongan HEP*
Abra
175.0
I
Upper Agno MHP*
Pangasinan
5.0
II
Adalam HEP
Quirino
46.0
Diduyon HEP*
Quirino
345.0
Abuan HEP*
Isabela
60.0
Ilaguen HEP*
Isabela
88.0
III
Dinalugan MHP
Aurora
0.5
Debutunan MHP
Aurora
0.5
IV-A Kanan HEP*
Infanta, Quezon
113.0
IV-B
Batang-Batang MHP
Palawan
3.5
Langogan MHP*
Palawan
6.8
Babuyan Island MHP* Palawan
5.6
Catuiran HEP*
Mindoro Oriental
18.0
Aglubang HEP*
Mindoro Oriental
13.6
Cabinbin MHP*
Palawan
0.8
V
Kapipian MHP
Catanduanes
3.0
Colasi MHP*
Camarines
0.96
Dugui MHP*
Catanduanes
3.5
Cawayan II MHP*
Sorsogon
2.5
Hitoma MHP*
Catanduanes
3.0
VI
Igbolo MHP*
Iloilo
4.0
Timbaban HEP*
Aklan
23.5
Villasiga HEP*
Antique
16.5
VII
Pacuan HEP
Negros Oriental
33.0
Siaton MHP*
Negros Oriental
5.4
Okoy HEP*
Negros Oriental
12.0
Sicopong HEP*
Negros Oriental
17.8
VIII
Bugtong MHP*
Samar
1.0
Amandaraga MHP*
Eastern Samar
4.0
IX
Lower Dapitan MHP
Zamboanga Norte
3.8
Salug Daku 1 MHP*
Zamboanga Sur
2.5
Salug Daku 2 MHP
Zamboanga Sur
2.5
Middle Dapitan MHP
Zamboanga Norte
4.4
Salug Daku 3 MHP
Zamboanga Sur
6.0
Salug Daku 4 MHP
Zamboanga Sur
6.0
Upper Dapitan MHP
Zamboanga Norte
3.6
Ingin MHP*
Zamboanga Norte
3.0
* With feasibility study
- 10 -
Year
Available
2011
2012
2012
2012
2014
2014
2008
2010
2011
2013
2014
2007
2010
2008
2006
2010
2010
2011
2011
2013
2006
2008
2009
2012
2012
2010
2011
2012
2007
2011
2012
2012
2009
2012
2006
2008
2008
2008
2010
2010
2011
2012
Region
X
Project
Location
Tuasan MHP
Larangan MHP
Culaman MHP
Odiongan 3 MHP*
Cabulig MHP*
Tagoloan HEP*
Impasugong HEP
Odiongan 2 MHP*
Liangan HEP
Bulanog Batang HEP*
Agus III HEP*
XI
Sibulan A
Sibulan B
Taytayan MHP
Tandik MHP*
Siguil B
Talaingod MHP
Suwawan HEP
Tamogan HEP
Camanlangan MHP
Balutakay MHP
XII
Magpet MHP*
Libungan MHP
Pulangi V HEP*
XIII
Taguibo MHP
Lake Mainit HEP
Pugo HEP*
ARMM Kanapnapan Fall MHP
* With feasibility study
Camiguin
Misamis
Occidental
Bukidnon
Misamis Oriental
Misamis Oriental
Bukidnon
Bukidnon
Misamis Oriental
Lanao Norte
Bukidnon
Lanao Norte/Sur
Davao del Sur
Davao del Sur
Compostela Valley
Compostela Valley
Sarangani
Davao del Norte
Davao City
Davao City
Compostela Valley
Davao del Sur
Cotabato
North Cotabato
North Cotabato
Agusan Norte
Agusan Norte
Agusan Norte
Lanao Sur
Potential
Capacity
(MW)
0.5
8.5
10.0
10.0
3.5
68.0
68.0
5.0
11.9
132.0
225.0
16.5
24.0
0.6
5.0
15.0
10.0
40.0
60.0
1.0
0.2
10.0
10.0
300.0
7.0
22.0
18.0
10.0
Year
Available
2008
2008
2008
2008
2009
2010
2010
2012
2012
2012
2014
2008
2008
2009
2010
2010
2010
2011
2011
2012
2012
2007
2010
2012
2008
2009
2010
2008
The 2006 Plan Update identifies 70 hydropower projects with a total potential capacity
of 2,603.5 MW (Table-2.2).
This is composed of 34 large hydropower projects, 27
mini-hydropower projects and nine micro-hydropower projects.
projects have existing feasibility studies.
- 11 -
About 37 of these indicative
Wind Power
Wind energy refers to the energy that can be derived from the wind, which can then be
converted into useful electrical or mechanical energy.
In the Philippines, there are six regions
identified with wind electric potential. These include the following:
1.
Batanes and Babuyan Island
2.
Northwest tip of Luzon (Ilocos Norte)
3.
Higher interior terrain of Luzon, Mindoro, Samar, Leyte, Panay, Negros, Cebu,
Palawan, Eastern Mindanao and adjacent islands
4.
Well-exposed east-facing coastal locations from Northern Luzon southward to
Samar
5.
The wind corridors between Luzon and Mindoro (including Lubang Island)
6.
Between Mindoro and Panay (including the Semirara and Cuyo Island
The first large-scale wind power plant in the Philippines and in Southeast Asia is
located in Bangui, Ilocos Norte.
This 25-MW plant is developed by Northwind Power
Development Corporation.
During the first wind contracting round in 2004, 16 potential wind power sites were
offered to private investors.
The estimated total capacity of these sites is 345 MW.
Six
pre-commercial contracts (PCCs) were since then issued by the Department of Energy (DOE) to
various developers.
Nineteen additional wind power sites with an estimated total capacity of 3,270 MW
were identified during the second batch.
Six private investors signified their interest in
developing some of these sites.
Solar Power
Solar energy is defined as energy derived form solar radiation which can be converted
into useful thermal or electrical energy.
Considering that the Philippines is situated near the
equator, there is a nationwide potential for harnessing solar energy.
Presently, there is a
960-kW CEPALCO solar power plant which is located in Cagayan de Oro in Mindanao and
connected to the grid.
- 12 -
There are eight solar energy programs, seven of which are funded by foreign donors.
As part of the Solar Electrification Project, a 28-kWp centralized photovoltaic (PV) plant was
also installed in Pangan-an Island, Cebu to supply electricity to about 200 households.
The Solar Power Technology Support (SPOTS) Project was designed to install solar
energy systems in about 80 Agrarian Reform Communities (ARCs).
There are 5,600 solar
energy systems completed in 154 barangays under this program.
The Environmental Improvement for Economic Sustainability (EIES) Project also
promotes the use of photovoltaic systems for rural-based electrification through the installation
of 15,000 Solar Hybrid Systems (SHSs) in the target regions, which include Regions I to VII,
the Minadanao area and the Cordillera Administrative Region (CAR).
implemented by PNOC, in coordination with the DOE.
This project is being
As of the first quarter of 2006, 9,191
SHS have already been installed.
Biomass
The Philippines has significant biomass resources which can be harnessed to develop
energy systems.
The DOE has identified a biomass (bagasse) potential of 250 million barrels
of fuel oil equivalent (MMBFOE) in the country. In terms of capacity, the country has a total
installed capacity of 235.7 MW from the different regions, with Western Visayas having the
biggest potential of 127.8 MW.
While the documentation of biomass energy systems is still an ongoing activity, the
DOE has listed down several ongoing biomass projects including the 30-MW Talisay Bioenergy
Project and the 50-MW Bioenergy Project.
There are likewise ongoing studies for the 25-MW Bais City Project, the 25-MW Capiz
Bioenergy Project, the 5-MW La Suerte Rice Hull Project and the 5-MW Inter City Rice Hull
project.
The DOE foresees the expansion of RE contribution (biomass, solar, micro hydro and
ocean) by 250 MW by year 2013.
- 13 -
2.3
Major Issues
The capital-intensive nature, long gestation period (average of seven years) and related
issues of social acceptability of large hydropower projects remain to be the sector’s biggest
challenges.
On the other hand, micro-hydro development for off-grid electrification is
hindered by high upfront costs and the need for government support and intervention.
Socio-environmental concerns
There is considerable resistance for the development of large hydropower projects due
to the potential for upstream flooding, destruction of agricultural areas and animal habitats and
disruption of communities in the affected areas.
These factors have affected the attractiveness
of large hydropower projects.
Shift in type of development
Given the many issues plaguing large hydropower projects, the logical step is to focus
on smaller, more manageable run-of-river projects.
However, such shift will have to consider
some challenges, such as a decrease in new potential capacity given the smaller scale of the
projects, intermittent supply of power and an anticipated decrease in power generation during
the summer months.
Commercialization of hydropower technology
There is a need to develop and commercialize suitable micro-hydro technology in the
Philippines, even as hydropower technology for large and small projects is proven and mature.
The Philippines remains to be dependent on imported electro-mechanical equipment for
micro-hydro projects.
The costs of these equipment vary based on kilowatt capacity.
For
instance, a 5-kW equipment with controls and metering devices costs US$11,000 while a
100-kW equipment costs US$64,500.
2.4
Government Policies and Programs
The aggressive development of the country’s renewable energy (RE) resource potential
comes as the second most critical strategy in attaining the Philippine government advocacy for
energy independence.
In recent years, the steady increase in the contribution of geothermal
- 14 -
and hydropower resources to the power generation mix has lessened the country’s dependence
on imported fuels.
In the government’s rural electrification efforts, renewable energy sources
such as solar, micro-hydro, wind and biomass resources are seeing wide-scale use.
Thus, it has
become the government’s policy to facilitate the energy sector’s transition to a sustainable
system with renewable energy as an increasingly prominent, viable and competitive option.
Along this context, the government is strongly working for the passage of House Bill
1068 entitled “An Act to Promote the Development, Utilization and Commercialization of
Renewable Energy Sources” to further boost renewable energy in the country.
The proposed
bill, now on bicameral discussions, aims to promote the development of RE to further reduce
the country’s reliance on generation systems powered by imported fuels while minimizing
exposure of the economy to price fluctuations in the international markets.
The bill will also
ensure the increase in RE use through the provision of fiscal and non-fiscal incentives to RE
developers, including mandatory generation, priority dispatch for intermittent generation and
establishment of a trust fund.
Likewise, the zero rating provided for RE-generated electricity
under the recently-implemented Reformed Value Added Tax Law (R-VAT) or Republic Act
9337 will enhance the competitiveness of RE-sourced electricity.
Specifically, for hydropower projects, the enactment of Republic Act No. 7156,
otherwise known as the Mini-Hydroelectric Power Incentives Act, in September 12, 1991
institutionalized attractive incentives for mini-hydro development, and consolidated under the
then Office of Energy Affairs the responsibility and authority for hydropower development in
the country.
The law was meant to address the financial issues plaguing the industry then in
the wake of the peso depreciation experienced by the country in the late 1980s.
Summarized
below are the important provisions of RA 7156 which are enforced to date:
a) Special privilege tax rates – Tax payable by developers/grantees to develop
potential sites for hydroelectric power and to generate, transmit and sell electric
power shall be 2.0 percent of their gross receipts.
b) Income tax holiday for seven years from the start of commercial operation.
c) Tax and duty free importation of machinery, equipment and materials – Exemption
from payment of tariff duties and value-added tax (VAT) on the importation of
machinery and equipment within seven years from date of award of contract.
- 15 -
d) Tax credit on domestic capital equipment – For developers who buy machinery,
equipment, materials and parts from local manufacturers, tax credit is granted in an
amount equivalent to 100 percent from the value of VAT and customs duties that
would have been paid to import said machinery, equipment, etc.
e) Special realty tax rates on equipment and machinery – Realty and other taxes on
civil works, equipment, machinery and other improvements of a registered
mini-hydroelectric power developer shall not exceed 2.5 percent of their original
cost.
f) VAT exemption – Exemption from payment of 10 percent VAT on gross receipts
derived from the sale of electric power whether wheeled via NPC or electricity
utility lines.
In relation to the issues presented earlier, the following are some action plans that the
DOE has indicated to pursue:
a) Information, Education and Communication to enhance public acceptability
Prior to the implementation of the hydropower projects, the DOE shall involve
all stakeholders in the decision-making process which could also include
consultations with cultural communities (since hydro projects are mostly in the
hinterlands).
consideration.
This would ensure that rights of the affected peoples are taken into
At the same time, project risks are easier to ascertain through the
joint conduct of social preparation activities.
b) Promotion of alternative hydro development
The run-of-river schemes of construction will allow for a balance of river
ecosystems while providing communities dependent on the river for their livelihood
to co-exist with hydropower projects.
In addition, the government would place
greater emphasis on projects with social and environmental issues by treating these
problems as an integral element, along with economic and financial considerations
in the decision-making process.
- 16 -
c) Commercialization of hydropower technology
With additional incentives as stipulated in the proposed RE Bill, the
commercialization of locally made hydropower equipment can be attained.
The
following measures are proposed to hasten commercialization:
1)
Establishment of a Market Service Center
The Center will assist RE producers to obtain legal papers and permits
required for RE projects.
Likewise, under the UNDP-assisted CBRED project,
there are provisions for various financing assistance options available to
developers of renewable energy projects.
The Center is also envisioned to be
the repository of database for all hydropower projects.
2)
Pursuit of technical cooperation with other countries
For small-scale hydropower development, the basic strategy for
commercialization is to encourage electro-mechanical manufacturers to set up
facilities in the Philippines and reduce the cost of importation of turbine
equipment.
There are several local turbine fabricators in the country that can
be trained to enhance their capability to manufacture turbine equipment.
The
DOE will likewise continue to seek technical and bilateral cooperation with
other countries that offer the latest expertise and technology transfer to replicate
some successful demonstration projects.
- 17 -
2.5
Impact to Host Communities
The DOE continues to fulfill its social commitment to communities hosting energy
projects through Energy Regulations (ER) 1-94 of Republic Act (RA) 7638 or the Department
of Energy Act of 1992. Other enabling legislations include the following: Republic Act 7160
or the Local Government Code and Republic Act 9136 or the Electric Power Industry Reform
Act (EPIRA) of 2001.
Energy projects include energy-generating facilities or energy resource
development activities.
Section 289 and 294 of the RA 7160 provides that the LGU shall receive 1.0 percent of
the gross sales of the preceding calendar year or 40 percent of the total collection of royalties,
taxes and other fees earned from the development and utilization of energy resources, whichever
is higher.
Eighty percent of this allocation shall be applied solely for the reduction of
electricity costs where such resources are located while the remaining 20 percent will be used
for local development and livelihood projects.
On the other hand, ER 1-94 requires generation companies and/or energy resource
developers to set aside Php 0.01/kWh of their total electricity sales as financial benefits to the
host communities.
classifications:
Funds can be accessed by proposing projects under any of the following
electrification fund (EF); development and livelihood fund (DLF); and,
reforestation, watershed management, health and/or environment enhancement (RWMHEEF).
The allocation of the fund is as follows: 50 percent of one centavo for EF and 25 percent each
for DLF and RWMEEF, respectively.
The non-monetary advantages, on the other hand, include the prioritization of load
dispatch, training and skills development, preference in employment, preference in procurement
of local supplies and sound environmental management.
The grant of financial benefits was subsequently strengthened in Section 66 of the
EPIRA and Part A, Rule 29 of the EPIRA’s Implementing Rules and Regulations. The
guidelines expanded the coverage with the inclusion of energy generating facilities having
capacities of 10 MW and below.
- 18 -
Chapter 3 Rural Electrification
3.1
Current Condition of Rural Electrification
Rural electrification in the Philippines has been adopted as a key policy of the national
government as it can improve the living standards of the people and reduce poverty by the
creation of new income sources in rural areas.
In 1960, the Philippine government declared its
stance in tackling rural electrification as a national policy, and established the Electrification
Agency (EA).
In 1969, the National Electrification Act was enacted and the EA was
reorganized to form the National Electrification Administration (NEA), with the task to
seriously undertake rural electrification.
As power distribution in the Philippines had been
carried out by private companies, the business was concentrated in highly populated urban areas
where economic efficiency is greater.
was growing larger.
Therefore, the difference between urban and rural areas
To solve this situation, NEA initiated the promotion of rural
electrification through the Rural Electrification Cooperatives (RECs1) to be established in the
local areas pursuant to the Act2.
Spurred by a substantial amount of subsidies from the national government and the
support agencies, rural electrification dramatically advanced in the 1970s, and the number of
RECs reached the current 119 in 1980.
However, there were some RECs with weak financial
foundation and many had poor collection of electricity charges.
Thus, electrification has been
carried out with many financial issues.
By 1997, electrification was completed for all municipalities, but the barangay level
electrification remained only at roughly 72%.
In order to keep promoting rural electrification,
the Philippine government launched the O-Ilaw program in 2000 and the Expanded Rural
Electrification (ER) program in April 2003.
These programs were initiated to meet the
objectives to complete electrification of all barangays by 2008 (initial target was 2004, which
was changed to 2006 and re-changed to the current target), and to reach 90% household
connection rate by 2017.
It is said that there are 41,995 barangays in the Philippines, and
roughly 8,300 (19.8%) were un-electrified as of the end of 2000. The national government is
trying to accelerate electrification by increasing the annual target for electrification to 1,500
barangays (Table-3.1).
1
2
REC changed its name to Electric Cooperative (EC) in 1993.
JICA Report of SW mission on "Rural Electrification in the Philippines (June 2004)" page 27
- 19 -
Table-3.1
1999 – 2006 Implementation Plans of O-Ilaw Program and ER Program
YEAR
ANNUAL
TARGET
CUMULATIVE
NO. OF
BARANGAYS
BARANGAY
ELECT. LEVEL
1999(actual)
2000(actual)
2001(actual)
2002
2003
2004
2005
2006
TOTAL
755
1,366
1,253
1,636
1,664
1,700
1,095
1,000
7,095
32,281
33,647
34,900
36,536
38,200
39,900
40,995
41,995
-
76.90%
80.10%
83.10%
87.00%
91.00%
95.00%
97.60%
100.00%
-
(Source: DOE, http://www.doe.gov.ph/Rep/O-ilaw/oilaw.htm)
In the Philippines, a subject barangay is deemed electrified either (1) electricity is
supplied to 10 or more households in that barangay, or (2) feeder lines have been installed in the
un-electrified barangay (electricity supply is possible, but to be electrified or not is up to the
customer). But recently DOE reformed its definition (1) electricity is supplied to 30 or 40
households in that barangay by sustainable energy such as solar power, battery charge station
(BCS), diesel power and others or (2) feeder lines have been installed in the un-electrified
barangay. Definition described in (2) is the same as the last one but the number of beneficiaries
of electrification was increased. However, even if 100% electrification is achieved on the
barangay level, many households are yet to be electrified.
In fact, an average 30 to 40
households in a barangay are connected, meaning that the barangay is electrified even if only a
part of the barangay is actually served with electricity3.
As of October 2006, of the total 41,945 barangays4, electrification has been completed
in 39,590 barangays, giving an electrification rate of 94.4% (Table-3.2).
Electrification rates
are largely different among regions: Luzon region 97.1%, Visayas region 96.0%, and Mindanao
region 87.0%.
Comparison of the electrification rate by power distributor, which is
responsible for electrification implementation, shows 93.8% for ECs, the largest in number,
followed by 98.5% for MERALCO, and 97.7% for private business/municipality/others
(Table-3.3).
3
4
Japan Electric Power Information Center, Inc "Overseas Electric Utility Industries 2003 – Philippines" pp. 543
The October 2006 data says the total number of barangays is 41,945.
- 20 -
Table-3.2
Area
Electrified
Barangays
39,590
19,888
10,982
8,720
Barangays
Philippines
Luzon
Visayas
Mindanao
(Source: DOE)
Table-3.3
Electrification Level by Region (As of 31, October 2006)
41,945
20,476
11,443
10,026
Unelectrified
Barangays
2,355
588
461
1,306
Ratio
(%)
94.4
97.1
96.0
87.0
Barangay Electrification Level by Franchise Holder (As of October 2006)
Franchise Holder
119 Electric Cooperatives
MERALCO
24 Private Investor
Owned/ LGUs/ Others
Total
(Source: DOE )
36,080
4,314
1,625
86%
10%
4%
Electrified
Completed
33,752
4,251
1,587
41,945
100%
39,590
Number of Barangay
- 21 -
Electrification
Level (%)
93.8
98.5
97.7
94.4
Challenge
2,251
66
38
2,355
3.2
Promotion Policy of Rural Electrification
Rural electrification has been carried out by concerned organizations led by the DOE, in
accordance with the O-Ilaw Program and the ER Program.
First, the Secretary of the DOE
formulates an electrification objective for the year, which is allocated to the concerned
organizations by the Program Team (PT) comprised of the DOE and other parties.
5
RECs and private power companies conduct actual implementation .
Then, the
The PT was formed
through DOE Special Order No. 2000-01-03 in January 2000 (revised by S.O. No. 2001-04-010
in 2001).
