Renewable Energy and Energy Efficiency Programme (REEP)

Transcription

Technical Assistance Consultant’s Report
Project Number: RETA-6102
April 2006
Pacific Subregional: Renewable Energy and Energy
Efficiency Programme (REEP)
(Financed by the Danish Cooperation Fund for Renewable
Energy and Energy Efficiency in Rural Areas)
Volume I: Program Activities
Prepared by
BURGEAP
Paris, FRANCE
For
The Asian Development Bank
This consultant’s report does not necessarily reflect the views of ADB or the Government concerned, and
ADB and the Government cannot be held liable for its contents. All the views expressed herein may not
be incorporated into the proposed project’s design.
CURRENCY EQUIVALENTS
(as of 1 April 2006)
Currency Unit
–
Samoa Tala (WS$)
WS$1.00
=
US$0.342
US$1.00
=
WS$2.924
Currency Unit
FJ$1.00
US$1.00
–
=
=
Fiji Dollar (FJ$)
US$0.5545
FJ$1.803
WEIGHTS AND MEASURES
MW (Megawatt)
kW (Kilowatt)
kWh (Kilowatt-hour)
Mt (Metric Ton)
–
–
–
Power in millions of Watts
Power in thousands of Watts
Energy in thousands of Watt-hours
1000 kilograms
i
ACRONYMS
ACP
Africa-Caribbean-Pacific EU Partner Countries
ADB
Asian Development Bank
ADO
Automotive Diesel Oil
AGO
Australian Greenhouse Office
CATD
Centre for Appropriate Technology Development
CEO
Chief Executive Officer
CFL
Compact Fluorescent Light
CIDA
Coconut Industries Development Authority (Fiji)
CO2
Carbon Dioxide (greenhouse gas)
CTA
Technical Centre for Agricultural and Rural Co-operation
CROP
Council of Regional Organizations of the Pacific
DOE
Department of Energy (Fiji)
DSM
Demand Side Management
EE
Energy Efficiency
EESCO
Energy Efficiency Service Company
EET
Energy Efficiency Technology
EPC
Electric Power Corporation (Samoa)
ESCAP
Economic and Social Commission for Asian and the Pacific
EU
European Union
EUEI
European Union Energy Initiative
EWG
Energy Working Group of CROP
FEA
Fiji Electricity Authority
FIT
Fiji Institute of Technology
FS
Forum Secretariat
FSC
Fiji Sugar Corporation
GEF
Global Environment Facility
GHG
Green-House Gas
GoF
Government of Fiji
GWh
Giga-Watt hours
ha
HECEC
IIEC
hectare
Australia's Hydro-Electric Commission Enterprises Corporation
International Institute for Energy Conservation
IPP
JICA
Independent Power Producer
Japan International Cooperation Agency
JV
Joint Venture
kVA
Kilo-Volt Ampere
LPG
Liquid Petroleum Gas
MoU
Memorandum of Understanding
ii
MOF
MOFP
Ministry of Finance (Samoa)
Ministry of Finance and Planning (Fiji)
MW
Megawatt
MWe
NCSMED
Megawatt electric equivalent
National Centre for Small and Micro-Enterprise Development (Fiji)
NEP
National Energy Policy
NGO
Non-Government Organization
NMFU
National Micro Finance Unit (Fiji)
NUS
National University of Samoa
O&M
Operation and Maintenance
OTEC
PDMCs
Ocean Thermal Energy Conversion
Pacific Developing Member Countries (of ADB)
PIC
PIEPSAP
PIGGAREP
PIREP
PIRGADI
PPA
Pacific Island Countries
Pacific Islands Energy Policies and strategic Action Planning
Pacific Island Greenhouse Gas and Renewable Energy Programme
Pacific Island Renewable Energy Project
Pacific Islands Regional Geothermal and Development Initiative
Pacific Power Association (also “Power Purchase Agreement”)
PV
Solar Photovoltaics
PWD
Public Works Department
RE
REEP
Renewable Energy
Renewable Energy and Energy Efficiency Program
REM
REP-PoR
Regional Energy Meeting
UN Asia-Pacific Renewable Energy Programme for Poverty Reduction
RET
RESCO
Renewable Energy Technology
Renewable Energy Service Company
RMI
Republic of the Marshall Islands
SHS
Solar Home System
SOPAC
South Pacific Applied Geoscience Commission
SPREP
Secretariat of the Pacific Regional Environment Programme
STEC
Samoa Trust Estates Corporation
TA
Technical Assistance
ToR
Terms of Reference
TPAF
Training and Productivity Authority of Fiji
UNDP
United Nations Development Programme
UNDESA
United Nations Department of Economic and Social Affairs
UNESCO
United Nations Education, Scientific and Cultural Organization
USP
University of the South Pacific
yr
year
iii
TABLE OF CONTENTS
EXECUTIVE SUMMARY
VI
I. INTRODUCTION
1
A. Target Country Selection ...................................................................................................1
1.