Its responsibilities include the overall planning, promotion, monitoring and
evaluation of rural electrification.
PNOC and NPC.
The PT is composed of officials from the DOE, NEA,
The Program Management Office (PMO) based in the DOE serves as the
implementing arm of the PT.
The O-Ilaw Program allows for a menu of options for participation from which donors
or prospective partners can choose. The O-Ilaw Program components include the following6:
(1) Regular electrification program of government agencies
a) Department of Energy
and its related agencies
(i) Locally-funded projects on electrification using new and renewable energy sources
(ii) Grant-in-Aid Programs
(iii) Electrification projects under ER 1-94 Fund7
b) National Electrification Administration/Rural Electric Cooperatives
c) National Power Corporation
d) Philippine National Oil Company through its Environmental Improvement for
Economic Sustainability (EIES) Project
e) PNOC-Energy Development Corporation
f) Department of Agrarian Reform through its Solar Power Technology Support (SPOTS)
Project for Agrarian Reform Communities
(2) Electrification projects of Private Investors-Owned Utilities such as Meralco, Davao Light
and Power Company, etc.
(3) Electrification projects of LGU-owned utilities
5
Japan Electric Power Information Center, Inc "Overseas Electric Utility Industries 2003 – Philippines" p. 544
The Philippine Department of Energy Website http://www.doe.gov.ph/Rep/O-ilaw/oilaw.htm
7 Financial Benefits to Host Communities under ER 1-94. One-centavo per kilowatt-hour (P0.01/kWh) of the
Electricity Sales which shall apply to Generation Facilities and/or energy resource development projects (50% for
Electrification Fund, 25% for Development and Livelihood Fund and 25% for Environment Enhancement Fund).
6
- 22 -
(4) The Independent Power Producers (IPP) Program
(5) The Adopt-a-Barangay Program
(6) Electrification through the Renewable Energy Service Company (RESCO) concept
As seen from these programs, the O-Ilaw Program and the ER Program offer
participation in rural electrification projects to organizations other than government agencies
and electric power suppliers.
The funds come from different sources such as the national
general budget, ER 1-94 fund, LGU budget, and subsidies from NGO or overseas.
IPPs are
also invited to participate with some expectation placed on their financial capability.
Some
examples of rural electrification implemented using the ER 1-94 fund are the PNOC-EDC's
electrifying roughly 10 barangays near Ormoc on Leyte Island in 2000, the US Southern
Energy's barangay electrification project near the coal-fired thermal power plant in Quezon, and
8
the Malaysia's East Asia project in Cebu .
Rural electrification is basically carried out by an entity which holds the power
distribution rights in the relevant area (Franchise Distribution Unit, e.g., EC).
However, in the
area where such FDU has declared no electrification plan in the foreseeable future in view of
economic efficiency, electrification is implemented by the Missionary electrification project.
Missionary electrification is undertaken by entities other than ECs, and they also expect private
companies to participate.
qualified third party (QTP).
as a last resort.
The entity implementing electrification in that area is called the
If there are no QTPs, the NPC-SPUG will implement the project
As Missionary electrification projects are for areas with little or no
profitability, continuous subsidies are needed and the fund from a universal charge is
appropriated.
Universal charge is imposed on every electricity end-user as a part of the
electricity charge, and its rate is decided by the Energy Regulatory Commission (ERC).
3.3
Issues of Rural Electrification
For power distribution, the country is divided into a total of 138 service districts; 119
ECs, 16 private power distributors, and 3 municipal electric power suppliers.
Of the ECs, only
15 (12.6%) have achieved 100% barangay electrification, and 75 (63.0%) have not reached 90%.
None of the ECs have achieved 100% household connection rate9.
8
9
Japan Electric Power Information Center, Inc "Overseas Electric Utility Industries 2003 – Philippines" p. 544
JICA "Survey of Donor Trend for Overseas Electrification (Philippines) September 2003" page 123
- 23 -
Electrification has two methods, one is to extend transmission/distribution grids and the
other is to utilize dispersion type power sources.
At the end of 2000, roughly 4,000 (approx.
45%) of about 8,300 barangays were located quite a distance from the existing grids 10 .
Investment efficiency in these areas is significantly low.
The grid extension is difficult due to
dispersed locations of villages and electrification cost is high because of the low income level.
Such areas have no choice but to depend on the off-grid dispersion-type power sources.
Mini-hydropower is utilized in areas where hydropower potential exists.
Other areas utilize
mini grids that use new or renewable energy sources such as solar light, wind power and
biomass.
Individual electrification by solar home system (SHS) is also promoted.
Table-3.4 shows the electrification methods used from 1999 to 2002.
Of the 5,082
barangays, 4,159 or 81.8% were electrified by grid extension, and the remaining 923 or 18.2%
ere through mini grid. Roughly 70% of the mini-grid electrification was through new or
renewable energy sources11.
Whether electrified by grid extension or by mini grid, the barangays to be electrified in
the future have a small power demand, making the electricity supply cost high. As the income
of the people living in such barangays is small, an electrification project is quite unattractive to
the power distributors.
A big issue for the future is how electrification should be promoted in
such areas from the perspective of livelihood improvement of the residents.
The DOE has other data useful for planning future electrification.
Roughly 1,700
barangays, approx. 18% of roughly 8,300 un-electrified barangays, are located in the provinces
where power plants have already been constructed.
for the demand outside the province.
These power plants mainly supply energy
It is desirable for them to contribute to promoting the
electrification of un-electrified barangays in one way or another. ER1-94 fund was established
to this end. As aforementioned, pursuant to this system, power producers are obliged to set aside
one centavo (0.01 peso) per kWh of energy generation to the DOE fund. 50% of this fund is
disbursed to energize the un-electrified barangays surrounding the power plants. It is also
possible for a power producer to construct a power-distribution grid, and in such a case, the ER
1-94 fund will be refunded later on12. At any rate, it has a significant value in planning the
10
11
12
The Philippine Department of Energy Website http://www.doe.gov.ph/Rep/O-ilaw/oilaw.htm
JICA Report of SW mission on "Rural Electrification in the Philippines (June 2004)" page 32
The Philippine Department of Energy Website http://www.doe.gov.ph/Rep/O-ilaw/oilaw.htm
- 24 -
future direction of rural electrification to physically or institutionally utilize the existing power
plants for electrification of areas surrounding the power plants.
Table-3.4
Rural Electrification by Method (1999 – 2002)
Year
1999
2000
2001
2002
Total
Extension of Grid
713
1,078
1,010
1,358
4,159（81.8%）
Isolated Small Gird
42
288
245
348
923（18.2%）
Solar (PV)
42
56
212
310
620（12.2%）
Micro Hydro
15
3
6
24 (0.5%)
Hybrid
2
2
4 (0.1%)
Generator Set
215
28
32
275 (5.4%)
Total
755
1,366
1,706
5,082 (100.0%)
１,255
(Source: JICA Report of SW mission on “Rural Electrification in the Philippines” (June, 2004) p. 32)
3.4
Effects of Rural Electrification
During the survey of last year, we visited the area in Pasil, Kalinga Province, which was
electrified through micro hydro by JICA.
We interviewed one customer and the details are as
given below:
(1) Place visited: Residence of Mr. Constantio Rosito
(2) Location:
Dangtalan (former Balangao), Pasil
(3) Summary:
i) State of electrification:
The electrification of this area was carried out in December
2004, through micro hydropower to provide 15 kW, by JICA and DOE.
of the 180 households in this area are connected.
a.m. the next morning.
Almost all
Power is supplied from 5 p.m. to 8
The operation is undertaken by the Barangay Alternative
Power Association (BAPA).
ii) Electric appliances owned:
adjacent town.
Mr. Rosito is in the police service of Balbalan, the
His house has fluorescent lamps (8 W x 5: 40 W), a refrigerator (93
W), a rice cooker, a TV, a VCR, etc.
demand is less than 200 W.
As they are not used simultaneously, the total
Fluorescent lamps of 8 W are recommended so that
electricity can be used by as many households as possible.
pesos.
One lamp costs 170
At another household whose head is a carpenter, a power saw (800 W) and a
- 25 -
power planer (500 W) were purchased after electrification.
The electricity charge is
computed using a calculation formula according to the demand.
per month.
They pay 180 pesos
Though there is no meter installed now, BAPA is looking into installing
meters, which have already been provided free of charge by the DOE.
As no meters
are installed, some residents complain that they may be overcharged.
The BAPA has
two charge collectors.
iii) Lifestyle changes after electrification:
after electrification.
People's lifestyle has significantly changed
The biggest change is the use of kerosene.
They were using
kerosene lamps and 4 liters of kerosene in 15 days costing 140 pesos.
turned out to be cheaper. Changes occurred in children's life.
Electricity
The time used for
studying lessened during the first 6 months after electrification because they were
watching TV and videos.
Recently, however, they got bored of those activities and
started to study longer than before.
There are 6 children in the family, 2 in junior
high school, 3 in elementary school, and one toddler.
happening in other households.
VCR.
The same thing seems to be
Roughly 30% of the households own a TV and a
Satellite broadcasting system can be installed for 750 pesos.
The problem
of micro hydropower is the voltage fluctuation. At one time, the heater of the
dummy load at the power plant broke down causing a rise in voltage and shutting the
lights off.
The effects of rural electrification on residents are systematically summarized in the
2004 Ex-Post Evaluation Reports regarding the Philippine NEA Rural Electrification Project13
implemented by the Japan Bank for International Cooperation from 1994 to 2001.
The Report
states that the rural electrification in the Philippines brought about the following effects14.
[Impact of Project]
For this evaluation, a survey was conducted to study the positive and negative impacts
of this project on local residents.
47% of the residents interviewed answered "very
satisfied," and 46% answered "satisfied," showing as much as 93% of the residents are
satisfied with the project.
Asked what impact of electrification they recognized, they
13
L/A was concluded in August 1994. Yen loan amount 11.4 billion yen (loan disbursed amount 9.7 billion yen).
Implementing agency: National Electrification Administration (NEA)
14 JBIC Ex-Post Evaluation Report 2004 "NEA Rural Electrification Project"
http://www.jbic.go.jp/english/oec/post/2004/pdf/2-26_full.pdf
- 26 -
responded that the project provided not only pastimes and convenience through lighting
and other electric appliances but various positive changes such as few fires, improved
working and educational environment and improved communications among family
members and neighbors.
The negative impacts of this project were the debts incurred by
household appliance purchases and electricity payment (13%) and the diminished
traditional sense of values (3%).
a) Increase in employment opportunities and income
In the barangays electrified under the project, some residents started new businesses or
increased their income utilizing electricity.
Other examples include being able to
operate the sundry store till late at night, making ice lollipops in the freezer for sale, and
opening of a bakery.
b) Improvement in educational environment
The project electrified the educational institutions in the barangays, such as nurseries
and elementary schools, as well as the general households.
In the 16 barangays
interviewed, a total of 13 nurseries and elementary schools and 4 high schools were
electrified.
In the general households, fluorescent and incandescent lamps that are much
brighter than the formerly used kerosene lamps allow for the children to study at night.
c) Improved convenience and increased pastimes
After electrification, most households purchased fluorescent lamps, light bulbs and
other lighting fixtures (93% of the surveyed).
Other electric appliances purchased that
can serve to enhance convenience and ease the burden of household chores are
refrigerators (26%), irons (16%), washing machines (8%), electric rice cookers (5%), and
electric pumps for domestic water (4%).
They also bought entertainment items, such as
TVs (54%), VCRs (24%), radios/radio cassette players (30%), karaoke machines (13%),
and video games (2%).
The residents' lifestyle changed from working in the field during
the day and coming home to sleep after the sunset to talking under the light, or visiting
neighbors to watch TV or video, or singing karaoke together.
Many households replied
that their communication within the family or with the neighbors had improved.
d) Securing less expensive, safe light source
Prior to electrification, most of the households were using kerosene lamps as a light
- 27 -
source.
After electrification, fluorescent lamps of 20 to 40 W or incandescent lamps of
40 to 60 W are used.
A 60-W incandescent lamp is 7 to 70 times brighter than a
kerosene lamp, while the former is roughly a half to one-ninth of the latter in cost.
The
kerosene lamps often caused a fire when toppled. Other problems with kerosene lamps are
bad smell from smoke, health damage including coughs and eye irritation, and soot.
Many residents think that, now that they use fluorescent or incandescent lamps, they are
worry free from fire and damage by kerosene lamp smoke.
- 28 -
Chapter 4 Outline of the Surveyed Area
4.1
Outline of Northern Samar Province
Northern Samar is part of the Eastern Visayas Region, which hosts five (5) other
provinces, namely: Leyte, Southern Leyte, Biliran, Eastern Samar and Western Samar.
Northern Samar province occupies a total land area of 3,498 square kilometers.
Northern Samar is located on the eastern part of the Philippine Islands. It is bounded by
San Bernardino Strait on the north, Samar Sea on the west, Pacific Ocean on the east, and the
provinces of Samar and Eastern Samar on the south.
It ranks thirty-fifth (35th) in size among the 74 provinces of the Philippines and accounts
for practically 1.2 percent of the total land area of the country. About 52 percent of the total
land area is covered by forest and 42 percent is classified as alienable and disposable.
Northern Samar is the gateway to the Visayas and Mindanao from Luzon. It can be
reached by 14 hours bus travel through the Maharlika Highway passing Bicol Region and
traversing the San Bernardino Strait via ferryboat in the primary ports of San Isidro and Allen.
Presently, it is already accessible to Manila via Asian Spirit Airlines servicing four flights a
week.
It can also be reached by boat from Manila and Cebu via Calbayog City, Catbalogan
- 29 -
and Tacloban City.
Some inter-island shipping companies have scheduled travel to the ports
of San Jose and Laoang.
Northern Samar covers 25 municipalities, 569 barangays and 94,410 households.
Catarman is its capital town. The province registered a total population of 500,639 in 2000
(2000 Census of Population and Housing), posting an annual growth rate of 2.11 percent. Its
population density is recorded at 143 persons per square kilometer. Majority speak the
Waray-waray dialect.
In terms of income, the province is classified as second class.
Among the
municipalities, majority or 62.5% are fifth class municipalities. Only two are considered second
and third class municipalities (Catarman and Laoang).
The major industries in Northern Samar are agriculture and fishery.
Coconut, abaca,
palay and root crops are the major agricultural crops of the province while bangus, crabs and
prawns are among its major fish/seafood products.
Other industries include furniture and
handicraft making, hat and mat weaving, brick making, oil manufacturing and soap making.
Northern Samar falls under the intermediate type climate, which has no distinct dry and
wet seasons.
4.2
The rainiest months are October to January, while the driest is the month of May.
Electric Power Situation in Northern Samar
Eastern Visayas is dependent mainly on geothermal resource, Leyte Province
host of the largest producer of geothermal energy in the country.
being the
The region hosts two (2)
geothermal power plants: the Leyte Tongonan 1, 2 and 3 geothermal power plants – the Leyte
Geothermal Power Plant (LGPP 1) with total installed capacity of 112.50 MW and dependable
capacity of 99 MW, and the Tongonan 2 & 3 (Leyte A) with a total installed capacity of
610.80 MW and dependable capacity of 578.40 MW.
The LGPP total power generation in
2005 stood at 1,929.62 GWh while Leyte A generation reached 604.04 GWh for the same year.
Excess power generation from these plants are exported to Cebu and Luzon through the
Leyte-Cebu grid and the Leyte-Luzon grid, respectively.
Northern Samar is being serviced by an electric cooperative - the Northern Samar
Electric Cooperative (NORSAMELCO) - in supplying the power requirements of the province.
In 2005, the EC sold a total of 36,271 MWh of electricty to its customers.
- 30 -
The residential
sector is the major user of electricity of the province with a 92.5 percent share in the total
electricity demand for the same year.
The electricity utilization level of the sector is expected
to post an annual average growth rate of 9 percent for the 10-year period (2006-2015).
On
the other hand, the commercial sector only registered a 5.36 percent share in 2005 with an
annual growth rate of 2 percent within the 10-year period, while the rest is shared by the
industrial sector and other users of electricity, such as public buildings and street lights.
Table-4.1 Electricity Demand
Electricity Demand
No. of Custom ers
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
Residential
33510
37670
41948
46001
50378
54995
59714
64131
68395
73001
Commercial
1985
2067
2128
2192
2279
2335
2391
2421
2450
2481
1
1
1
1
1
1
1
1
1
1
Others
818
869
888
905
930
956
962
969
982
996
Total
36,313
40,608
44,966
49,099
53,588
58,287
63,068
67,521
71,829
76,479
Industrial
NORSAMELCO has no existing bilateral supply contract with the National Power
Corporation (NPC) for the delivery of its power requiement.
of power for the province.
As such, there is no firm supply
The EC depends on its annual non-contracted purchase of power
from NPC, which is not sustainable since it would be determined by the availability of supply
from NPC not contracted with other utilities.
Given this condititon, the annual supply power
deficit would be the annual power purchase of the province.
average of 18% from 2001 to 2005.
System losses acounted at an
Projected system loss for the next 10 years is seen at a
decreasing rate from 14% in 2006 to 5% in 2015.
Meanwhile, peak demand stood at an
average of 7.4 from 2001 to 2005, which is expected to demonstrate an increasing trend within
the 10-year period – from 8% in 2006 to 17% in 2015.
7:00 p.m.
consumers.
The system peak occurs at around
The over-all system load factor is low at 58% due to the dominance of residnetial
To meet the required 13.2% reserve margin , the the electric cooperative needs
additional capacity of 1 MW from 2006 to 2009 and 2 MW from 2010 to 2015.
- 31 -
Table-4.2 Annual Power Purchase
Annual Pow e r Purchas e
Purchas e
Ye ar
(MWh)
2001
25,871
2002
30,790
2003
34,235
2004
39,224
2005
40,550
2006
42,734
2007
45,967
2008
49,776
2009
54,235
2010
59,106
2011
65,391
2012
72,459
2013
78,001
2014
83,267
2015
89,302
Table-4.3 Supply – Demand Profile
30.00
Supply - Demand Profile
(MW)
20.00
10.00
0.00
2008
2009
2 0 10
2 0 11
2 0 12
2 0 13
2 0 14
2 0 15
A dd'l C a p t o m e e t a t le a s t 13 .2 % R M
2002 2003
0 .9 2
1.0 6
2004 2005 2006 2007
1.0 6
1.0 6
1.11
1.19
1.2 9
1.4 1
1.5 4
1.7 0
1.8 5
1.9 9
2 .0 9
2 .2 4
Indic a t iv e S upply ( M W)
7 .0 0
8 .0 0
8 .0 0
8 .0 0
8 .4 1
9 .0 5
9 .8 0
F irm S upply ( M W)
0 .0 0
0 .0 0
0 .0 0
0 .0 0
0 .0 0
0 .0 0
0 .0 0
0 .0 0
P E A K LO A D ( M W)
7 .0 0
8 .0 0
8 .0 0
8 .0 0
8 .4 1
9 .0 5
9 .8 0
10 .6 7 11.6 3
- 32 -
10 .6 7 11.6 3
0 .0 0
12 .8 7 14 .0 2 15 .0 9 15 .8 4 16 .9 9
0 .0 0
0 .0 0
0 .0 0
0 .0 0
0 .0 0
12 .8 7 14 .0 2 15 .0 9 15 .8 4 16 .9 9
The barangay electrification level in 2005 stood at 67%, which can be translated to 380
barangays electrified.
The electrification level represents one of the lowest in the country
and is mainly due to the remote nature of the remaining unenergized barangays in the province.
The absence of roads also makes it more difficult to extend the distribution lines to the
barangays. The municipality of Las Navas, for example, can be easier reached by cruising the
Catubig River, a main source of transportation for the village folks from the said town.
The
EC has waived twenty-three (23) barangays from its coverage for possible Third Party
Agreements
From its 546 coverage barangays (96% of the total number of barangays), the
EC could meet its target of 100% barangay electrification level by 2008.
However, about
40% of the total household population would remain unelectrified until 2015.
Table-4.4 Level of Electrification
Level of Electrification
2006
2007
2008
2009
2010
2011
2012
2013
2014
2015
83%
92%
96%
96%
96%
96%
96%
96%
96%
96%
No . o f B arangays Energized (On-Grid)
446
493
516
516
516
516
516
516
516
516
No . o f B arangays Energized (Off-Grid)
26
30
30
30
30
30
30
30
30
30
Barangay Level (%)
Total
472
523
546
546
546
546
546
546
546
546
36%
37%
39%
41%
44%
46%
49%
52%
55%
58%
No . o f Ho useho ld Energized (On-Grid)
31,717
34,096
36,653
39,402
42,475
45,788
49,360
53,308
57,573
62,179
No . o f Ho useho ld Energized (Off-Grid)
n.a.
n.a.
n.a.
n.a.
n.a.
n.a.
n.a.
n.a.
n.a.
n.a.
Total
31,717
34,096
36,653
39,402
42,475
45,788
49,360
53,308
57,573
62,179
Household Level (%)
References:
1.
2.
3.
4.
5.
Philippine Energy Plan 2005-2014
Philippine Energy Plan 2006 Update
Renewable Energy Policy Framework
National Electrification Chronicle, 2003 - 2005
Official Website of Northern Samar (www.northernsamar.gov.ph)
- 33 -
Chapter 5 Pre-Feasibility Study of Rural Electrification by Renewable
Energy
5.1
Current Situation of Rural Electrification in Coverage Area
5.1.1 Current Situation of Rural Electrification in Northern Samar
An area for this investigation is located along the Catubig watershed area in Northern
Samar, in the municipalities of Catubig and Las Navas. Northern Samar is a province in the
Eastern Visayas region (Region VIII). As of July 2006, the level of energization for barangays
in Region VIII stood at 90.8%, with several electric cooperatives in Leyte, whose electric power
is supplied by geothermal power plant, attaining a 100% energization level. However, the
energization level in NORSAMELCO, which covers Northern Samar, is only 73.1%, the lowest
among electric cooperatives in Region VIII (Table-5.1, Fig-5.1). The energization level in
Catubig is 60.9% but in Las Navas, the level is a very low 11.3%. Thus, the acceleration of
energization has become a very serious problem (Table-5.2 , Fig-5.2).
- 34 -
Table-5.1
Status of Barangay Electrification in Region VIII
Electric
Number of Barangays
Cooperatives Covered Energized
%
Region VIII
4390
3984
90.8
DORELCO
499
494
99.0
LEYECO II
196
196
100.0
LEYECO III
285
285
100.0
LEYECO IV
245
242
98.8
LEYECO V
416
416
100.0
SOLECO
500
483
96.6
BILECO
132
132
100.0
SAMELCO I
427
366
85.7
SAMELCO II
524
482
92.0
ESAMELCO
597
472
79.1
NORSAMELC
569
416
73.1
(as of 2006,July,31)
(Source: NEA)
Fig-5.1 Status of Barangay Electrification in Region VIII
Status of Barangay Electrification in Region VIII (as of 2006,July)
90
80
70
io
n
VI
II
DO
RE
LC
O
LE
YE
CO
LE
II
YE
CO
III
LE
YE
CO
IV
LE
YE
CO
V
SO
LE
CO
BI
LE
CO
SA
M
EL
SA CO
I
M
EL
CO
ES
I
AM I
EL
NO
CO
RS
AM
EL
CO
60
Re
g
Barabgay Base Electrification Ratio (%)
100
- 35 -
Table-5.2
Status of Barangay Electrification in Northern Samar
(as of 2004.12.31)
Municipality
Energized
Allen
Biri
Bobon
Capul
Catarman
Catubig
Gamay
Laoang
Lapinig
Las Navas
Lavezares
Lope de Vega
Mapanas
Mondragon
Palapag
Pambujan
Rosario
San Antonio
San Isidro
San Jose
San Roque
San Vicente
Silvino Lobos
Victoria
Total
Potential
Number of Barangays
Households
Covered Energized
%
20
19
95.0
3,217
8
2
25.0
1,317
18
13
72.2
2,613
12
5
41.7
1,780
55
37
67.3
9,228
46
28
60.9
4,050
26
12
46.2
3,119
56
33
58.9
7,968
15
5
33.3
1,396
53
6
11.3
4,286
26
20
76.9
3,635
22
5
22.7
1,621
13
7
53.8
1,326
25
14
56.0
3,987
32
23
71.9
4,019
26
12
46.2
3,349
11
7
63.6
1,196
10
10
100.0
1,423
14
13
92.9
3,591
16
16
100.0
2,099
16
10
62.5
2,493
7
3
42.9
1,178
26
3
11.5
1,601
16
13
81.3
1,873
569
316
55.5
72,365
Cooperative
Members
House Connections
Total
%
Total
%
2,140
66.52
2,529
78.6
376
28.55
397
30.1
1,710
65.44
1,598
61.2
504
28.31
446
25.1
7,465
80.90
8,145
88.3
1538
37.98
1596
39.4
992
31.81
1104
35.4
3,707
46.52
3,905
49.0
441
31.59
476
34.1
451
10.52
479
11.2
1,565
43.05
1,624
44.7
309
19.06
374
23.1
472
35.60
471
35.5
1,985
49.79
1,927
48.3
2,181
54.27
2,259
56.2
1,396
41.68
1,470
43.9
596
49.83
629
52.6
723
50.81
665
46.7
2,155
60.01
2,291
63.8
1,356
64.60
1,385
66.0
1257
50.42
1288
51.7
195
16.55
196
16.6
12
0.75
12
0.7
956
51.04
945
50.5
34,482
47.65
36,211
50.0
Source : Northern Samar Electric Cooperative (NORSAMELCO), Inc., Bobon, Northern Samar
Fig-5.2
Status of Barangay Electrification in Northern Samar
Status of Barabgay Electrification in Northern Samar (as of 2004)
90
80
70
60
50
40
30
20
10
- 36 -
Total
Victoria
San Vicente
Silvino Lobos
San Jose
San Roque
San Isidro
Rosario
San Antonio
Palapag
Pambujan
Mapanas
Mondragon
Lope de Vega
Lavezares
Lapinig
Las Navas
Gamay
Laoang
Catubig
Catarman
Capul
Biri
Bobon
0
Allen
Barangay Base Electrification Ratio (%)
100
5.1.2 Power Supply Facilities
NORSAMELCO supplies electricity to its customers through the Wright substation
(138kV/69kV), a transmission line system with 69kV and three substations (Dalakit, Lawaan
and Allen) from the Tongonan geothermal power plant unit 1 (Steam Development:
PNOC-EDC, Generating: NPC, Output 112.5MW). NORSAMELCO covers the Northern
Samar area after receiving the electricity at the substation and distributes electricity to its
customers. Electric supply to Catubig and Las Navas is transmitted from the Lawaan substation
(69kV/13.2kV, 3.75MW) through a 30 km long distribution line (Fig-5.3).
Fig-5.3
Diagram of Transmission Line in Philippines (Northern Samar Area)
Electricity is also supplied by photovoltaic (PV) solar systems, small diesel power
generating sets and battery charging systems (BCS) in Catubig and Las Navas.
BCS put up
using Solar panel systems are supplied by PNOC-EDC and NPC. The cost for charging a
battery through the grid is 50-70 pesos while charging a battery through the PV solar system is
about 20 pesos. The diesel power system is supplied by private enterprises with a cost of 100
pesos per 10m per month and four operating hours (18:00-21:00, 5:00-6:00). Even though the
electricity rate is still expensive compared to the residents’ average income of 4,000-6,000
pesos per month, electricity demand is high as it increases the level of convenience in the life of
the residents. Even though the normal cost of the solar system panel is 75Wp per set, the
expensive 150Wp panel has nevertheless started to become popular.
- 37 -
5.1.3 Summary of NORSAMELCO
NORSAMELCO, the electric cooperative which provides
electricity to the Northern
Samar area, was established in 1977. NORSAMELCO distributes power to a total of 23
municipalities and 316 barangays out of 24 Municipalities and 569 Barangays in an area
covering 3,498km2. The only remaining municipality without electricity will be energized by
2007. As of 2004, a total of 36,211 households out of the 72,000 households had a contract to
receive the electricity (Table-5.3). The breakdown of the consumer volume of NORSAMELCO
is 67% for residential, 18% for commercial, 9% for public building, 1% for industrial and 4%
for street light (Fig-5.4).
Table-5.3
Outline of NORSAMELCO (As of 2006 Oct.)
Item
Unit
Number
Peak Load
kW
8,133
Load Factor
%
64.8
System Power factor
%
94.1
No. of Towns Covered
24
No. of Towns Energised
24
No. of Barangays Covered
569
No. of Barangays Energised
318
No. of Potential Consumers
72,365
No. of Actual Consumers
38,400
Energy Net Purchased (Monthly)
kWh
3,717,908
%
21
Average Energy Rate (Buying)
Peso/kWh
4.66
Average Energy Rate (Selling)
Peso/kWh
6.23
Peso
18,331
System Loss
Revenue (Monthly)
(Source: NORSAMELCO)
The energy distribution of NORSAMELCO in 2004 was 31,249MWh which included
72.4% for residential (Table-5.4). The latest information shows that 3,717,900kWh per month is
distributed (as of October 2006) corresponding to 44,615MWh per year. As of 2006, the
maximum electricity demand was 8,133kW (Table-5.3). With more electrification projects on
line, NORSAMELCO foresees a problem of a larger system loss. At present, the average system
loss stands at 12%. In addition to technical losses, the other sources of losses may come from
defective electric meters, etc.
- 38 -
As of 2004, the electricity selling rate of NORSAMELCO was 6.13 pesos/kWh for
Residential, 5.41 pesos/kWh for Commercial and 5.60 pesos/kWh for Total (Table-5.5). As of
October 2006, the rate increased to 6.23 pesos/kWh. NORSAMELCO pays 4.66 pesos/kWh for
electricity it purchases from the NPC (Table-5.3).
Fig-5.4
Breakdown of Consumer Numbers in NORSAMELCO (as of 2004)
Industrial, 1%
Street Light, 4%
Public Building, 9%
Commercial, 18%
Resident, 67%
(Source: NORSAMELO)
Table-5.4
Energy Distribution of NORSAMELCO(2004)
MWh
22,632
5,141
183
3,293
31,249
Type
Residential
Commercial
Industrial
Others
Total
72.4%
16.5%
0.6%
10.5%
100.0%
(Source:2005 Regional Social & Economic Trends)
Table-5.5
Electric Tariff of NORSAMELCO(2004)
Type
Peso/kWh
Residential
Commercial
Industrial
Public Building
Street Light
Total
6.13
5.41
5.45
5.46
5.57
5.60
(Source:2005 Regional Social & Economic Trends)
According to the income statement of the electric cooperative, NORSAMELCO
recorded deficits in two years.
It had a deficit of 1,550,085 Pesos in 2004 but the deficit has
been covered in recent years (Table-5.6). Fig-5.5 and Table-5.7 show the prospects for electric
- 39 -
demand and development plan, respectively, in NORSAMELCO. According to Fig-5.5 and
Table-5.7, the number of consumers and the maximum peak load will increase by 13% and 7%
per year, respectively. NORSAMELCO has formulated plans to attain its target of completing
the energization of all barangays by year 2008.
Table-5.6
Income Statement of NORSAMELCO(2004)
Operating Revenue
Operating Expense
Net Operating Income
Interest Charge
Depreciation Charge
Net Operating Income after Interest & Dep.
Other Income
Net Income (Loss)
(Source: NORSAMWELCO 2004 Annual Report)
Fig-5.5
Demand Forecast of NORSAMELCO
100,000
16.0
90,000
14.0
80,000
12.0
70,000
60,000
10.0
50,000
8.0
40,000
6.0
30,000
4.0
20,000
2.0
10,000
0
0.0
2005 2006 2007 2008 2009 2010 2011 2012
No. of Consumers
- 40 -
Peak Load (MW)
Peak Load (MW)
No. of Consumers
(Peso)
2003
151,005,569
144,958,715
6,046,854
5,650,702
5,871,375
-5,475,223
2,998,464
-2,476,759
2004
188,004,480
180,266,376
7,738,104
3,326,224
8,291,743
-3,879,863
2,329,778
-1,550,085
Table-5.7
NORSAMELCO Development Plan
Item
2005
No. of Costumers
39,044
Peak Load (MW)
9
Level of Electrification
Barangay Level
73%
No. Barangay Electrified (On-Grid)
352
No. Barangay Electrified (Off-Grid)
63
Total
415
Projected Infrastructure Requirement
Distribution/ Sub-transmission Facilities
102
Expansion (ckt-kms)
102
Rehabilitation / Upgrade (ckt-kms)
Substation Capacity (MVA)
Reactive Power Compensation Plan (MVAr)
48
Capital Investment Requirements (Million Peso
(Source: Phillipnes Energy Plan 2004-2013 )
2006
44,014
9
2007
49,617
10
2008
55,942
11
2009
63,075
12
2010
71,124
13
2011
80,329
13
2012
90,447
14
82%
382
84
466
91%
412
105
517
100%
443
126
569
100%
443
126
569
100%
443
126
569
100%
443
126
569
100%
443
126
569
125
125
64
64
94
94
87
26
31
9
8
8
9
NORSAMELCO has adopted the QTP (Qualified Third Party) concept to implement
the extension of distribution lines to some of its franchise areas. The DOE has considered the
weakness of the financing base of NORSAMELCO. PNOC-EDC provides the electricity to
surrounding areas in Leyte as it operates geothermal power plants in the area. Therefore, there is
no claim from the beneficiaries of economical inefficiencies. However, intention of
development of distribution lines depends on the QTP’s policy so that it is not so smooth to
implement. The DOE expects that development of distribution lines will be implemented not
only by PNOC-EDC but also by NPC-SPUG, NEA using public funds, and Mirant and KEPCO
using private funds.
5.1.4 Current Situation of Electrification in the municipalities of Catubig and Las Navas
A total of 28 barangays out of the 47 barangays in Catubig have been energized, while a
total of 26 barangays out of the 53 barangays in Las Navas have been energized. Both
municipalities consider electrification plans which will be implemented by QTPs (Table-5.8(1),
Table-5.8(2)). However, these plans may not be actually implemented because no measures are
taken such as assistance or penalty.
5.2
Assumption of Electric Demand associated with Rural Electrification
As mentioned in the Help for Catubig Agricultural Advancement Project (HCAAP), the
said project as financed through a yen-loan has been implemented. This project will bring
development of irrigation and drainage facilities in an area of 4,500ha and a highway with a
- 41 -
distance of 65 kilometers. As a result of this project, extensive improvements are expected so
that agricultural productivity will significantly increase from 1 ton/ha to 5 tons/ha.
This study provides for the feasibility of the effective utilization of renewable energy
resources in rural electrification. Renewable resources will be provided by micro hydro power
potential from the irrigation canal as developed by HCAAP, and by biomass energy, contingent
to increased agricultural production.
Once barangays are energized, residents will purchase electric products such as lights,
TV
and refrigerator to make living conditions more convenient, and improve livelihood
opportunities. Residents will also be encouraged to buy electric equipment such as power planer
and electric saw which will generate savings on labor power and produce high-value added
products.
Once barangays are energized, household electrical goods such as household lights, TV,
and refrigerators will become common along with street lights and pumps for water well, Ice
manufacturing stores and rice mills will likewise be installed in the barangays (Table-5.9). Thus,
a peak load of 9.6 kW is estimated for all barangays with a condition that 50 households are
energized in one barangays. According to the daily power demand in the barangays (Fig-5.6),
the load factor is estimated as 48.8%.
- 42 -
Table-5.8(1) Current Situation of Electrification of Barangays in Catubig
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
Catubig
Barangay
Population Household Electrification Plan
Barangay 1Pobl
1,119
240
Barangay 2Pobl
441
83
Barangay 3Pobl
607
122
Barangay 4Pobl
416
78
Barangay 5Pobl
370
71
Barangay 6Pobl
313
58
Barangay 7Pobl
299
64
Barangay 8Pobl
827
154
Anongo
795
155
2007
Bonifacio
332
61
2007
Boring
182
35 Energized
Cagbugna
432
76 Energized
Cagmanaba
728
113 Energized
Cagugubngan
451
84
Calingnan
976
182 Energized
Canuctan
280
48 Energized
CM Recto
477
88
D Mercader
465
97 Energized
Guibuangan
368
73 Energized
Hinagonoyan
676
105 Energized
Hiparayan
694
125 Energized
Hitapian
1,004
180 Energized
Inobururan
141
25
Irawahan
704
128 Energized
Lenoy ahan
334
65 Energized
Libon
273
47 Energized
Mag-ongon
342
53 Energized
Magtuad
876
178 Energized
Manering
221
43 Energized
Nabuluo
337
63 Energized
Nagoocan
643
120 Energized
Nahulid
198
39 Energized
Opong
590
114
Osang
244
51
2008
Osmena
290
66
P Rebadulla
339
56
Roxas
896
147
2007
Sagudsoron
435
80
San Antonio
309
55
2007
San Fransico
1,074
193
San Jose
2,348
435
San Vicente
1,671
327
2007
Santa Fe
787
138
2007
Sulitan
801
151
Tangbo
342
77
2006
Tongodnon
174
35
2006
Viena Maria
224
37
Total
26,845
5,015
(Source: Census 2000, DOE materials)
- 43 -
Fund Source
PNOC-EDC
PNOC-EDC
NPC-SPUG
PNOC-EDC
PNOC-EDC
PNOC-EDC
PNOC-EDC
NEA
Mirant
Table-5.8(2) Current Situation of Electrification of Barangays in Las Navas
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
Las Navas
Barangay
Population Household Electrification Plan
Balugo
385
80 Energized
Bugtosan
436
83 Energized
Bukid
900
189 Energized
Geguinta
408
82 Energized
Geraodo
337
66 Energized
Guyo
387
73 Energized
H Jolejole
409
82 Energized
H Jolejole District
1,477
322
L Empon
332
69 Energized
Lourdes
793
151 Energized
Lumala-og
399
89 Energized
Mabini
491
92 Energized
Mac Arthur
326
56 Energized
Palanas
164
35 Energized
Quirino District
1,748
331 Energized
Rebong
557
101
Roxas
571
99 Energized
San Andres
380
82 Energized
San Jorge
756
149 Energized
San Miguel
1,116
207 Energized
Caputoan
209
41 Energized
Cuenco
290
54 Energized
San Fransisco
654
111 Energized
San Isidro
1,666
335 Energized
San Jose
259
44 Energized
Santo Tomas
155
31 Energized
316
60 Energized
Tagan-aｙan
Victory
565
102 Energized
Bugay
621
103
2006
Bulao
935
196
2008
Catoto ogan
219
44
2006
Dapdap
1,673
296 Energized
2006
Del Pilar
858
168
2006
Dolores
143
24
2006
Epaw
179
36
2006
Hangi
521
98
2008
Imelda
296
54
2006
Lakandula
224
46
2006
Magsaysay
459
96
2008
Matelarag
261
48
2007
Osmena
206
40
2008
Paco
305
63
2006
Perez
360
64
2008
Poponton
526
104
2008
Quezon
163
35
2008
Quirino
841
159
2008
Rizal
517
90
2008
Rufino
200
35
2008
Sag-od
188
33
2008
San Antonio
228
45
2008
San Fermando
921
184
2006
Tagab iran
1,157
224
2008
Taylor
859
140
2006
Total
29,346
5,641
(Source: Census 2000, DOE materials)
- 44 -
Fund Source
Mirant
PNOC-EDC
KEPCO
NEA
NEA
KEPCO
KEPCO
PNOC-EDC
KEPCO
KEPCO
PNOC-EDC
PNOC-EDC
NPC-SPUG
KEPCO
NPC-SPUG
NPC-SPUG
PNOC-EDC
NPC-SPUG
PNOC-EDC
NPC-SPUG
NPC-SPUG
NPC-SPUG
NEA
PNOC-EDC
KEPCO
Table-5.9
Assumption of Electric Demand by Rural electrification
＜Energy Denmand in Barangay＞
<Demand>
coverage (kW) (hour)
Number of Households
50 Households
160 W
Household Light (40Wx4)
70 W
Household TV
Households Refrigerator (50L 100 W
(Refrigerator Availability)
0.3 )
(
Street Light (40WX25)
40 W
Pump for Water Well
250 W
Ice Manufacturer
1,250 W
Rice Miller
3,000 W
Total
（Peak Demand
（Base Demand
Fig-5.6
0.8
0.5
0.3
6.4
1.75
0.45
25
1unit
1unit
1unit
1
0.25
1.25
3
9.6
5.0
4
4
24
(kWh/
day)
Remarks
25.6 Peak
7.0 Peak
10.8 Peak & Base
12 12.0 Peak & Base
20 5.0 Non-Peak
20 25.0 Non-Peak
9 27.0 Non-Peak
112.4
kW 44.6 ）
kW 67.8 ）
Assumption of Electric Demand by Rural electrification (daily load curve)
Daily Power Demand in Barangay (50 Households)
12
10
Demand (kW)
8
6
4
2
0
1
2
3
4
5
6
HH Ref
7
8
9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
hour
St Light
HH Light
- 45 -
HH TV
Pump
Ice
Rice
5.3
Assumption of Electrification associated with Expansion of Distribution Line
Before initiating the study of electrification by renewable energy, a cost estimation
study to develop extension of distribution line for rural electrification is needed.
Unenegized barangays in Catubig and Las Navas are distributed in the south and east
areas. To study rural electrification by extension of distribution line in the vicinity of the
Catubig Service area, that study team needed to obtain the potential data. The population and
number of households of the barangays are shown in Table-5.10. The table includes energized
barangays as shown in Table-5.8(1) and Table-5.8(2). Barangays served by solar panel systems
and small diesel generators are considered by the government as energized.