2.
Criteria for Short List Selection
Country Selection Survey
2
2
II.
CURRENT RENEWABLE ENERGY AND ENERGY EFFICIENCY ACTIVITIES IN THE
PACIFIC REGION
2
A. REEP team interaction with regional energy programs ......................................................5
III. NATIONAL PROJECT DEVELOPMENT AND ACTIONS
8
A. Fiji .....................................................................................................................................8
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
B.
Steering Committee
Policy strategies and incentives
Establishment of an appropriate institutional framework
Financing schemes development
Capacity building
Regional activities by the REEP team.
Project development
Priority 1 Project in Renewable Energy: Namosi hydroelectric joint venture
Priority 2 Renewable Energy: Rotuma electrification using biofuel
Priority 3 Renewable Energy: Geothermal resource investigation
8
8
8
11
12
15
15
16
22
29
Samoa .............................................................................................................................32
1.
2.
3.
4.
5.
6.
7.
8.
9.
Steering Committee
Capacity building
Dissemination of activities in Samoa
Project development
Priority 1 - Renewable Energy: EPC generation using biofuel and biomass
Priority 2 Renewable Energy: hydro-electric development for Upolu
32
32
32
35
36
39
39
40
47
IV. SUB-REGIONAL PROJECT IN ENERGY EFFICIENCY (FIJI AND SAMOA)
50
A. Project Concept and Objectives.......................................................................................50
B. Project Background .........................................................................................................50
C. Project proponents ..........................................................................................................53
1.
2.
D.
53
Project Activities ..............................................................................................................54
1.
2.
3.
4.
5.
E.
Fiji 53
Samoa
Capacity development
Implementation loan guarantee
Performance guarantee
Independent auditing of performance
Government support
54
55
55
56
56
Project preparation components ......................................................................................56
1.
Proposed TA activities leading to a project design suitable for funding
57
V. DISSEMINATION OF RESULTS
59
VI. CONCLUSIONS AND NEXT STEPS
60
A. Attainment of intended outputs from the REEP................................................................60
B. Next steps .......................................................................................................................61
1.
2.
Project pipeline
Policy and institutional development
61
61
iv
APPENDICES
Appendix 1
63
Namosi, Naitisiri Hydro Project Prefeasibility Study
Appendix 2
Prefeasibility study for the Electrification of Rotuma Based on Locally
Produced Coconut Oil
Appendix 3
Proposed Energy Efficiency Action Plan for Samoa 2006-2008
Appendix 4
Review of Past and Present Fiji DOE Energy Efficiency Activities and
Recommendations for the Future
Appendix 5
Survey of Standards and Certification Systems for Energy Efficiency and
Renewable Energy
Appendix 6
Proposed Standards for RESCO SHS Installation and Maintenance
Appendix 7
Proposed Standard Specifications for RESCO managed Solar Home
Systems (SHS)
Appendix 8
Training Course for Solar Photovoltaics Instructors in Fiji (9-10 February,
2006). Curriculum for Solar PV at FIT (2005)
Appendix 9
Facility Requirements for PV Technician Training
Appendix 10
Regional Workshop on Renewable Energy and Energy Efficiency, Fiji, 2024 February, 2006
Appendix 11
Case Studies of Renewable Energy and Energy Efficiency Financial
Mechanisms Around the World
Appendix 12
Persons Contacted in the Course of REEP Activities
Appendix 13
Terms of Reference for the Renewable Energy and Energy Efficiency
Program
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EXECUTIVE SUMMARY
Introduction
1. The Renewable Energy and Energy Efficiency Program (REEP) was a regional
program for the Pacific having the goal of increasing the use of renewable energy and
energy efficiency with emphasis on private sector involvement, poverty reduction and
rural area development.
2. January 26, 2004 to May 26, 2004 was the Inception period during which Samoa and
Fiji were selected as the target countries. A Steering Committee was formed in each
country to assist in the determination of REEP project activities and their priorities.
Current Renewable Energy and Energy Efficiency Activities in the Pacific Region
3. The Pacific Region has one of the highest per-capita levels of bilateral and
multilateral donor assistance in the world. A number of regional renewable energy and
energy efficiency programs exist or are in the pipeline. The REEP team maintained close
contact with these programs and coordinated its activities to avoid duplication of efforts.