Table-5.10
No.
47
53
14
48
27
25
35
49
24
50
Electrification Plan of Barangay
Barangay
Population
Households
Rizal
Taylor
Palanas
Rufino
Tagan-aｙan
San Jose
Epaw
Sag-od
San Isidro
San Antonio
517
859
164
200
316
259
179
188
1,666
228
90
140
35
35
60
44
36
33
335
45
Total
4,576
853
- 46 -
The specific plan for expansion of distribution line is assumed as shown in Fig-5.7. As a
result of these expansion plans, the distance of expansion of distribution line and households is
assumed as shown in Table-5.11.
The electrification cost by expansion of distribution line is assumed to consist of the
items as follows.
1. Capital cost for expansion of distribution line
2. Capital cost for installation of electric transformer and incoming line
3. Capital cost for extension of transformer at Lawaan substation
4. Operation and Maintenance cost for power distribution equipment
5. Cost for distribution loss from Lawaan substation to household
6. Power cost
Where,
As for No.1, the cost for expansion of distribution line is estimated to be USD 8,000 per
km. The annual expense rate of 0.114 is estimated based on an expected lifetime of 25
years and a discount rate of 12%.
As for No.2, the unit rate for a transformer of USD 1,600 is applied based on
NORSAMELCO’s standard specifications for transformers with 13.2kV, 240V and
15kVA.
As for No.3, the unit rate for a transformer of USD 12/kVA is applied. Even though no
expansion is needed at the Lawaan substation in this plan, this cost is estimated for future
expansion of electrification.
As for No.4, the O & M cost is assumed to be 1.5% of the construction cost
As for No.5, the distribution loss depends on the distance of the distribution line and the
electric power, so that it is estimated by the multiplication method using the electric unit
rate of NORSAMELCO.
As for No.6, the consumer price is applied which contains the generating and transmission costs
as well as the administration costs of NORSAMELCO.
- 47 -
Fig-5.7
Expansion Plan of Distribution Line
Las Navas
Mabini
Goyo
Taylor
Rizal
Hangi
San Antonio
Del Pilar
Tagab iran
Palanas
Rufino
Dapdap
San Isidro
Epaw
Tagan-aｙan
San Jose
Sag-od
Table-5.11
Section
1
2
3
4
5
6
7
8
9
10
Number of Household and Distance of Distribution Line
From
Mabini
Rizal
Hangi
Palanas
Tagabiran
Dapdap
Epaw
San Jose
Dapdap
Dapdap
Total
To
Household Population
(house)
(people)
Rizal
Taylor
Palanas
Rufino
Tagan-ayan
Epaw
San Jose
Sag-od
San Isidro
San Antonio
- 48 -
90
140
35
35
60
44
36
33
335
45
853
517
859
164
200
316
259
179
188
1,666
228
4,576
Distance
(km)
2.8
2.2
3.0
2.4
3.6
2.4
2.4
3.6
3.4
3.6
29.3
The Long-run Marginal Cost (LRMC) is estimated by the cost at block distance of
expansion of distribution line divided by the annual usage of electric power of consumer.
Table-5.12 shows the electrification cost of each area by expansion of distribution line.
As a result, the electrification cost is estimated to range from 19.8 centavos/kWh to 32.2
centavos/kWh. If the distance of the distribution line is long and the barangay is small, the
electrification cost is estimated to be more than 25centavos/kWh.
- 49 -
Table-5.12
Eenergize Plan up to each Barangay
Rizal
Taylor
Palanas
Electrification Cost by Expansion of Distribution Line
Rufino
Tagan-ayan
Epaw
San Jose
Sag-od
San Isidro San Antonio All Area-A
Calculation Methodology
90
517
140
859
35
164
35
200
60
316
44
259
36
179
33
188
335
1,666
45
228
853
4,576
(a)
(b)
Census 2000 data
Census 2000 data
(kW)
(MWh)
17.3
73.8
26.9
114.9
6.7
28.7
6.7
28.7
11.5
49.2
8.4
36.1
6.9
29.5
6.3
27.1
64.3
274.9
8.6
36.9
163.8
699.9
(c)
(d)
(a)xStandard Barangay Power Demand/100
(a)xStandard Barangay Energy Demand/100x365
(km)
(km)
(%)
(MWh)
(MWh)
2.8
29.8
0.13%
73.9
0.1
2.2
31.9
0.22%
115.1
0.3
3.0
29.4
0.05%
28.7
0.0
2.4
31.8
0.05%
28.7
0.0
3.6
31.8
0.09%
49.3
0.0
2.4
36.0
0.08%
36.1
0.0
2.4
38.4
0.07%
29.6
0.0
3.6
42.0
0.07%
27.1
0.0
3.4
37.0
0.61%
276.6
1.7
3.6
37.2
0.08%
37.0
0.0
29.3
34.5
0.31%
702.1
2.2
(e)
(f)
(g)
(h)
(i)
From Feeder Line Allocation Tabel
Distance from Laoang S/S
depend on distance & power demand
(d)/(1-(g))
(h)-(d)
Cost of Dist. Trans. Extension
('000$)
Cost of Distribution Lines Extensio('000$)
Pole Transformer
('000$)
Connecting Line
('000$)
Total Construction Cost
('000$)
0.3
22.1
2.3
6.1
30.8
0.4
17.3
3.6
9.5
30.8
0.1
24.0
0.9
2.4
27.4
0.1
19.2
0.9
2.4
22.6
0.2
28.8
1.5
4.1
34.6
0.1
19.2
1.1
3.0
23.4
0.1
19.2
0.9
2.4
22.7
0.1
28.8
0.8
2.2
32.0
1.0
26.9
8.6
22.8
59.2
0.1
28.8
1.2
3.1
33.1
2.5
234.2
21.8
58.0
316.5
(j)
(k)
（ｌ）
(m)
(n)
@12$/kVA
@8,000$/km
@1,600$(15kVA)
@85$/Household
(j)+(k)+(l)+(m)
Annual Cost of Construction.
O&M Cost
Cost of Loss Energy
Total Cost (Annual)
('000$)
('000$)
('000$)
('000$)
3.50
0.46
0.01
3.98
3.50
0.46
0.03
4.00
3.12
0.41
0.00
3.53
2.57
0.34
0.00
2.91
3.94
0.52
0.01
4.46
2.67
0.35
0.00
3.02
2.58
0.34
0.00
2.92
3.64
0.48
0.00
4.12
6.74
0.89
0.21
7.84
3.77
0.50
0.00
4.27
36.0
4.7
0.3
41.1
(o)
(p)
(q)
(r)
(n)x annuity 0.114 (25 yrs, 12%)
(n)x1.5%
(i)x(t)
(o)+(p)+(q)
Cost of Grid Expansion
Cost of Energy
Energy Cost by Grid Extension
（￠/kWh)
（￠/kWh)
（￠/kWh)
5.4
17.0
22.4
3.5
17.0
20.5
12.3
17.0
29.3
10.1
17.0
27.1
9.1
17.0
26.1
8.4
17.0
25.4
9.9
17.0
26.9
15.2
17.0
32.2
2.9
17.0
19.8
11.6
17.0
28.6
5.9
17.0
22.9
(s)
(t)
(u)
(r)/((d)
Norsamelco Tariff (6.23P/kWh) x Tariff Increase (2.0% annu
(s)+(t)
Beneficiary Households
Beneficiary Population
(houses)
(people)
Power Demand
Annual Energy Demand
Distance of Feeder Expansion
Distance from Laoang S/S
Loss rate in Dist. Line
Annual Energy to be Transmitted
Annual Energy Loss in Dist. Line
- 50 -
5.4
Assumption of Electrification Cost by Renewable Energy
5.4.1 Assumption of Electrification Cost by Micro Hydro Power Plant
As mentioned in Chapter 2, the electric demand for rural electrification is estimated to
have a peak load of 10 kW and a base load of 5kW. If all electric demand is covered only by the
micro hydro power plant, an output of 10 kW is needed. If the facility is not used efficiently
during peak load, the utilized capacity is estimated to be 46.8%. A potential discharge 0.2m3/s
and a head of 7m is essential to cover the output of 10kW generation.
On the other hand, if only the base load is to be covered by the micro-hydro power plant,
the installation of a plant with an output of 5kW is needed. In this case, the utilized capacity is
estimated as 66.5%. A potential discharge 0.1m3/s and a head of 7m is essential to cover the
output of 10kW generation.
The electrification cost by micro hydro power plant is assumed to consist of the items as
follows.
1. Capital cost of installation of Turbine and Generator
2. Capital cost of installation of distribution line (low-voltage distribution system of
240V)
3. Operation and Maintenance cost for Turbine and Generator
4. Cost of operator
Where,
As for No.1, the cost for Turbine is estimated at USD 8,000 per kW. The annual expense
rate of 0.1078 is estimated based on an expected lifetime of 45 years and a discount rate
of 12%.
As for No.2, the same unit rate is applied with the expansion of distribution line
As for No.3, the total annual O&M cost for the Turbine, Generator and distribution
facility is assumed to be 1.5% of the construction cost.
As for No.4,the
remuneration of one operator is assumed to be 4,000peso/month.
The Long-run Marginal Cost (LRMC) is estimated by all construction cost of micro
hydro power plant divided by the annual usage of electric power of consumer. The
- 51 -
electrification cost of 27.7centavos/kWh is estimated if the total electric demand of 10kW is
covered by the micro hydro power plant. Meanwhile, the electrification cost of
22.1centavos/kWh is estimated if the base load of 5kW is covered by the micro hydro power
plant.
The details of the hydro power potential from the irrigation canal constructed under
HCAAP is described in chapter 6. Accordingly, a potential of 10kW can not be anticipated so
that the installation of a 5kW micro hydro power plant is assumed as suitable. Table-5.13 shows
the results of the study.
- 52 -
Table-5.13
Micro Hydro
Generation Type
Biogas
<ALL>
(a)
Power Plant
Output
Plant Factor
Annual Generation
(kW)
(%)
(MWh)
10.0
46.8%
41.0
Energy Source
Current of Irrigation Channel
Discharge
(m3/s)
Head
(m)
0.2
7
Initial Construction Turbine & Generator
Cost Estimation
Distribution Line
Connecting Line
Total
('000$)
('000$)
('000$)
('000$)
Annual Generation Capital Cost
Cost Estimation
O&M Cost
Operator (1 person)
Total
Generation Cost
Comments
Electrification Cost by Each Method of Power Generation
Generation Cost
<Base>
(b)
<ALL>
(c)
5.0 Output
66.5% Plant Factor
29.1 Annual Generation
(kW)
(%)
(MWh)
Animal Waste
0.1 Swine
7 Daily Biogas Offtake
Heat Value
Gas Engine Efficiency
80.0
Rice Hull Combustion
(heads)
(Nm3)
(kcal/m3)
(%)
10.0
46.8%
41.0
<Peak>
(d)
5.0 Output
27.2% Plant Factor
11.9 Annual Generation
1,800
100
5,000
20%
500
28
5,000
20%
Micro Hydro & Biogas
<ALL>
(e)
Rice Hull
Harvest Area
Annual Available Rice Hull
Heat Value
Engine Efficiency
(kW)
(%)
(MWh)
(ha)
(ton/y)
(kcal/kg)
(%)
10.0
46.8%
41.0
<Hybrid>
(b)+(d)
10.0
46.8%
41.0
130
182
3,250
8%
('000$)
('000$)
('000$)
('000$)
('000$)
('000$)
30.0
4.0
8.0
1.2
3.4
46.6
10.0
2.0
5.0
1.2
3.4
21.6
Stirling Eng. & Gen.
(3.3 kW x 3units)
Rice Hull Storage
Distribution Line
Connecting Line
Total
('000$)
105
1.2
3.4
84.6
40.0 CIGER
Gas Holder
Gas engine & Generator
1.2 Distribution Line
3.4 Connecting Line
44.6
Total
('000$)
('000$)
('000$)
('000$)
5.0
1.2
3.4
114.6
('000$)
('000$)
('000$)
9.12
1.27
0.96
4.81 Capital Cost
0.67 O&M Cost
0.96 Operator (2 person)
('000$)
('000$)
('000$)
5.57
0.93
1.92
('000$)
11.35
6.44
('000$)
8.42
2.58 Capital Cost
0.43 O&M Cost
1.92 Operator (3 person)
Supplemental Fuel
4.93
Total
('000$)
('000$)
('000$)
('000$)
('000$)
13.70
2.29
2.88
0.46
19.33
10.41
(￠/kWh)
27.7
22.1 Generation Cost
(￠/kWh)
20.5
41.5 Generation Cost
(￠/kWh)
47.1
25.4
-
-
Total
Difficulty of
acquiring
necessary
swine
Difficulty of
acquiring
necessary
discharge
- 53 -
As stirling engine is in the demonstration stage,
the generation cost estimation is high. However
if the engine cost becomes lower, the generation
cost also becomes lower.
50.0
2.0
5.0
1.2
3.4
61.6
7.39
1.10
1.92
5.4.2 Assumption of Electrification Cost by Biogas Energy
The system which performs a methane fermentation process using livestock manure
from swine, cows, or poultry has been used commercially in the Philippines. These technologies
have been used as the technology for livestock manure processing from an environmental
impact point of view but marsh gas has also been used effectively from an energy usage point of
view. According to DOE officials, large and small processing system of livestock manure has
been done in more than 650 places in Philippines. An example of a large case application is at
the Maya farm, where electricity is generated by marsh gas from 60,000 hogs in a farm with an
area of 40Ha, and is used for light and refrigerator in the enclosure. The usage of simplified
digester tanks of concrete is encouraged in case of small scale farming. There have been 9
manufacturers for digester tank of livestock manure processing in the Philippines.
In recent years, cases of methane fermentation system with swine manure planned as
CDM project have been increasing in the Philippines (Table-5.14). In this case, marsh gas has
been processed by CIGAR (Covered In-ground Anaerobic Digester) which was developed by
the Bioscience Company. Thus, the system which performs a methane fermentation processing
of livestock manure has been used commercially. Swine farming has been a livelihood activity
in Catubig (Table-5.15). If the income level of the farm household is increased in association
with HCAAP, it is assumed that farm households engaged in swine farming as an auxiliary
business will also increase. Thus, biogas generation by livestock manure as renewable energy is
studied.
Table-5.14
Registered
CDM Project by Usage of Biogas in Philippines (Registered CDM Project)
Title
Host Parties
Other Parties
Methodology *
Reductions **
Ref
30-Oct-06
Gaya Lim Farm Inc. Methane Recovery
Philippines
United Kingdom of Great
Britain and Northern Ireland
AMS-III.D. ver.
9
3130
611
28-Oct-06
Uni-Rich Agro-Industrial Corporation
Methane Recovery and Electricity
Generation
Philippines
United Kingdom of Great
Britain and Northern Ireland
AMS-III.D. ver.
9
2929
609
23-Oct-06
Joliza Farms Inc. Methane Recovery
Philippines
United Kingdom of Great
Britain and Northern Ireland
AMS-III.D. ver.
9
3656
607
21-Oct-06
Gold Farm Livestocks Corporation
Methane Recovery and Electricity
Generation
Philippines
United Kingdom of Great
Britain and Northern Ireland
AMS-III.D. ver.
9
2929
612
（Source: UNFCCC CDM Project activities http://cdm.unfccc.int/Projects/registered.html）
- 54 -
Table-5.15
Current Situation of Firming of Livestock and Poultry in Catubig
(as of 2000)
Livestock /
Production
Number
Poultry
(heads)
(metric tons)
Livestock
Swine
5,200
6.50
Cattle
150
0.75
Goat
1,000
5.75
Carabao
3,197
15.90
Horse
Sheep
20
0.02
Poultry
Chicken
11,760
5.80
Duck
500
0.25
Turky
100
0.10
(Source: Materials of Catubig Municiparity)
In the case of generating by marsh gas, and similarly as with micro hydro power, biogas
generating equipment with an output of 10 kW is needed. In this case, the utilized capacity is
estimated as 46.8%. 1,800 hogs, a digester tank with a capacity of 3,600m3 and a biogas volume
of 100m3/day is needed for an electric demand of 10 kW.
On the other hand, if only the base load is to be covered by the biogas power plant, an
installation of only 5kW is needed. The utilized capacity is estimated as 11.9% but if the gas
holder uses 500 hogs only, a corresponding smaller biogas digester tank and a biogas volume of
28m3/day is need.
The electrification cost by biogas power plant is assumed to consist of the items as
follows.
1. Capital cost of biogas transaction equipment (including installation cost)
2. Capital costs of gas engine and generator (including installation cost)
3. Capital cost of installation of distribution line (low-voltage distribution system of
240V)
4. O&M cost of biogas transaction equipment, gas engine, generator and distribution
equipment.
5. Cost of operator
Where,
As for No.1, the construction cost for CIGAR is estimated as 7.4$/m3 and an annual
expense rate of 0.1195 is estimated based on an expected lifetime of 20 years and a
- 55 -
discount rate of 12%.
As for No.2, the cost of gas engine and generator is estimated with annual expense rate
of 0.1195.
As for No.3, the same unit rate is applied with the expansion of the distribution line.
As for No.4, the total annual O&M cost of CIGAR, gas engine, generator and
distribution equipment is assumed to be 1.5% of the construction cost.
As for No.5, the remuneration of two operators is assumed to be 4,000peso per person
per month.
The Long-run Marginal Cost (LRMC) is estimated by all construction costs`of the
biogas power plant divided by the annual usage of electric power of consumers. The
electrification cost of 20.5centavos/kWh is estimated if the total electric demand of 10kW is
covered by the biogas power plant. Meanwhile, an electrification cost of 41.5centavos/kWh is
estimated if the base load of 5kW is covered by the biogas power plant (Table-5.13).
As a result of this study, the electrification cost by biogas with a capacity of 10kW is
assumed as the same cost as by expansion of distribution line. However, it might be difficult to
gather 1,800 hogs for swine farming.
5.4.3 Assumption of Electrification Cost by Rice Chaff Power Plant
It is expected that agricultural productivity will increase substantially from rice
cropping, from a daily capacity of 1ton/ha to 5ton/ha under HCAAP. As a result of this, rice
chaff might be used for generating energy. Even though rice chaff is used for household cooking
in the Philippines, there is no experience of large scale usage of rice chaff. According to the
DOE, rice chaff power plant is planned in Bulacan province with a capacity of 35MW and in
Nueva Ecija province with capacity of 25-30MW.
If the study of rice chaff power plant is conducted and existing boiler technology and
steam electric generation are used, the scale of generating equipment becomes large. In fact, the
capacity of the case example mentioned above is 25-30MW, and operating rice chaff power
plant in Thailand is 10-20MW. To install the generating equipment with large capacity, large
amounts of rice chaff is needed. However, there is no committed plan of rice chaff collecting
system under HCAAP. Thus, in the current situation, rice chaff power is not suitable for rural
electrification.
- 56 -
On the other hand, Stirling engine has been coming up with small size biomass energy
using higher efficiency technology. Stiring engine is an external-combustion engine, unlike an
internal-combustion engine, and generates power from various external fuel sources such as
rubbish timber, biomass, etc.. Even if the technology of internal-combustion engine was
invented
many years ago, it has not, come into practical use, in the shadow of development of
internal combustion power. However, nowadays, the technology of external-combustion engine
has come up from the point of view of the efficient use of untouched natural resources and
environmental aspects. These days, small type systems with 5 horsepower and capacity output
of 3kW (Fig-5.8) have been tested for validation. Since a small size system is suitable for the
electrification of small barangays, the feasibility of electrification by using the Stirling engine is
studied15.
If rice chaff power is generated using a Stirling engine, it becomes advantageous to
raise economical efficiency by raising the facility utilization factor. Thus a total of 10kW output
may be generated by 3 sets of 3.3kW engines. In this case, the utilization factor is estimated as
46.8%. The specifications of the Stirling engine is shown in Table-5.16. An amount of 180 tons
per year of rice chaff is needed to generate 10kW. This amount is equivalent to the amount of
rice chaff produced from the farm with an area of 130ha and which is prepared under HCAAP
(Table-5.17).
Fig-5.8
Outline of 3kW Stirling Engine (ST-5)
Biomass Fuel Hopper
Controller
Fan
Combustion Chamber
Heater Head
（Source:
15
Compressor
Generator
Boucher of STIRLING ENGINE Co. Ltd.）
Materials and information about stirling engine has been kindly provide by STIRLING ENGINE Co.
Ltd. Kanagawa Science Park East Tower 213 3-2-1 Sakado, Takatsu-ku, Kawasaki-city, Japan,
213-0012
http://www.stirling–engine.com
- 57 -
Table-5.16
Specification of Stirling Engine
Specifications of the ST-5 Stirling Engine
Engine Type
Engine Output
Fuels Used
External Combustion, Stirling Cycle, Crank Drive
5 Horse power (Shaft), at 650 rpm
Wood, Saw dust, Husks, Corn cods, Weeds,
Other Agro-byproducts, Natural Gas
Fuel Consumption
38 kW of Heat (approximately 10 kg/h of wood)
Lubrication
Dry bearing; No oil used
Working Fluid
Air
Working Pressure
5 bar, self pressurizing
Heater Head temperature 650 ℃
Dimension
49" x 16" x 16"
Weight
440 lbs (200kg)
(Source: Stirling Engine Co. Ltd)
Table-5.17
Assumed Amount of Rice Chaff for Generating
Item
Rice Productivity
Paddy Field Area
Rice Production
Available RiceHusk Ratio
Rice Husk Weight
Available Rice Husk
Heat Value of RiceHusk
Energy Generation
Energy Generation
（*) Rainy season 5.0 t/ha,
- 58 -
Estimation
5.0
t/ha
130
ha
1,140 ton/year (*)
0.8
0.2
kg/kg Rice
180
ton/year
3,250 kcal/kg
41,270 kWh/year
113
kWh/day
dry season 3.75 t/ha.
The electrification cost by rice chaff power with Stirling engine is assumed to consist of
the items as follows.
1. Capital cost of Stirling engine and installation cost
2. Capital cost of construction of storage house for rice chaff
3. Capital cost of installation of distribution line (low-voltage distribution system of
240V)
4. O&M cost of Stirling engine, generator and distribution equipment
5. Cost of operator
Where,
As for No.1, currently, since stirling engine is under verification test, the commercial
price has not been set. Therefore, the cost of $35,000 is used as a provisional value. An
annual expense rate of 0.1195 is estimated based on an expected lifetime of 20 years and
discount rate of 12%.
As for No.2, the cost is estimated to be $5,000 and an annual expense rate of 0.1195 is
used similarly as in No.1.
As for No.3, the same unit rate is applied with the expansion of distribution line.
As for No.4, the total annual O&M cost of Stirling engine, generator and distribution
equipment is assumed to be 2.0% of the construction cost.
As for No.5, the remuneration of three operators is assumed to be 4,000peso per person
per month.
The Long-run Marginal Cost (LRMC) is estimated by all construction costs of biogas
power plant divided by the annual usage of electric power of consumers. The electrification cost
of 47.1centavos/kWh is estimated if the total electric demand of 10kW is covered by the biogas
power plant (Table-5.13).
This price is estimated to be higher than the cost of expansion of
distribution line since the capital cost of Stirling engine is provisional. Meanwhile, the
electrification cost of 20centavos/kWh is estimated if the cost of Stirling engine becomes
common and consequently attains a lower price such as $10,000. The commercial viability and
popularization of Stirling engine is expected since the cost is just the same as the expansion cost
of distribution line.
- 59 -
5.4.4
Assumption of Electrification Cost by Hybrid Generating System between Micro
Hydro Power and Biogas Power
As described in Sub clause 4.1 and 4.2, it is not expected that only micro hydro power
potential is hard to cover the number of 50 households of standard Barangay. On the other hand,
number of the firming swines are also not enough to produce the electricity by Biogas method
to cover all households. In consideration of both features, micro hydro is available to operate 24
hours and Biogas is available to stock in Gas holder, hybrid system between a micro hydro
power plant for base load and biogas power for peak load is proposed in this study.
As a result of this study total construction cost of rural electrification by hybrid
generating system between micro hydro power with 5kW and biogas power with 5 kW is
estimated to be $61,600. As the method mentioned above indicates that the annual operating
and maintenance cost is estimated to be about $10,400. The Long-run Marginal Cost (LRMC) is
estimated by all construction costs of the hybrid generating system divided by annual usage of
electric power of consumers. The electrification cost of 25.4centavos/kWh is estimated.
5.5
Selection of Candidate Barangays for Electrification by Renewable Energy
As mentioned in Chapter 3, the electrification cost for the expansion of distribution line
is estimated from 20centavos/kWh to 32centavos/kWh and there are some barangays with costs
of more than 25centavos/kWh. On the other hand, the electrification cost by hybrid generating
system between micro hydro power and biogas power is estimated as 25centavos/kWh. As a
result of this study, seven barangays in Las Navas may possibly adopt the hybrid system as
follows.
No.
1
2
3
4
5
6
7
Barangay
Palanas
Rufino
Tangan-ayan
Epaw
San Jose
San-od
San Antonio
Population
164
200
316
259
179
188
228
- 60 -
Household
35
35
60
44
36
33
45
Chapter 6 Rural Electrification Plan by Renewable Energy
6.1
Potential of Micro Hydro Power Plant
The HCAAP plan consists of constructing three irrigation facilities which include the
Catubig service area (3,565.5ha), the Bulao service area (742.2ha) and the Hagbay service area
(665.3ha), respectively. The data discharge and head of the water channel, and of the irrigation
channel at the Catubig service area were subsequently obtained in this study. Table-6.1 show
the potentials for micro hydro power generation at the Catubig service area.
As a result of this study, the possibility of micro hydro power generation was found in
four barangays, namely, Palanas, Tagan-ayam, Epaw and San Jose.
Table-6.1
Potential of Micro Hydro Power at Catubig Service Area
Site No. Discharge
(m3/s)
1
0.11
2
0.19
3
0.19
4
0.17
5
0.24
6
0.22
7
0.10
8
0.14
6.2
Head
(m)
2.6
2.8
1.5
4.5
4.2
2.0
3.0
3.4
Output
(kW)
1.7
3.2
1.8
4.3
6.0
2.6
1.8
2.8
Nearest
Barangay
San Isidro
Epaw
San Jose
Tagan-Ayan
Tagan-Ayan
Tagan-Ayan
Palanas
Rizal
Hybrid Power Generation Plan at Barangays
The respective electric power demand in each of the four barangays, namely, Palanas,
Tagan-ayan, Epaw and San Jose is shown under the Demand side column of Table-6.2. The
possible supply sources, on the other hand, and in case that power is provided for by Micro
hydro power and Biogas power, is shown under the Supply side column of Table-6.2.
In Palanas, a barangay peak demand of 6.7kW and an electric energy demand of
78.7kWh per day are anticipated. These requirements can be met by hybrid power generation,
which consists of constructing a 1.8kW micro hydro power facility along the No.7 water
channel for base load, and a supplemental 4.9kW biogas power facility, for covering the
shortfall. In this instance, a total of about 540 farmed swine (about 15 swine per stand alone)
and the installation of a CIGER digester chamber with a volume of 1,100m3 shall be needed.
- 61 -
In barangay Tagan-ayan, the expected peak demand of 11.5kW and an electric energy
demand of 134.9kWh per day are anticipated. The expected demand can likewise be met
through hybrid power generation, which consists of constructing a 6.0kW micro hydro power
plant along the No.5 water channel for base load, and an additional biogas power facility with a
capacity of 5.5kW, to cover for the shortfall. About 600 farmed swine (about 10 swine per stand
alone) and the installation of a CIGER digester chamber of 1,200m3 shall be needed.
In barangay Epaw, the daily peak demand is expected to reach 8.4kW with a
corresponding electric energy demand of 98.9kWh. Hybrid power generation, consisting of a
3.2kW micro hydro power facility along the No.2 water channel for base load, and a 5.2kW
biogas power structure for covering the shortfall, are necessary. These will require getting
manure from about 440 farmed swine (about 10 swine per stand alone) and installing a CIGER
digester chamber with a volume of 900m3.
In barangay San Jose, a peak demand of 6.9kW and electric energy demand of 80.9kWh
per day is anticipated. Once again, a hybrid power generation consisting of a 1.8kW micro
hydro power facility along the No.3 water channel for base load, and a biogas power structure
with a capacity of 5.1kW for covering the shortfall, are needed. Considering the requirements,
manure from about 580 farmed swine (about 16 swine per stand alone) and the installation of a
CIGER digester chamber with a volume of 1,200m3 are needed.
6.3
Micro Hydro Power Plant
6.3.1 Turbine for micro hydro power
With the micro hydro power turbine, which is applied to micro hydro power stations of
less than 100kW, more emphasis is placed on low cost and ease of inspection and maintenance
rather than on turbine efficiency.
The Pelton turbine, Francis turbine and S-type tubular turbine, which are also widely
used for small and micro hydro power, and only the types particular to micro hydro power are
described below.
The cross-flow turbine is used for relatively small flow with a head of 5 to 100m. The
runner is a cylindrical cage type with 20 to 30 arc shaped blades. One guide vane is divided into
two parts which are arranged axially. It maintains high efficiency in a wide load range as the
guide vanes are switched according to the load.
- 62 -
The rim-generator unit has the generator rotor installed on the circumference of the
runner blade and the generator and turbine are integrated into one piece.
The turgo impulse turbine is applied to the intermediate specific speed between the
Pelton turbine and Francis turbine. This is an old model dating from 1920’s but is now being
reconsidered for small hydro power applications. Fig-6.1 shows various types of micro hydro
power turbine.
Fig-6.1
Micro Hydro Power Turbine Types
- 63 -
6.3.2 Selection of type of turbine
The turbine type is selected on the basis of the effective head and turbine discharge,
while considering such factors as river flow, operation of the reservoir and regulating pondage.
When two or more turbine types are possible, they are determined by comprehensively studying
their cost efficiency, maintainability, etc.
Various turbines have limitation on their respective head and applicable specific speed.
The application range is determined by their adaptability to the head variation, characteristic,
strength against cavitation, etc. Turbine Selection Diagram is shown in Fig-6.2.
Effective Head
Ｈ（ｍ）
1000
1000
Pelton Turbine
Horizontal Francis Turbine
Turgo Impulse Turbine
Vertical Francis Turbine
100
100
Kaplan Turbine
10
10
Reversible pump Turbine
Cross-Flow Turbine
S-type Tubular Turbine
Submerged pump Turbine
Propeller Turbine
Propeller Turbine(Siphon)
1
0.01
1
0.1
1
10
100
Maximum Discharge Ｑ（ｍ 3 /s）
Fig-6.2
Turbine Selection Diagram
For the type of turbine, Propeller turbine was found to be appropriate in view of the
flow (0.1-0.24m3/s) and effective head (1.5-4.5m) relationship based on the turbine selection
diagram given in Fig-6.2. Thus Propeller turbine was selected for its high efficiency and proven
performance.
- 64 -
Table-6.2
Basic Specification of Hybrid Power Generating at Each Barangay
Demand Side
Barangay
Palanas
Tagan-ayan
Epaw
San Jose
Supply Side
Hydro
Energy
Daily Base
Biogas
Micro Hydro
Site production by
Energy
Generation
Potential
No. Micro Hydro
Demand
Household
s
Peak
Demand
Base
Demand
Daily
Energy
Demand
(house)
(a)
(kW)
(b)
(kW)
(c)
(kWh)
(d)
(kWh)
(e)
(kW)
(f)
35
60
44
36
6.7
11.5
8.4
6.9
3.5
6.0
4.4
3.6
78.7
134.9
98.9
80.9
55.9
95.8
70.2
57.5
1.8
6.0
3.2
1.8
7
5
2
3
Energy
Necessary Capacity of
Production
No. of Swine
Digester
by Biogas
(kWh)
(g)
(kW)
(h)=(b)-(f)
(kWh)
(i)=(d)-(g)
(Head)
(j)
(m3)
(k)
43.2
95.8
70.2
43.2
4.9
5.5
5.2
5.1
35.5
39.1
28.7
37.7
540
600
440
580
1,100
1,200
900
1,200
Note 1. Peak demand (b) is calculated by 9.6kW x (Households No./ 50)
2. Base demand (c) is calculated by 5.0kW x (Households No./ 50)
3. Daily energy demand (d) is calculated by 112.4 kWh x (Households No./ 50)
4. Daily base energy demand (e) is calculated by 79.8 kWh x (Households No./ 50)
5. Energy production by Micro hydro (g) is smaller number of either micro hydro potential (f) x 24h or daily base energy demand (e).
6. Biogas generation (h) is the balance of peak demand (b) and Micro hydro potential (f).
7. Energy production by biogas (i) is the balance of daily energy demand (d) and energy production by micro hydro (g).
8. Necessary No. of swine (j) is calculated by energy production by biogas (i) divided by 6.54 kWh/day/100 swine head.
9. Capacity of digester (k) is calculated by energy production by biogas (i) multipled by 31.0 m3/kWh/day.
- 65 -
6.4
Biogas Power Plant
As already mentioned, the CIGER (Covered In-ground Anaerobic Digester) method,
which is more common in the Philippines and which was developed by the Philippine
Bioscience Company, is considered for the biogas power plant plan. In order to protect the
penetration of digestive juice to the ground and the emission of produced gas to the air, the
chamber is covered with a 1mm-thick, high density polyethylene (HDPE) liner. The waste
material of the farm animal is stocked in the digester chamber for at least 30 days. Then, the
organic matter is broken down by bacteria, so that biogas, including methane, is produced. This
gives a BOD of more than 90% and a COD of more than 80% which account for the density of
methane becoming more than 65%. On the other hand, bacillus withers away in a temperature
condition of more than 35 degrees.
（Source: UNFCCC CDM Project Activity, Gaya Lim Farm Inc. Methane Recovery project
PDD p.5）
The biogas generating system with a CIGER chamber is being constructed by the
Sorosoro Ibaba Development Cooperative (SIDC) in Batangas province. The SIDC was
established in 1969 as a cooperative and as of the end of 2005, the cooperative had full category
members totaling 3,834 and supporting members numbering 4,976. The activities of SIDC
include stock growing, distribution, rice milling and sales of goods. SIDC also
consistently maintains a swine population of approximately 30,000 throughout the year.
Two years ago, SIDC started the study of fermentative treatment with swine’s manure, from an
environmental perspective and considering digestive gas and usage of organic manure. At
present, a big gas power generation system is being constructed with funding support from the
British government. This system covers the following processes: manure is produced from
8,000 swine; the manure is digested in the CIGER chamber (30m x 90m x depth of 6m), where
- 66 -
biogas with an average daily volume of 400-500m3 is produced; the gas is collected in the tank
to generate 75kw of electricity; and the electricity is distributed to the office building of SIDC
and some households in the vicinity. The generating system will be completed by 2007. The
swine manure is gathered automatically using a drain system.
The total construction cost of 6 million pesos is broken down as: 4 million pesos for the
digester chamber, and 2 million pesos for construction.
The generator is procured from the
United States of America with a price of 1.3 million per set. The generated electricity is
distributed to some households (50-100 households, 200-300 residents) in the barangay. At the
moment, electricity is being distributed by MERALCO. However, a reduction in electricity
tariff is expected with the potential use of biogas power.
Aside from swine, manure from poultry and cows may additionally be considered. For
instance, chicken manure produces biogas more efficiently than manure from swine. However,
due to the local dry conditions, manure from poultry has been utilized better as fertilizer on
commercial basis, than for energy use. Therefore, manure of swine is still the most efficient fuel
source for biogas energy in the Philippines.
Considering the specifications of SIDC’s system, manure from 500 swine and a biogas
digester chamber with a volume of 1,010m3 shall be needed to generate an output of 5kW.
These are expected to result in the production of 28m3 of biogas per day and the generation of
about 32.7kWh of electric energy. Table-6.4 shows that comparison of biogas generation in
Philippines and Japan.
Table-6.3
Basic Specification of Biogas Power Generation
Item
Swine number
Biogas Production
Heat Value of Biogas
Daily Energy of Biogas
Output Power
Generation Hour per day
Energy Prod. by Swine No.
Capacity of Digester
Digester cap. by Energy prod
Estimation
500
head
28
m3/day
5,000 kcal/m3
32.7
kWh/day
5
kW
6.5
hours
6.5
kWh/day/100head
1,010 m3
31.0
m3/kWh/day
- 67 -
Table-6.4
Comparison of Biogas Generating in Philippines and Japan
Item
Bio Materials
Animal Waste
Digester
Type
Capacity
Daily Biogas Offtake
Heat value
Gas Holder
Capacity
Engine
Capacity
SIDC Cooperative
(Philippines)
Yagi Bio-Ecology Center
(Japan)
Swine
8,000 (heads)
Cow, Swine etc.
86 (t/day)
CIGER
16,200 m3
30m×90m×6m(D)
450 m3
around 5,000 kcal/m3
(Methane content 65%)
ＢＩＭＡ
2,100 m3
14mφ×17.7m(H)
2,120 m3
4,780 kcal/m3
500 m3
unknown
220 kW
75kW×2
80kW×1
28.1%
3,500 kWh
75 kW
Heat Efficiency
Daily Electricity Generation
unknown
Project Cost
Digester
Gas Engine
Total
6.0 million Peso
1.3 million Peso
7.3 million Peso
1,048 million Yen
Source
Hearing at SIDC
(Note: CIGER;Covered in ground anaerobic reactor）
Fig-6.3
350 m3
Broacher of the Center
Biogas Generating System
Pigpen
Gas Holder
CIGER
Electricity
Gas Engine & Generator
- 68 -
Chapter 7 Profile of the Project
Profile for Rural Electrification Program by Renewable Energy in
The Mountainous Region of Northern Samar
1. Sector
2. Project site
Energy
Catubig and Las Navas Province, Mountainous
Region in Northern Samar, Philippines,
3. Agency in charge of implementation
Philippine National Oil Corporation ;PNOC
4. Background and Purpose
The Northern Samar province in the Eastern Visayas region, which is the study area for this
feasibility study on rural electrification, is one of the underdeveloped areas in the Philippines. Its per
capita income level is less than 50% of the average per capita income level in the Philippines. Since
the electrification rate of households in the northern mountainous area is only less than 20%, it has
targeted to increase the electrification rate in order to boost the growth of agricultural activity and
the development of the tourism industry.
This study covers the feasibility of rural electrification by renewable energy, such as micro hydro
power supplied from the potential of the Catubig River and irrigation facilities and biomass power
energy supplied from agricultural products.
The increase in agricultural products is an expected
outcome of the Exclusive Agricultural Development Project in the Catubig watershed area.
5. Outline of Project
(1)
Name
; Rural Electrification Program by Renewable Energy
(2)
Maximum Output Generated by Hybrid Power System
Palanas barangay: P=6.7kW (Micro Hydro: 1.8kW, Biogas: 4.9kW)
Tagan-ayan barangay: P=11.5kW (Micro Hydro: 6.0kW, Biogas: 5.5kW)
Epaw barangay: P=8.4kW (Micro Hydro: 3.2kW, Biogas: 5.2kW)
San Jose barangay: P=6.9kW (Micro Hydro: 1.8kW, Biogas: 5.1kW)
6. Project implementation term
F/S to completion of construction ; approx two years（Construction period : a half year）
7. Expected benefit and beneficiary
Beneficiary ; Local residents
Benefits ; Efficient use of Livestock Manure, Employment effect brought by construction,
Development of local industry after electrification,
Reduce poverty by productivity improvement
8. Expected influence to environment
9. Expected cost
Almost no influence
About 0.5million dollars
- 69 -
- 70 -
Appendix 1
Schedule for Field Investigation
- 71 -
- 72 -
Schedule for Field Investigation
(1st Field Investigation)
Days Night
1
2
3
Date
Week
1 2006.10.10 Tue
From
(Via)
Fukuoka
By
To
Air
Manila
Departure
Meeting with West Jec Resident Coordinator
Manila
Meeting with DOE Energy Utilization Management
Bereau Director
Meeting with PNOC-EDC Engineering Design and
Construction Department
Manila
Meeting with NIA Design and Specfications
Department Office-in-Charge
Data collection at Bureau of Agricultural Statistics
Data collection at National Statistic Office
Manila
Meeting with DOE Energy Utilization Management
Bureau (JICA Experts)
Meeting with PNOC-EDC Assistant to the President
Meeting with PNOC-EDC Engineering Design and
Construction Department
2 2006.10.11 Wed
3 2006.10.12 Thu
4
4 2006.10.13
Fri
5
5 2006.10.14
Sat
Manila
Air
Fukuoka
- 73 -
Activities
Arrival
Schedule for Field Investigation
(2nd Field Investigation)
Days Night
1
2
3
4
5
6
7
Date
Week
1 2006.12.03 Sun
From
(Via)
Fukuoka
By
To
Air
Manila
Departure
Meeting with West Jec Resident Coordinator
Manila
Meeting with DOE Energy Utilization Management
Bureau Director
Meeting with NIA Design and Specfications
Department Office-in-Charge
Meeting with NPC-SPUG Vice President
2 2006.12.04 Mon
3 2006.12.05 Tue
Manila
Air
4 2006.12.06 Wed
Catarman
Meeting with NIA Catubig Agricultural Project Office
Meeting with Las Navas LGU Office
Survey for Catubig irrigation dam site
Survey for Pinipisakan Fall
Survey for Energized Barangay (Dapdap)
Survey for Unenergized Barangay (Epaw)
Catarman
Meeting with NIA Catubig Field Office
Meeting with Catubig LGU Office
Survey for Lawaan Substation (NORSAMELCO)
Meeting with NIA Catubig Consultant Office
Meeting with NORSAMELCO
Meeting with Eastern Philippines University
Catarman
Air
Manila
Manila
Car
Batangas
5 2006.12.07 Thu
6 2006.12.08
7 2006.12.09
Fri
Activities
Batangas
Car
Manila
Manila
Car
Laguna
Laguna
Car
Manila
Sat
Meeting with DOE Electric Power Industry
Management Bureau Director
Meeting with DOE Rural Electrification Adm. & Mgt.
Division
Meeting with PNOC-EDCEngineering Design,
Procurement & Construction Department
Meeting with NIA Administrator
Meeting with Sorosoro Ibaba Development
Cooperative
Survey for Biomass Powerstation site (Under
construction)
Data collection at National Statistic Office
Survey for Balugbog Hydropower Plant
Meeting with Philippine Power and Development
Corporation
Survey for Villa Escudero Hydropower Plant
8
8 2006.12.10 Sun
Manila
Making for field investigation report
Collection data arrangement
9
9 2006.12.11 Mon
Manila
Meeting with EDCOP (Philippine consultant)
Meeting with JBIC Manila
Meeting with DOE Energy Utilization Management
Bureau (JICA Experts)
10
2006.12.12 Tue
Manila
Air
Fukuoka
- 74 -
Arrival
- 75 -
Appendix 2
Interviewed Persons List
- 76 -
Interviewed Persons List (No.1)
Name
Post
Position
Dr.Guillermo R. Balce
Department of Energy
Undersecretary
Mr. Mario C. Marasigan
Ditto
Mr. Ronnie N. Sargento
Ditto
Ms.Mylene Capongcol
Ditto
Ms.Marissa Mariano
Ditto
Mr.Sherwin Adeva
Ditto
Mr.Elmer Casao
Ditto
Mr.Rodel Padrique
Ditto
Mr. Lorenzo S. Marcelo
National Power Corporation
Vice President(Small Power Utilities Group)
Mr. Noel D. Salonga
PNOC Energy Development
Corporation
Assistant to the President
Energy Utilization Management Bureau
Director, Officer-in-Charge
Renewable Energy Management Division
Officer in charge
Electric Power Industry Management Bureau
Director
Electric Power Industry Management Bureau
Senior Science Research Specialist
Electric Power Industry Management Bureau
Senior Science Research Specialist
Electric Power Industry Management Bureau
Science Research Specialist
Electric Power Industry Management Bureau
World bank consaultant on rural power project
Engineering Design Procurement and Construction
Department Manager
Construction Department
Superintendent
Corporate Plannung
Manager
Mr. Martin Jude Lacambra Ditto
Mr. Ronnie Andador
Ditto
Mr. Erudito S. Recio
Ditto
Mr.Danilo H. Cruz
Ditto
Process Design Supervisor
Mr.Arturo C. Lomibao
National Irrigation
Administration
Administrator
Mr. Rodolfo D. Gales
Ditto
Ms. Proserpina Mariano
Ditto
Mr.Reinerio E. Irinco
Ditto
Project Manager(HCAAP-IDC)
Mr.Prisco Buco
Ditto
Project Engineer(HCAAP-IDC)
Mr.Abner Morales
Ditto
Project Engineer(HCAAP-IDC, Catubig)
Mr.Romualdo Saises
Las Navas LGU
Municipal Engineer
Dr.Felipe Gavino
Las Navas LGU
Municipal Engineer
Mr.Antonio Adella
Catubig LGU
Planning Officer
Mr.Lidany Cornillez
University of Eastern
Philippines
Engineer
Design and Specifications Department
Office-in-Charge
Design and Specifications Department
Senior Engineer
- 77 -
Interviewed Persons List (No.2)
Name
Post
Position
Mr.Henry Banjawan
Northern Samar Electric
Cooperative, Inc.
Engineer
Mr.Roy Sosa
Ditto
Engineer
Mr.Rico B. Geron
Sorosoro Ibaba Development
Cooperative
General Manager
Ms.Marife Dimaano
Ditto
Executive Assistant
Mr.Ramon Achacoso
Mr.jaime Iporac
Mr.Hiroshi Togo
Philippine Power and
Development Corporation
Villa Escudero Hydro Power
Station
Japan Bank for International
Cooperation
General Manager
Engineer
Chief Representative in Manila
Mr. Jun Tamakawa
Department of Energy
Energy Utilization Management Bureau
JICA expert (Tokyo Electric Power Company)
Mr.Jose U. Jovellanos
Engineering and Development
Corporation of the Philippines
Chairman
Mr.Restituto A. Arbolente Ditto
Vice President(Power & Industrial)
Mr.Wilfredo A. Osabel
Ditto
Vice President(Agri-Infrastructure)
Mr.Teofilo Malicse
Ditto
NIA HCAAP Engineer
Mr.Ben Ibuna, Jr
Ditto
NIA HCAAP Engineer
- 78 -
- 79 -
Appendix 3
Photos
- 80 -
Boatslip of Catubig
Boatslip of Catubig
River Condition of Catubig River
(Downstream)
River Condition of Catubig River
(Downstream)
River Condition of Catubig River
(Upstream)
River Condition of Catubig River
(Upstream)
- 81 -
Intake Dam Site
(JBIC Catubig Agricultural Advancement Project)
Upstream of Intake Dam
Intake Site
Unenergized Barangay
(Right side of Intake Dam)
Unenergized Barangay
(Right side of Intake Dam)
- 82 -
Pinipisakan Falls
(Downstream of Intake Dam site)
Pinipisakan Falls
(Downstream of Intake Dam site)
Downstream of Pinipisakan Falls
Boatslip of Pinipisakan falls
Rest Area of Pinipisakan Falls
- 83 -
Las Navas LGU Office
Las Navas Town
Energized Barangay (Dapdap)
Energized Barangay (Dapdap)
Energized Barangay (Dapdap)
Rice mill (Dapdap)
- 84 -
Unenergized Barangay (Epaw)
Unenergized Barangay (Epaw)
Diesel generator 3kW (Epaw)
Diesel generator 3kW (Epaw)
University of Eastern Philippines (Catubig)
Old Church (Catubig)
- 85 -
NORSAMELCO Substation (Catubig)
NORSAMELCO Substation (Catubig)
Biogas Powerstation of Under construction
(SIDC)
Pig Farm (SIDC)
Covered In-ground Anaerobic Digeter of
Under construction (SIDC)
- 86 -
フィリピン国サマール島北部山間地域における
再生可能エネルギーによる地方電化促進計画可能性調査
和文要約
- 87 -
- 88 -
１.
背景と目的
フィリピン国においては、地方電化は貧困撲滅につながり人間生活の質的向上に寄与す
るため、政府の最重要政策の一つとして 2008 年のバランガイ（村落）電化率 100％を目標
に地方電化を推進しているところである。
フィリピンでは、人口の約４割を占める貧困層の約３分の２が地方部の農民・漁民であ
ると言われている。したがって、地方電化の実現は農村部での貧困軽減、都市部と地方農
村部の格差是正など農村地域における住民の生活水準向上や新しい収入源の創造を生み出
すものと期待されている。
今回、地方電化調査の対象としたフィリピン中部ビサヤス地方サマール島の北サマール
州は、フィリピンの中でも、経済・社会開発の最も遅れた地域の一つであり（フィリピン
全７０州のうち約２０を数える貧困州の一つ）
、住民一人当たりの所得水準が全国平均の５
割未満となっている。また、北部山間地域は、世帯数から見た電化率は 20%以下でフィリピ
ンの中でも最も開発が遅れている地域であるため、再生可能エネルギーを利用した地方電
化を図り、農業生産の拡大や観光産業の発展を目指している。
同州の産業は農業が主体であり、米、とうもろこし、ココナツ、バナナ、キャッサバな
どが主な収穫物である。しかし、農業が主な収入源であるにもかかわらず、米の州内自給
が達成されておらず、近隣のレイテ州等からの移入に頼っている状況である。また、排水
状況が悪いため住民が住血吸虫病にかかるなど、劣悪な保健衛生状態も開発の妨げとなっ
ている。さらに、当地域の道路は未舗装のため雨季に水没するなどほとんど通行が出来ず、
農産物を市場に運搬することもままならず、収入確保の道まで閉ざされている状況である。
このような状況のもと、国際協力銀行は北サマール州カトゥビッグ川流域のカトゥビッ
グ町、ラスナバス町において、「フィリピンカトゥビッグ農業総合開発事業」を円借款事業
として支援することとなった。本事業は、かんがい施設を中心とする農村基盤整備を行う
ことにより、同地域における米を中心とする農業生産性の向上と農産物の増産を図り、ひ
いては地域農民の所得向上、保健・衛生状態の改善に寄与することを目的とするものであ
る。本事業は今年度着手され 2008 年に完成する見込みであるが、事業の進捗にしたがって
基礎インフラの整備が進み、さらには貧困層の生活の質的向上が見込まれるため、それに
伴う電化の促進が望まれているところである。
本調査では、フィリピン国サマール島北部を流れるカトゥビッグ川（Catubig River）流
域の未電化村落地域において、再生可能エネルギー、特に同河川やかんがい施設が持つ水
力発電ポテンシャル及び当地域で実施される農業総合開発事業による農産物の増産に伴っ
て発生するエネルギーであるバイオマスを利用した地方電化プロジェクトの促進可能性検
討を行うものである。
- 89 -
２.
再生可能エネルギー開発と地域社会
2.1 フィリピンの経済発展とエネルギー
フィリピンにおいては、今後 3 年間で 5.5％の経済成長が見込まれており、エネルギーは
国の経済発展に不可欠な要素として今後の方策が検討されている。
2006 年のフィリピンエネルギープランでは、輸入化石燃料依存型エネルギー構造からの
脱却を促進するため、2010 年までにエネルギー自給率を 60％とすることを目標としている。
また、環境負荷の少ない国産エネルギーの開発と利用を積極的に推進しており、特に原油
価格が高騰している現在の状況も考慮のうえ再生可能エネルギーによる電源開発を下記に
示す国の重要なエネルギー政策として位置づけている。
・世界で一番の地熱エネルギー開発国になること。
・2013 年までに水力エネルギー開発量を 2 倍にすること。
・東南アジアで一番の風力エネルギー開発国になること。
・東南アジアにおけるソーラー設備製作の拠点となること。
・バイオマス、太陽光、海洋エネルギーの拡大を図ること。
2.2 フィリピンの再生可能エネルギー開発
フィリピン国内の再生可能エネルギーの開発は、現在積極的に進められている地方電化
プログラムの中でオフグリッド電源、更には環境保護面から環境負荷の少ない電源として
重要な位置付けとなっている。特に今後は水力、地熱、バイオマス、太陽光、風力などを
中心に積極的に導入される計画となっている。
(1) 水力
フィリピンの水力発電施設は国家の電力系統に 3,219MW の電力を供給している。水力発
電は、信頼できる電力供給源であり、国の電力需要に対しかなりの貢献をしてきている。
フィリピンエネルギープランでは、下表に示すように 2014 年までに 780MW の新たな開発
を行い電力供給量を 3,991MW にする目標を掲げている。
表−1 水力発電開発目標
2005
(MW )
2006
2010
2014
3,219.1
3,219.1
3,219.1
3,991.1
2,209.8
2,209.8
2,209.8
2,509.8
11.61
11.61
11.61
61.61
997.65
997.65
997.65
1,427.65
8,374
8,563
12,996
14,741
4,422
4,611
8,896
8,819
35
35
35
188
Mindanao
3,917
3,917
4,065
5,734
総輸入石油等価換算量
14.44
14.76
22.41
25.42
設備容量
Luzon
Visayas
Mindanao
(GWh)
発電量
Luzon
Visayas
(in
MMBFOE)
- 90 -
(2) バイオマス
バイオマスエネルギーの開発も期待されており、エネルギー省は国全体で石油換算にし
て 250 百万バレルのポテンシャルがあると推定している。
既存バイオマス発電設備容量は 235.7MW でそのうち西ビサヤス地方が 127.8MW を占めて
いる。現在、ネグロス島の 2 箇所で 30MW と 50MW のバイオエネルギー発電所が建設中であ
り、4 箇所のプロジェクトが進行中である。
(3) 太陽光
フィリピンは赤道に近いことから全国的に太陽エネルギーの潜在量は大きい。
フィリピン政府は、太陽エネルギー技術サポートプロジェクトとして、約 80 の農業組合
組織にソーラーシステムを設置することとしており、現在 154 のバランガイで 5,600 箇所
の太陽光発電設備が設置されている。また、環境改善プロジェクトとしてエネルギー省と
PNOC が共同してルソン島北部コルディリア地域とミンダナオ島においてソーラーハイブリ
ッドシステムの導入を進めているところである。
(4) 風力
フィリピンでの風力開発有望地域は以下に示すとおりである。
・北部ルソンのバタネス、バブヤン諸島
・ルソン島北東端
・ルソン、ミンドロ、サマール、レイテ、パナイ、ネグロス、セブ、パラワンの内
陸山岳部
・北部ルソンから南部サマールの東海岸
・ルソン島とミンドロ島の間
・ミンドロ島とパナイ島の間
フィリピンで最初の大規模風力発電所（25MW）は、北部ルソン島イロコスノルテで開発
された。その後 2004 年には 16 箇所で合計 345MW の風力発電開発が計画された。また、最
近では 19 箇所で合計 3,270MW の開発が計画されている。
2.3 政府の政策とプログラム
フィリピン国における再生可能エネルギーの積極的な開発は、フィリピン政府がエネル
ギー自給のために達成しなければならない重要な戦略である。近年、電源構成における地
熱と水力発電の確実な増加は、輸入燃料への依存を減少させている。政府の地方電化施策
においても、ソーラー、マイクロ水力、風力、バイオマス発電は再生可能エネルギー資源
として利用が拡大されている。このように優れた特徴を持つ再生可能エネルギーが持続可
能なシステムに移行することが出来るよう促進することは重要な政府の政策となっている。
政府はこのような背景のもと、「再生可能エネルギー資源開発、利用、商業化促進法案」
の下院議会通過を強力に進めている。国際市場での価格変動が経済に影響を与えないうち
にエネルギーシステムにおける輸入燃料への依存を減らすために、再生可能エネルギー開
発を推進する目的でこの法案の提案を行い現在上下院で協議しているところである。この
法案の成立によりは再生可能エネルギーの使用が増加することは確実である。同様に最近
実施された改正付加価値税法あるいは共和国法 No9337 のもと再生可能エネルギーの非課税
措置は再生可能エネルギーによる電化の競争力を高めることになる。
- 91 -
2.4 地域社会への影響
フィリピン政府は、発電所の建設が遅滞している事態に対処するため、1990 年代に２つ
の建設促進策を策定した。
（地方自治法による制度）
第１の政策は 1991 年成立した地方自治法による制度である。これによると、発電事業者
は事業による売上げ１％、または国富税、ロイヤリティ、または料金の 40%を地元自治体に
おさめる必要がある。地元自治体は次の 2 つの方法で発電事業者から得られた売り上げを
使用することができる。この収入は、80%を住民の電気代の助成金や配電線のリハビリなど
を通じ、地元の電気代を下げるのに使用することができる。また、残る 20％は開発と生活
向上プロジェクトに使用することができる。1992 年から 2004 年の間に水力開発からの国富
税により徴収された総売り上げは 1,019,715,354.53 ペソである。
ただし、有識者によると、この政策は担当者の実施能力と評価能力の欠乏によってうま
く機能していないと評価されている。地元自治体の行政境界のわかる正確な地図の欠如、
基金を管理する国家予算当局の基金の執行の遅れ、いくつかの自治体職員の国富税体系に
対する認識不足などがこれらの原因となっている。
（ER 1-94 による利益還元）
2 番目の政策は、エネルギー省令（Energy Regulation(ER)）1-94 として発電所地元自治
体に対する利益還元制度である。この省令によると発電事業者は、販売電力量 1kWh 当た
り 0.01Peso を積み立てなければならない。この資金は次の割合で次の基金に充当される。
①電化基金(Electrification Fund)<50%>
この電化基金は、発電所のため住民移転が行われた地域、発電所立地集落（バ
ランガイ：Barangy）、立地市（Municipality or City）、立地県（Province）、
立地州（Region）の順に、各地域の電化事業に当てられる。
②開発・生計基金(Development and Livelihood Fund)<25%>
この開発・生計基金は、地元地域の福祉の向上プログラムに使用される。この
基金は、住民移転地域：5%、発電所立地集落（バランガイ）：20%、立地市：
35%、立地県：30%、立地州 10%で配分される。
③植林・流域管理・保健・環境向上基金(Reforestation, Watershed management,
Health and Environment Enhancement Fund)：<25%>
この基金は文字通り、地元自治体における植林・流域管理・保健・環境の向上
のために使用される。配分方法は開発・生計基金と同じである。
ER 1-94 基金の資金量は 2005 年 3 月には 3,360,000,000 ペソに至っている。うち
1,500,000,000 は積立の義務量であるため、残る 1,800,000,000 ペソが地元自治体で利用可
能となっており 1,877 件のプロジェクトが ER 1-94 資金で承認され完成された。
- 92 -
３.
地方電化の状況
3.1 地方電化の現状
フィリピンにおける地方電化は、農村及び遠隔地域における住民の生活水準の向上や新
規収入源の創出により貧困削減につながるとして、政府の重要政策として取り上げられて
きた。フィリピン政府は 1960 年に国策として地方電化に取り組むことを宣言し、電化庁を
設立した。さらに 1969 年、地方電化法を制定し国家電化庁（NEA）に改組し、地方電化に
本腰を入れることとなった。フィリピンの配電事業は民間会社によってなされていたため、
経済性の高い人口集中地区の都市部に集中し、都市部と地方部との格差が広がっていた。
このため、NEA では法に基づき地方に設立される地方電化組合を通じて地方電化を推進し
ていくこととなった。
1970 年代には政府と援助機関からの多額の援助により地方電化は急速に進展し、1980
年には電化組合数は現在の 119 組合に至った。しかし、一方で財政基盤の脆弱な電化組合
が設立され、また、電気料金の徴収率が悪い組合も多数あり、財務面では多くの課題を抱
えながらの電化の拡大が行われてきている。
1997 年には国内のすべての町（Municipality）レベルでの電化が達成されたが、バラン
ガイ（村落：Barangay）レベルでの電化率は約 72%にとどまっていた。このため、フィリ
ピン政府は引き続き地方電化を推進するため、2000 年に O-ILAW と称する地方電化推進プ
ログラムを開始し、2003 年 4 月からは新たに ER（Expanded Rural Electrification）計画
をスタートさせた。これは「2008 年にまでにすべてのバランガイの電化達成」を目標に掲
げるとともに(当初は 2004 年目標だったものが、2006 年に延長され、現在は 2008 年目標
とされている)、新たに「2017 年に世帯ベースでの電化率 90%達成」という目標も設定し
たものである。フィリピンには 41,995 バランガイが存在するとされている。2000 年末現
在ではこのうち 19.8%に相当する約 8,300 バランガイが未電化であった。このため、フィ
リピン政府は毎年の電化バランガイ数を約 1,500 に加速しようとしている。
フィリピンでは、従来、①バランガイの中の 10 戸以上に電気が供給されている、②無電
化のバランガイに配電線が通過している（電力供給は可能であり、電化するか否かは需要
家の判断によるとの考えに基づく）
、のいずれかの条件が満たされるとそのバランガイは電
化されたと判断されていた。しかし、最近ＤＯＥではこの定義を見直し、①独立系統の場
合、持続可能なエネルギーにより 30∼40 件が電化されていること、（持続可能エネルギー
とは、ソーラー、バッテリーチャージステーション（ＢＳＣ）、ディーゼルによる小規模発
電機セット、などである）、②グリッドからの電化の場合はバランガイに配電線が通過しア
クセス可能であること、とした。すなわち、②は従来通りであるものの、①は電化受益者
数を引き上げた。しかしながら、依然、バランガイ単位での電化率で 100%を達成したとし
ても実体は依然多くの家屋の電化がなされていない状態が続くことには変わりない。実際、
１つのバランガイで電化される世帯数は平均 30∼40 戸程度とされ、バランガイの一部世帯
の電化というケースがほとんどのようである。
2006 年 10 月現在、バランガイ総数 41,945 のうち、電化されたバランガイは 39,590 で
- 93 -
電化率は全国平均で 94.4％となっている。電化率は地方により大きな差があり、ルソン地
域では 97.1%、ビサヤス地域では 96.0%、ミンダナオ地域では 87.0%となっている。これ
を電化実施の責任者である配電事業者別にみると、最も多い電化組合(ECs)では 93.8%、
MERALCO では 98.5%、その他民間事業者/地方自治体/その他で 97.7%となっている。
3.2 地方電化の推進方策
地方電化は O-ILAW プログラム及び ER 計画に基づき、DOE が中心となって各関係機関が実
施している。地方電化の進め方はまず大統領と DOE 長官が年間の電化目標を立てる。この
電化目標を DOE 等によるプログラムチーム(PT)が関係機関に割り振り、これに基づいて地
方電化組合、民営電力会社等の実施機関が実施に行っている。
O-ILAW プログラム及び ER 計画では地方電化を効率的に進めるために、政府機関や電気
事業者以外の組織にも地方電化事業に参加する機会を与えている。またその資金も国の一
般予算、ER1-94 基金、地方自治体予算、NGO や外国援助による支援、など多様な資金源
によっている。さらに、IPP にも参加の機会を与えると共にその資金力にも期待している。
ER1-94 基金を用いて実施した地方電化の例としては、2000 年に PNOC-EDC がレイテ島
の Ormoc 周辺で約 10 のバランガイの電化を実施したのをはじめ、米国の Southern Energy
がケソンにある石炭火力発電所周辺のバランガイ電化を実施した例、セブでマレーシア
East Asia が行った例などが報告されている
なお、地方電化は当該地域に配電事業権利を有する者（Franchise Distribution Unit、具
体的には EC など）が基本的に実施するものであるが、配電事業権利者が採算性から当該地
域に当面電化計画はない、と表明した地位に対しては Missionary 電化制度により電化を進
めることとしている。Missionary 電化は、EC 以外の者にやってもらうことになり、例え
ば民間企業にも期待している。このような場合、その地方電化の実施者は QTP（Qualified
Third Party 有資格第３者）と呼ばれる。近年はバタンガス州イリハン火力発電所の主要企
業である韓国電力（KEPCO）も QTP として貢献をしているとのことである。QTP が現れ
なければ最後の手段として NPC-SPUG が実施する。Missionary 電化は採算のとれない地
域を対象としていることから継続した補助金が必要であり、ユニバーサルチャージによる
資金が充てられる。ユニバーサルチャージとは電気料金の一部として全需要家に転化され
徴収される資金であり、その額はエネルギー規制委員会（ERC）が決定している。
3.3 地方電化の課題
フィリピンの配電事業は 119 の電化組合、16 の民間配電事業者、3 つの市営電気事業者
の合計 138 の配電事業者のサービス地区に分割されている。電化組合のうちバランガイ電
化 100%を達している組合は 15 組合（12.6%）にすぎず、75 組合（63.0%）はバランガイ
電化率が 90%に達していない。また、いずれの組合も世帯電化率は 100%に達していない。
電化事業は送配電系統の延伸と分散型電源を活用する方法に分けられる。2000 年末時点
で未電化である約 8,300 バランガイのうち、約 45%に相当する約 4,000 バランガイは既存
系統からかなり離れた地域に存在している。これらの地域では集落も分散して存在してお
り系統の延伸は困難であるうえ、所得水準も低いことから電化にかかるコストは高く、投
- 94 -
資効率は極めて低い状態にある。このような地域においてはオフグリッドの分散型電源の
活用に頼らざるを得ない状態である。分散型電源としては、包蔵水力がある地点では小水
力を活用し、その他の地点では太陽光を中心に風力、バイオマスなどの新・再生可能エネ
ルギー発電によるミニグリッドを活用し、また、SHS（Solar Home System）による戸別
電化の取り組みを強化することとしている。なお、1999 年から 2002 年の間に電化された
5,082 バランガイのうち 81.8%に相当する 4,159 バランガイは系統の延伸により電化され、
残りの 18.2%、923 バランガイはミニグリッドによる電化であった。ミニグリッドによる電
化のうち約７割が新・再生可能エネルギーによる電化であった。
系統延伸による電化にせよ、ミニグリッドによる電化にせよ、今後の電化対象となるバ
ランガイは電力需要の規模も小さく、電力の供給コストは高いものとなっている。また、
このようなバランガイの住民の所得は小さいことから配電事業者にとって電化事業の魅力
は極めて小さいものとなっている。しかしながら、住民の生活水準の向上の観点からこの
ような地域においてどのように電化を進めていくかが今後の大きな課題となっている。
3.4 地方電化の効果
国際協力銀行が実施したフィリピン「NEA 地方電化事業」に関する「円借款案件事後評
価報告書（2004 年）」によると、フィリピンにおける地方電化は次のような効果をもたらし
たとされている。
a)就業機会および収入の増加
本事業によって電化が完了したバランガイでは、電気を活用して新しい仕事を始め
たり、収入を増やしたりしている事例がみられる。また、経営している雑貨店を夜遅
くまで開くことができるようになった、冷凍庫を使用してアイスキャンディーを作り
販売している、パン屋を開業したなどの事例がみられた。
b)教育環境の改善
本事業では一般の世帯ではなく、バランガイの保育園、小学校などの教育施設も同
時に電化されている。インタビュー調査を実施した16のバランガイでは、合計13カ所
の保育園・小学校、4カ所の高校が電化されている。また各家庭においても従来のケ
ロシンランプよりはるかに明るい蛍光灯・白熱電球を使用できるようになったため、
夜間でも勉強を行えるようになった。
c)利便性の向上と娯楽の増加
電化後、ほとんどの世帯が蛍光灯、電球等の照明を購入している。そのほかにも、
住民は冷蔵庫、アイロン、洗濯機、電子ジャー、生活用水くみ上げ用電気ポンプ等、
利便性を高め、家事労働を軽減することができる家電製品を購入している。また、テ
レビ、ビデオ、ラジオ、ラジカセ、カラオケなど余暇を楽しむための電気製品を購入
している。電化されるまでの昼間畑で働き、暗くなったら寝るという生活から、電化
後には、娯楽や家族、近所とのコミュニケーションが向上したと回答した世帯が数多
くみられた。
- 95 -
d)安価で安全な光源の確保
電化される以前、各世帯は照明として、ほとんどの家庭がケロシンランプを使用し
ていた。電化後は、蛍光灯や白熱電球等が使用されている。60W白熱電球は、明るさ
の面でケロシンランプの7∼70倍もの明るさがあるのに対し、1時間あたりの費用は約
2分の1∼9分の1倍も安価である。また、ケロシンランプは火災の原因、排煙による悪
臭、咳・目のかゆみ等の健康被害、室内への煤の付着などの問題が生じていた。多く
の住民は電化によりケロシンランプの排煙による被害や火災の心配がなくなったと
考えている。
４.
対象地域の状況
4.1 北サマール州の状況
北サマール州は、レイテ州、南レイテ州、ビリラン州、東サマール、西サマールと並ぶ
東ビサヤス地域の一部である。北サマール州はフィリピン諸島の東部に位置し、北はサン
ベルナディノ海峡、西はサマール海、東は太平洋、南部は西サマール州、東サマール州に
接している。
図−1 北サマール州概略図
北サマール州は、ルソンからビサヤス及びミンダナオへのゲートウェイで、バスとフェ
リーを使いマニラから 14 時間かかるが最近ではマニラと州都であるカタルマンの間で航空
機が週 4 便利用可能となりアクセスが良くなった。
北サマール州は面積 3,498km2、25 の Municipalitiy（町）、569 の Barangay（村）から構
成されたおり、人口は 500,639 人（年率 2.11％で増加）、世帯数は 94,410 世帯である（2000
年調査）。
北サマール州は、フィリピンの中でも、経済・社会開発の最も遅れた地域の一つであり
（フィリピン全７０州のうち約２０を数える貧困州の一つ）、住民一人当たりの所得水準が
全国平均の５割未満となっている。また、北部山間地域は、世帯数から見た電化率は 20%
以下でフィリピンの中でも最も開発が遅れている地域であるため、再生可能エネルギーを
- 96 -
利用した地方電化を図り、農業生産の拡大や観光産業の発展を目指している。
同州の産業は農業が主体であり、米、とうもろこし、ココナツ、バナナ、キャッサバな
どが主な収穫物である。しかし、農業が主な収入源であるにもかかわらず、米の州内自給
が達成されておらず、近隣のレイテ州等からの移入に頼っている状況である。また、排水
状況が悪いため住民が住血吸虫病にかかるなど、劣悪な保健衛生状態も開発の妨げとなっ
ている。さらに、当地域の道路は未舗装のため雨季に水没するなどほとんど通行が出来ず、
農産物を市場に運搬することもままならず、収入確保の道まで閉ざされている状況である。
北サマール州は元来、土壌・水質ともに農業に適していることから、中部ルソン平野や
ミンダナオ島と並び農産物増産の潜在力が最も高い地域として期待されてきた経緯があり、
1970 年代には、世銀などの支援のもと、道路、上水道整備、農業開発などの開発計画が作
成された。しかしながら、共産ゲリラの活発な活動などの治安問題により実際には開発に
着手されず、現在も道路やかんがい施設の未整備が原因で作物収量が伸び悩み、農民が貧
困から脱却できない状況にある。現在ではその治安上の問題も解消されて、かんがい施設
などの基礎インフラを整備することにより、農民の収入増加を図ることが求められている。
さらに農業インフラに加え、電力設備、上水道整備、運輸インフラ整備、住血吸虫病対策
などの保健衛生施設整備を行うことにより、農民の居住環境・生活向上を図ることが緊急
の課題となっている。
4.2 北サマール州の電力事情
北サマール州を含む東ビサヤス地域の電力供給は、レイテ州のトンゴナン No1,2,3 地熱
発電所からとなっており、総発電容量は 700MW を超えている。ここで発電された電力は、
ルソン−レイテ連系線、レイテ−サマール連系線、レイテ−ボホール−セブ−ネグロス−
パナイ連系線により各地へ供給されている。
北サマール州の電力供給は、北サマール配電組合（NORSAMELCO）により行われており、
2005 年末現在で、北サマール州の 569 の Barangay のうち 73％に相当する 415 の Barangay
で電化が行われている。世帯数に対しての約 50%の電化率である。配電組合の詳細は５章に
示す。
５.
再生可能エネルギーによる地方電化の可能性検討
5.1 対象地域における地方電化の状況
5.1.1 北サマール州の地方電化の状況
今回調査の対象地域は北サマール州 Catubig 川流域であり、行政区域でいうと北サマー
ル州 Catubig 町および Las Navas 町である。
北サマール州は東ビサヤスの Region VIII に属する。2006 年 7 月現在における Region
VIII のバランガイ電化率は全体で 90.8%であり、特に地熱発電所を有するレイテ島の各電
化組合はほぼ 100%の電化率になっている。しかしながら、北サマール州を管轄地域とする
配電組合 NORSAMELCO においては電化率は 73.1%にすぎず、Region VIII の最低となってい
る（ 表−2 ）。
- 97 -
また、2004 年末時点での北サマール州内の各自治体別電化状況を見ると Catubig 町は北
サマール州平均を若干超える 60.9%であるものの、Las Navas 町は同州内の最低の電化率
（11.3%）となっており、電化促進が喫緊の課題となっていることが分かる（ 表−3 ）。
表−2
RegionⅧの Barangay 電化率
Electric
Number of Barangays
Cooperatives Covered Energized
%
Region VIII
4390
3984
90.8
DORELCO
499
494
99.0
LEYECO II
196
196
100.0
LEYECO III
285
285
100.0
LEYECO IV
245
242
98.8
LEYECO V
416
416
100.0
SOLECO
500
483
96.6
BILECO
132
132
100.0
SAMELCO I
427
366
85.7
SAMELCO II
524
482
92.0
ESAMELCO
597
472
79.1
NORSAMELC
569
416
73.1
(as of 2006,July,31)
(Source: NEA)
表−3 北サマール州の Brangay 電化率
(as of 2004.12.31)
Municipality
Energized
Allen
Biri
Bobon
Capul
Catarman
Catubig
Gamay
Laoang
Lapinig
Las Navas
Lavezares
Lope de Vega
Mapanas
Mondragon
Palapag
Pambujan
Rosario
San Antonio
San Isidro
San Jose
San Roque
San Vicente
Silvino Lobos
Victoria
Total
Potential
Number of Barangays
Households
Covered Energized
%
20
19
95.0
3,217
8
2
25.0
1,317
18
13
72.2
2,613
12
5
41.7
1,780
55
37
67.3
9,228
46
28
60.9
4,050
26
12
46.2
3,119
56
33
58.9
7,968
15
5
33.3
1,396
53
6
11.3
4,286
26
20
76.9
3,635
22
5
22.7
1,621
13
7
53.8
1,326
25
14
56.0
3,987
32
23
71.9
4,019
26
12
46.2
3,349
11
7
63.6
1,196
10
10
100.0
1,423
14
13
92.9
3,591
16
16
100.0
2,099
16
10
62.5
2,493
7
3
42.9
1,178
26
3
11.5
1,601
16
13
81.3
1,873
569
316
55.5
72,365
Cooperative
Members
House Connections
Total
%
Total
%
2,140
66.52
2,529
78.6
376
28.55
397
30.1
1,710
65.44
1,598
61.2
504
28.31
446
25.1
7,465
80.90
8,145
88.3
1538
37.98
1596
39.4
992
31.81
1104
35.4
3,707
46.52
3,905
49.0
441
31.59
476
34.1
451
10.52
479
11.2
1,565
43.05
1,624
44.7
309
19.06
374
23.1
472
35.60
471
35.5
1,985
49.79
1,927
48.3
2,181
54.27
2,259
56.2
1,396
41.68
1,470
43.9
596
49.83
629
52.6
723
50.81
665
46.7
2,155
60.01
2,291
63.8
1,356
64.60
1,385
66.0
1257
50.42
1288
51.7
195
16.55
196
16.6
12
0.75
12
0.7
956
51.04
945
50.5
34,482
47.65
36,211
50.0
Source : Northern Samar Electric Cooperative (NORSAMELCO), Inc., Bobon, Northern Samar
- 98 -
5.1.2 電力供給設備
NORSAMELCO は主にレイテ島の Tongonan 地熱発電所１号機（蒸気開発 PNOC-EDC,発電 NPC、
出力 112.5MW）からの電力をサマール州 Wright 変電所にて 138kV から 69kV に降下させ、
69kV
送電線を経由して Dalakit、Lawaan、Allen の３変電所にて受電し管内に供給している。
NORSAMELCO の所管は変電所受電端以降である。Catubig 町や Las Navas 町への電力供給は
Lawaan 変電所（69kV/13.2kV 容量 3.75MW)から行われ、ここから約 30km の配電線を介して
Las Navas まで供給している。
また、Catubig 町や Las Navas 町においては、ソーラーシステムや小規模なディーゼル発
電機セットによる電化、あるいはソーラーシステムや系統からの電力を自動車用バッテリ
ー（12v）に充電し各戸で利用するというバッテリー・チャージ・システム（BCS）による
戸別電化も行われている。ソーラーシステムによる BCS は PNOC-EDC や NPC により提
供されているとのことである。BCS の充電価格は系統からの電力の場合１回当たり 50-70
ペソ、ソーラーシステムの場合 20 ペソ程度である。また、ディーゼル発電機セットは地場
の民間企業がビジネスとして行っており、電気料金は 10W 当たり月 100 ペソ、運転は４時
間（18:00-21:00、5:00-6:00）である。なお、当地の家庭の平均月収は 4,000-6,000 ペソ程
度であり、電気料金は収入に比較するとかなり高いものとなっている。しかし、利便性向
上のため、電気利用を希望するものが多いとのことである。ソーラーシステムはパネル１
枚 75Wp（1.2ｍ×1.7m）が標準であるが、１枚 150Wp のパネルも普及が始まっていると
のことである。
5.1.3 NORSAMELCO の概要
NORSAMELCO 配電組合は、北サマール州を供給区域とする電化組合であり、1977 年
に設立された。供給区域面積は 3,498km、供給対象の Municipality 数は 24、Barangay 数
は 569 であるが、うち、23 Municiparity、316 Barangay に供給している。未電化の 1
Municiparity も 2007 年中には電化される予定である。供給区域内の世帯数は約 72,000 世
帯であるが、
2004 年現在、36,211 世帯が受電契約を行っている。需要家構成は家庭用が 67％、
商業用が 18%、官公庁用が 9%、産業用 1%、街灯 4%となっている。
NORSAMELCO の販売電力量は 2004 年で 31,249MWh であり、72.4%が家庭用である。
最新のデータでは１カ月 3,717,900kW ｈ（ 2006 年 10 月）とされているので、年間
44,615MWh に相当する。
最大需要電力は 2006 年で 8,133ｋW である。電化の進展に伴い、
NORSAMELCO ではシステムロスが大きくなる問題も出ており、平均システムロスは 21％
にも達している。技術的なロスに加え、電力計の故障など非技術的ロスも大きいとのこと
である。
NORSAMELCO の 2004 年の電気料金は、家庭用が最も高く 6.13 ペソ/kWh、商業用が
最も安く 5.41 ペソ/kWh、全体で 5.60 ペソ/kWh である。また、最新の電力料金では 2006
年 10 月現在で 6.23 ペソ/kWh に上がっている。なお、NORSAMELCO が NPC から購入
している買電単価は 4.66 ペソ/kWh である。
- 99 -
NORSAMELCO の収支状況は、営業利益▲1,550,085Peso の赤字（2004 年）で、２年
連続赤字を記録している。なお、赤字幅は縮小してきている。また、需要家件数は年率約
13%、最大電力は年率約 7％で増加するものと見られており、2008 年には全バランガイの
電化率達成を目標にしている。
5.1.4 カトービッグ町及びラスナバス町の電化の概要
Catubig 町には 47 の Barangay が存在する。このうち 28 Barangay が電化されている。
また、La Navas 町には 53 の Barangay が存在し、うち 26 Barangay が電化されている。
また、両町とも未電化の Barangay に対し、QTP による電化計画を有している。しかし、
QTP による電化に対し、支援策あるいは罰則のような措置はないため、この電化計画が予
定通り実施されるかは予断を許さない。
5.2 地方電化に伴う電力需要の想定
Catubing 町および Las Navas 町においては「Catubig 農業総合開発事業（Help for Catubig
Agricultural Advancement Project;HCAAP）」がわが国の円借款を活用して実施されている。
これにより約 4,500Ha にのぼる灌漑･排水施設の整備が行われ、幹線道路も約 65km にわた
り整備される予定である。この結果、当地の農業生産性は従来の稲作単位生産量 1 トン/ha
未満から 5 トン/ha へと大幅に改善することが期待されている。
本調査は同プロジェクトにより整備された灌漑水路における小規模水力ポテンシャル、
農業生産性向上に伴うバイオ廃棄物の発生などに注目し、これらの再生可能エネルギー資
源を当地域に多数存在する未電化 Barangay の電化に有効利用できないかを検討するもので
ある。
まず、Barangay の電化に伴い、どの程度の電力需要が発生するであろうか。3 章で見た
とおり、ひとたび電化が行われると住民は、照明、TV、冷蔵庫などの家電製品を購入し、
生活の利便性を高めようとする。また、電動かんな、電動のこぎりなどの器具を整備し、
労働力の軽減や付加価値の高い製品を生産しようとする。このため、ある程度のまとまっ
た電力需要が発生することが観測されている。
ここでは、世帯数 50 戸の Barangay をモデルとし、電化が行われた場合、家庭用照明機
器、TV、冷蔵庫などの家電製品がある程度の家庭に普及するものと考え、また、Barangay
内においても街灯設置、簡易水道用ポンプ整備などが行われ、さらには、精米業者や氷製
造業者の発生などが起こるものと想定した（表−4）。これにより、村落全体として約 9.6kW
のピーク需要が発生するものと考えられる。また、これらの需要による模式的日負荷曲線
は図−2 のように想定される。この需要の負荷率は 48.8%である。
- 100 -
表−4 村落電化による需要想定
＜Energy Denmand in Barangay＞
<Demand>
coverage (kW) (hour)
Number of Households
50 Households
160 W
Household Light (40Wx4)
70 W
Household TV
Households Refrigerator (50L 100 W
(Refrigerator Availability)
(
0.3 )
Street Light (40WX25)
40 W
Pump for Water Well
250 W
Ice Manufacturer
1,250 W
Rice Miller
3,000 W
Total
（Peak Demand
（Base Demand
0.8
0.5
0.3
6.4
1.75
0.45
25
1unit
1unit
1unit
1
0.25
1.25
3
9.6
5.0
(kWh/
day)
4
4
24
Remarks
25.6 Peak
7.0 Peak
10.8 Peak & Base
12 12.0 Peak & Base
20 5.0 Non-Peak
20 25.0 Non-Peak
9 27.0 Non-Peak
112.4
kW 44.6 ）
kW 67.8 ）
図−2 村落電化による電力需要想定（日負荷曲線）
Daily Power Demand in Barangay (50 Households)
12
10
Demand (kW)
8
6
4
2
0
1
2
3
4
5
6
HH Ref
7
8
9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
hour
St Light
HH Light
HH TV
Pump
Ice
Rice
5.3 配電線延長による電化計画とコスト想定
再生可能エネルギーによる電化を検討するに当たり、配電線の延長による電化にはどの
程度のコストがかかっているかを検討する必要がある。検討の結果、配電線延長方式の電
化コストは 19.8￠/kWh から 32.2￠/kWh まで幅があることが分かった。特に、村落規模の
小さい場合や配電線延長距離の長い場合は 25￠/kWh を上回る場合も出現する。これらの配
電線延長方式による電化コストの高い Barangay については再生可能エネルギー利用の独立
系統による電化方式が競争力を有する場合があるものと考えられる。
- 101 -
5.4 再生可能エネルギーによる電化計画とコスト想定
5.4.1 マイクロ水力による電化計画とコスト想定
5.2 で述べたように村落電化による電力需要はピーク時で約 10kW、ベース時で約 5kW で
ある。これをマイクロ水力により発電を行う場合、すべてをまかなうことを前提に発電所
を建設すると、出力 10kW の発電設備が必要となる。この場合、非ピーク時には設備が有効
利用されないことから、設備利用率は 46.8%となる。10ｋW の発電に必要なエネルギー源と
しては、流量 0.2 m3/s、落差 7ｍ程度のポテンシャルが必要である。他方、電力需要のうち
ベース分のみを水力発電により負担すると考えた場合は、5kW の発電設備の設置が適切であ
る。この場合、設備利用率は 66.5%になり、5ｋW の発電に必要なエネルギー源としては、
流量 0.1 m3/s、落差 7ｍ程度のポテンシャルが必要となる。
水力発電設備による電化コストは次の要素からなる。すなわち、
①水車・発電機の設置に要する資本費（建設費込み）
②配電線（240V による低圧配電を前提とする）設置に要する資本費
③水車・発電機、配電線等の維持管理費（O&M 費）
④運転員費用
このうち、
①に関しては、水車単価を 8,000＄/kW と想定し、さらに耐用年 45 年、割引率 12%
を用いて算出した年経費率 0.1078 を用いて年経費換算した。
②に関しては、配電線延長方式の場合と同様の単価を用い算出した。
③に関しては、水車・発電機、配電設備の維持管理費は年間に建設費の 1.5%相当
額が必要であるものとした。
④に関しては、運転員１名、給与月額 4,000 ペソと想定した。
これらの経費を受益する消費者の年間電力使用量で除すことで、マイクロ水力利用方式
による電化の長期限界費用（LRMC）が求められる。10ｋW の設備を設置してすべての需要を
水力のみでまかなう方式の場合の電化コストは 27.7￠/kWh と試算された。また、5kW のベ
ース対応の発電設備を設置し、ベース負荷のみをまかなう場合は 22.1￠/kWh と試算された。
なお、HCAAP 計画により整備される灌漑水路における水力ポテンシャルは概ね 5kW 程度と
判明した。このため、10ｋW のエネルギー源確保の観点からは困難が伴うものと考えられる。
5.4.2 バイオガス利用による電化計画とコスト想定
フィリピンでは豚、牛、鶏などの家畜糞をメタン発酵して処理するシステムが既に商業
利用段階にある。これらの技術は環境面から家畜糞処理技術として利用されていたが、発
生するメタンガスをエネルギー面から有効利用することも行われている。DOE によると、大
小様々な家畜糞の処理システムがフィリピン全体で 650 カ所以上にわたり導入されている
とのことである。大規模利用の代表例としては、農地 40Ha、豚 6 万頭を飼育する民間企業
である Maya 農場で、発酵メタンを利用した発電を行い、場内の照明、冷蔵庫などに利用し
ている事例がある。また、農家による小規模飼育の場合にはコンクリート製の簡易消化槽
が推奨されている。このような家畜糞処理消化槽のメーカーはフィリピン国内に 9 社ほど
存在しているようである。
- 102 -
近年、フィリピン国内では豚糞のメタン発酵処理事業を CDM 事業として計画する事例が
増加している。このように豚糞処理によるバイオガス発電は技術的に実用段階に入ってお
り、Catubig 町においても豚の飼育は一般に行われている。今後、HCAAP 計画の進展に伴
い農家の所得水準の向上が図られた場合、各農家が副業として豚の飼育数を増加させるこ
とは大いに考えられるシナリオである。このため、ここでは再生可能エネルギーとして豚
糞利用によるバイオガス発電を検討した。
このバイオガス利用により発電を行う場合、マイクロ水力の場合と同様に、すべてをま
かなうことを前提に発電所を建設すると、出力 10kW のバイオガス発電設備が必要となる。
この場合、設備利用率は 46.8%となる。
10ｋW の発電に必要なエネルギー源としては、豚 1,800
3
頭、容量 3,600m 程度のバイオガス発生消化槽、バイオガス発生量 100 m3/日の設備と豚飼
育数が必要である。
他方、電力需要のうちピーク分のみをバイオガス発電により負担すると考えた場合は、
5kW のバイオガス発電設備の設置が適切である。この場合、設備利用率は 11.9%と少ないも
のであるが、ガスホルダーの利用により豚飼育数は 500 頭、容量 1,000 m3 程度のバイオガ
ス発生消化槽、バイオガス発生量 28 m3/日程度の設備ですむこととなる。
バイオガス発電設備による電化コストは次の要素からなる。すなわち、
①バイオガス発生設備の設置に要する資本費（建設費込み）
②ガスエンジン・発電機設置に要する資本費（建設費込み）
③配電線（240V による低圧配電を前提とする）設置に要する資本費
④バイオガス発生設備、ガスエンジン・発電機、配電線等の維持管理費（O&M 費）
⑤運転員費用
このうち、
①に関しては、CIGER 装置建設費単価を 7.4＄/m3 と想定し、さらに耐用年 20 年、割引
率 12%を用いて算出した年経費率 0.1195 を用いて年経費換算した。
②に関しては、ガスエンジン・発電機設置費に対し、①と同様に年経費率 0.1195 を用
い年経費換算した。
③に関しては、配電線延長方式の場合と同様の単価を用い算出した。
④に関しては、CIGER 装置、ガスエンジン・発電機、配電設備の維持管理費は年間に建
設費の 2.0%相当額が必要であるものとした。
⑤に関しては、運転員 2 名、給与月額 4,000 ペソと想定した。
これらの経費を受益する消費者の年間電力使用量で除すことで、バイオガス発電方式に
よる電化の長期限界費用（LRMC）が求められる。10ｋW の設備を設置してすべての需要をバ
イオガス発電のみでまかなう方式の場合の電化コストは 20.5￠/kWh と試算された。また、
5kW のピーク対応の発電設備を設置し、ピーク負荷のみをまかなう場合は 41.5￠/kWh と試
算された。この結果、10kW のバイオガス発電により電力需要をすべて賄う方式で電化した
場合、電化コストは配電線延長方式と同レベルであると考えられる。しかし、必要となる
豚糞を集めるため 1,800 頭という飼育数の確保に課題が残るものと考えられる。
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5.4.3 籾殻発電による電化計画とコスト想定
HCAAP 計画により当地の農業生産性は従来の稲作単位生産量 1 トン/ha 未満から 5 トン/ha
へと大幅に改善することが期待されている。この結果大量に生じる籾殻を電化に利用する
ことも検討に値する。フィリピンでは籾殻は家庭調理用などに小規模に利用することはあ
っても、大規模に利用する事例はまだない。DOE によると現在、Bulacan 州で 35MW の籾殻
発電が、また、Nueva Ecija 州で 25-30MW の籾殻発電が計画されている段階である。
籾殻発電を検討する場合、従来の技術であるボイラー及び蒸気発電を利用した場合、設
備容量がどうしても大規模になってしまう。事実、上記の計画中の事例も 25-35MW クラス
であり、また、タイで稼働中の籾殻発電も 10MW∼20MW クラスである。このような大規模の
発電設備を設置する場合、大量の籾殻を効率的に収集するシステムが必要となるが、HCAAP
計画においてはそのような籾殻収集システム（例えば大規模ポストハーベスト施設の建設）
が計画されていない現状では村落電化の電源とするには適当とは言えない。
現在、小規模なバイオマス燃料を有効利用する技術としてスターリングエンジンが注目
され始めている。スターリングエンジンとはガソリンエンジンやディーゼルエンジンなど
のようにシリンダー内で燃料を燃やしてピストンを駆動するいわゆる内燃機関とは異なり、
シリンダー内の気体に外部から熱を加え膨張させることによりピストンを駆動するいわゆ
る外燃機関である。現在、軸出力 5 馬力、発電出力 3kW 程度の小規模なシステムが実証段
階にある。今回調査の対象となる小規模 Barangay の電化には適切な規模であるため、ここ
では籾殻をこのスターリングエンジンを利用して電化に利用する可能性を検討した。
このスターリングエンジン籾殻発電を行う場合、できるだけ設備利用率を高めることが
経済性を高めるうえで有利になるため、発電出力 3.3ｋW の設備を 3 基導入し合計 10kW の
設備とするものとした。この場合、設備利用率は 46.8%となる。スターリングエンジンの仕
様をに示す。また、10ｋW の発電に必要な籾殻量としては年間 180 トンと推計され、これは
HCAAP 計画により整備された農地 130ha から生じる籾殻量に相当する。
スターリングエンジン籾殻発電による電化コストは次の要素からなる。すなわち、
①スターリングエンジン・発電機設置に要する資本費（建設費込み）
②籾殻貯蔵庫建設に要する資本費
③配電線（240V による低圧配電を前提とする）設置に要する資本費
④スターリングエンジン・発電機、配電線等の維持管理費（O&M 費）
⑤運転員費用
このうち、
①に関しては、現在、スターリングエンジンは実証試験中であり商業価格が設定され
ていない。このため暫定値として１基 35,000＄と想定した。さらに耐用年 20 年、割
引率 12%を用いて算出した年経費率 0.1195 を用いて年経費換算した。
②に関しては、5,000＄と想定し、①と同様に年経費率 0.1195 を用い年経費換算した。
③に関しては、配電線延長方式の場合と同様の単価を用い算出した。
④に関しては、スターリングエンジン・発電機、配電設備の維持管理費は年間に建設
- 104 -
費の 2.0%相当額が必要であるものとした。
⑤に関しては、運転員 3 名、給与月額 4,000 ペソと想定した。
これらの経費を受益する消費者の年間電力使用量で除すことで、スターリングエンジン
籾殻発電方式による電化の長期限界費用（LRMC）が求められる。これによると 10ｋW の設
備を設置した場合の電化コストは 47.1￠/kWh と試算された。この価格は他の方式による電
化コストより高いものとなっているが、スターリングエンジンの価格を暫定的に設定した
ためであり、仮にスターリングエンジンが普及し、価格が１基 10,000＄程度まで低下した
とすればこれによる電化コストは 20￠/kWh 程度まで大幅に低下する。これは配電線延長に
よる電化コストと遜色ないレベルであり、スターリングエンジンの実用化、普及が大いに
期待されるものである。
5.4.4 マイクロ水力とバイオガスのハイブリッド発電による電化計画とコスト想定
5.4.1 及び 5.4.2 から、50 世帯の標準 Barangay をマイクロ水力のみで電化するだけの水
力ポテンシャルはこの地ではあまり期待できない。また、豚糞バイオガスのみを利用して
電化するだけの豚飼育数も期待できない状態である。他方、技術的特性としてマイクロ水
力は 24 時間の発電が可能であり、豚糞バイオガスはガスホルダーを利用することでガスを
ため必要なときに発電が可能である。このため、両者を組み合わせ、マイクロ水力をベー
ス電源として、豚糞バイオガス発電をピーク電源として組み合わせるハイブリッドシステ
ムを検討する。
5kW のマイクロ水力と 5kW の豚糞バイオガス発電を組み合わせて村落電化を行った場合、
建設に要する総コストは約 61,600＄と想定される。また既に各節で示した方法により年間
の必要経費を試算すると約 10,400＄と試算される。これを年間の利用可能電力量 41.0ＭＷ
ｈで除すことでこのハイブリッド方式の電化コスト（長期限界費用）は 25.4￠/kWh と試算
される。
5.4.5 再生可能エネルギーによる電化対象 Barangay の抽出
5.3 で検討したように配電線延長方式による電化コストは概ね 20￠/kWh∼32￠/kWh であ
ったが、中には 25￠/kWh を越える Barangay も存在する。他方、マイクロ水力と豚糞バイ
オガス発電を組み合わせた再生可能エネルギー発電による電化の場合、電化コストは概ね
25￠/kWh 程度であることが判明した。このことから以下の 7 Barangay がこのシステムの導
入可能性のある地域といえる。
表−5 電化対象 Barangay
Barangay
人口
世帯数
Palanas
164
35
Rufino
200
35
Tangan-ayan
316
60
Epaw
259
44
San Jose
179
36
San-od
188
33
San Antonio
228
45
- 105 -
６.
再生可能エネルギーによる地方電化計画
6.1 マイクロ水力ポテンシャル
HCAAP 計画は、Catubig Sercvice Area(3,565.5ha)、Bulao Service Area (742.2ha)、
Hagbay Service Area(665.3ha) の３地域の灌漑計画からなっている。このうち、今回、
Catubig Sercvice Area に関する灌漑用水路の水量及び水路落差のデータが入手できた。こ
れから判断されるマイクロ水力のポテンシャルは、表−6 の通りである。
この結果、前章で検討した再生可能エネルギー利用の可能性がある Barangay のうち、
Palanas、Tagan-ayan、Epaw、San Jose の４Barangay において、マイクロ水力を利用で
きる可能性がある。
表−6 マイクロ水力ポテンシャル
Site No. Discharge
(m3/s)
1
0.11
2
0.19
3
0.19
4
0.17
5
0.24
6
0.22
7
0.10
8
0.14
Head
(m)
2.6
2.8
1.5
4.5
4.2
2.0
3.0
3.4
Output
(kW)
1.7
3.2
1.8
4.3
6.0
2.6
1.8
2.8
Nearest
Barangay
San Isidro
Epaw
San Jose
Tagan-Ayan
Tagan-Ayan
Tagan-Ayan
Palanas
Rizal
6.2 各 Barangay におけるハイブリッド発電計画
Palanas、Tagan-ayan、Epaw、San Jose の４Barangay について、前章の住戸数 50 世
帯の標準 Barangay で検討した電力需要が同様に発生するとした場合の電力需要を表-2 の
Demand Side 欄に示す。また、この需要に対し、マイクロ水力発電及びバイオガス発電に
より電力を供給する場合の仕様を同表の Suply Side 欄に示す。
これによると、Palanas Barangay では、ピーク需要 6.7ｋW、電力量需要（日量）78.7kWh
が想定され、これに対し、水路７番サイトにおいて 1.8ｋW のマイクロ水力が期待できるた
めこれによりベース需要を賄うと共に、4.9ｋW の不足分をバイオガス発電により賄うハイ
ブリッド発電計画が考えられる。この場合、必要な豚飼育数は約 540 頭（一戸当たり約 15
頭）であり、消化槽は容量 1,100ｍ3 の CIGER 消化槽を設置することが必要である。
同様に Tagan-ayan Barangay では、ピーク需要 11.5ｋW、電力量需要（日量）134.9kWh
が想定され、これに対し、水路５番サイトにおいて 6.0ｋW のマイクロ水力が期待できるた
めこれによりベース需要を賄うと共に、5.5ｋW の不足分をバイオガス発電により賄うハイ
ブリッド発電計画が考えられる。この場合、必要な豚飼育数は約 600 頭（一戸当たり約 10
頭）であり、消化槽は容量 1,200ｍ3 の CIGER 消化槽を設置することが必要である。
同様に Epaw Barangay では、ピーク需要 8.4ｋW、電力量需要（日量）98.9kWh が想定
され、これに対し、水路２番サイトにおいて 3.2ｋW のマイクロ水力が期待できるためこれ
- 106 -
によりベース需要を賄うと共に、5.2ｋW の不足分をバイオガス発電により賄うハイブリッ
ド発電計画が考えられる。この場合、必要な豚飼育数は約 440 頭（一戸当たり約 10 頭）で
あり、消化槽は容量 900ｍ3 の CIGER 消化槽を設置することが必要である。
同様に San Jose Barangay では、ピーク需要 6.9ｋW、電力量需要（日量）80.9kWh が
想定され、これに対し、水路３番サイトにおいて 1.8ｋW のマイクロ水力が期待できるため
これによりベース需要を賄うと共に、5.1ｋW の不足分をバイオガス発電により賄うハイブ
リッド発電計画が考えられる。この場合、必要な豚飼育数は約 580 頭（一戸当たり約 16 頭）
であり、消化槽は容量 1,200ｍ3 の CIGER 消化槽を設置することが必要である。表−7 に
各 Barangay におけるハイブリッド発電の基本仕様を示す。
- 107 -
Demand Side
Barangay
Palanas
Tagan-ayan
Epaw
San Jose
Supply Side
Hydro
Energy
Daily Base
Biogas
Micro Hydro
Site production by
Energy
Generation
Potential
No. Micro Hydro
Demand
Household
s
Peak
Demand
Base
Demand
Daily
Energy
Demand
(house)
(a)
(kW)
(b)
(kW)
(c)
(kWh)
(d)
(kWh)
(e)
(kW)
(f)
35
60
44
36
6.7
11.5
8.4
6.9
3.5
6.0
4.4
3.6
78.7
134.9
98.9
80.9
55.9
95.8
70.2
57.5
1.8
6.0
3.2
1.8
7
5
2
3
Energy
Necessary Capacity of
Production
No. of Swine
Digester
by Biogas
(kWh)
(g)
(kW)
(h)=(b)-(f)
(kWh)
(i)=(d)-(g)
(Head)
(j)
(m3)
(k)
43.2
95.8
70.2
43.2
4.9
5.5
5.2
5.1
35.5
39.1
28.7
37.7
540
600
440
580
1,100
1,200
900
1,200
Note 1. Peak demand (b) is calculated by 9.6kW x (Households No./ 50)
2. Base demand (c) is calculated by 5.0kW x (Households No./ 50)
3. Daily energy demand (d) is calculated by 112.4 kWh x (Households No./ 50)
4. Daily base energy demand (e) is calculated by 79.8 kWh x (Households No./ 50)
5. Energy production by Micro hydro (g) is smaller number of either micro hydro potential (f) x 24h or daily base energy demand (e).
6. Biogas generation (h) is the balance of peak demand (b) and Micro hydro potential (f).
7. Energy production by biogas (i) is the balance of daily energy demand (d) and energy production by micro hydro (g).
8. Necessary No. of swine (j) is calculated by energy production by biogas (i) divided by 6.54 kWh/day/100 swine head.
9. Capacity of digester (k) is calculated by energy production by biogas (i) multipled by 31.0 m3/kWh/day.
- 108 -
北サマール州山岳地域における再生可能エネルギーによる地方電化計画可能性調査
1. セクター
電力
2. プロジェクト地点
フィリピン国、北サマール州、カトゥビグ
及びラスナバス地方
3. 実施機関
フィリピン国営石油公社；PNOC
4. 背景及び目的
本地方電化プロジェクト可能性調査の対象地域は東ビサヤス地域の北サマール州に位置
するフィリピンにおいても未開発地域である。当該地域の一人当たりの収入はフィリピン
全体平均値の 50％程度である。北サマール州の山岳地域における家屋電化率は 20％以下で
あることから、同州では農業生産性の向上及び観光産業の発展を促進させるため電化率の
向上を目標に掲げている。
本調査は、カトゥビグ川、潅漑施設からの水を利用したマイクロ水力及び農産物から発
生するバイオマスエネルギー等の再生可能エネルギーによる地方電化の可能性を検討す
る。カトゥビグ流域においては、現在実施されている包括的農業開発計画（ECDP）により
農産物の生産性向上が期待されている。
5. プロジェクト概要
(1) プロジェクト名：再生可能ｴﾈﾙｷﾞｰによる地方電化計画
(2) ハイブリッド発電による最大出力
ﾊﾞﾗﾝｶﾞｲ ﾊﾟﾗﾅｽ: P=6.7kW （ﾏｲｸﾛ水力: 1.8kW、 ﾊﾞｲｵｶﾞｽ: 4.9kW）
ﾊﾞﾗﾝｶﾞｲ ﾀｶﾞﾝｱﾔﾝ: P=11.5kW （ﾏｲｸﾛ水力: 6.0kW、 ﾊﾞｲｵｶﾞｽ: 5.5kW）
ﾊﾞﾗﾝｶﾞｲ ｴﾊﾟｳ: P=8.4kW （ﾏｲｸﾛ水力: 3.2kW、 ﾊﾞｲｵｶﾞｽ: 5.2kW）
ﾊﾞﾗﾝｶﾞｲ ｻﾝﾎｾ: P=6.9kW（ﾏｲｸﾛ水力: 1.8kW、 ﾊﾞｲｵｶﾞｽ: 5.1kW）
6. プロジェクト実施期間
可能性調査から工事完了まで約 2 年間（建設期間：0.5 年間）
7. 期待される便益及び受益者
受益者 ； 地域住民
便益 ； 家畜糞の有効利用、建設工事による雇用創出、
電化による地域産業の発展、生産性改善による貧困削減
8. 環境への影響
影響なし
9. プロジェクト費用
約 0.5 百万米ドル
- 109 -