Where appropriate the REEP supported complementary activities with funds, personnel
and information. In particular the Pacific Islands Energy Policies and Strategic Action
Planning (PIEPSAP) project overlapped with REEP in the policy and regulatory
development areas, recent Economic and Social Commission for Asia and the Pacific
(ESCAP) activities overlapped in capacity building, the Pacific Islands Renewable
Energy Project (PIREP) overlapped in areas of renewable energy and capacity
development, the Australian Greenhouse Office (AGO) project with the Department of
Energy (Fiji) overlapped in the area of energy efficiency standards and certifications, the
UNDP funded CocoGen project overlapped in the area of biofuel development for
Samoa, the South Pacific Applied Geoscience Commission (SOPAC) Regional Energy
Efficiency Programme overlapped in Fiji and Samoa and ADB projects for Samoa utility
development overlapped in Samoa.
4. Programs in the pipeline that needed to be considered when developing REEP
activities included the follow-on project to PIREP, the Pacific Islands Greenhouse Gas
and Renewable Energy Programme (PIGGAREP), new initiatives by ADB with the
Samoa and Fiji utilities, a new regional initiative by UNDP in renewable energy (REPPoR) and activities in renewable energy by the Pacific Power Association (PPA) that the
European Union (EU) is expected to support.
5. The Asia Pacific Economic Cooperation (APEC) Expert Group on New and
Renewable Energy, the APEC Energy Standards Information System and the proposed
UNDP “Barrier Removal for the Cost Effective Development and Implementation of
Energy Standards and Labelling Project” are not specifically Pacific regional programs
but are a source of information useful for Pacific project development.
Policy strategies and initiatives
6. The PIEPSAP project includes all areas of policy development that were originally
included in the REEP. Therefore the REEP did not include policy development in its
activities unless the Fiji or Samoa governments requested specific assistance from the
REEP.
7. Helping design an institutional framework to support the development of Energy
Efficiency Service Companies (EESCOs) was the primary institution building effort under
REEP. Because both the Fiji and Samoa Steering Committees considered the EESCO
concept as appropriate for development, a sub-regional project concept was developed
by REEP. The REEP team laid the ground work by locating individuals and businesses
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Executive Summary
that are EESCO candidates, developing support for the concept from large energy users
and working with the Fiji and Samoa Governments to make use of EESCO services both
to improve efficiency of energy use in Government and to provide initial work for the new
EESCOs. The team also participated in an Asia-Pacific Energy Service Company
(ESCO) workshop held in Bangkok in October, 2005 to examine the experiences of the
developing countries in Asia using the concept.
Regulatory framework development
8. The primary areas of regulatory framework development that REEP addressed are:
1) Assistance in the development of technical standards for PV including
components, system designs, system installation procedures and maintenance
procedures for RESCO operated rural electrification by solar PV in Fiji. This
assistance builds on earlier GEF/UNDP funded work in Fiji. (See Appendixes 5, 6
and 7)
2) Assistance in the development of an action plan for energy efficiency
improvement, including appliance labeling and certification processes, in Samoa.
A multi-sectoral committee is expected to be established by Government to
address this issue. (See Appendix 3)
Development of a renewable energy association in Fiji and Samoa
9. Fiji has at least eight private businesses that concentrate on renewable energy sales
and services. In February 2006, a meeting of these businesses was arranged and Mr.
Bruce Clay of Clay Engineering in Fiji has accepted the role of founding secretary with
the goal of establishing the legal structure and operating format for a Fiji Renewable
Energy Business Association. A Constitution has been prepared and further
organizational meetings are expected to be held in the first half of 2006.
10. The development of a renewable energy business association in Samoa is not
presently practical since there are no businesses specializing in renewable energy.
However, both the Samoa Association of Manufacturers and Exporters and the Samoa
Engineer’s Association have indicated a willingness to establish a subsection devoted to
renewable energy and energy efficiency matters should sufficient interest develop in the
future.
11. Surveys of the availability of finance for renewable energy development were carried
out in both Samoa and Fiji and availability of finance is not considered by the team to be
a primary barrier to renewable energy development in rural areas in either country. In
Samoa, the only renewable energy financing likely to be needed is for solar water heater
purchase. Existing commercial bank finance structures appear adequate for that
purpose.
12. Micro-finance structures and rural financial access have both been developed in Fiji
though to date there has been little use of finance for the purchase of renewable energy
systems in rural areas. In rural Fiji, it appears likely that rural households are not aware
of either the availability of renewable energy (mainly solar PV) systems for household
use or of the availability of micro-finance for their purchase. Rather than attempt further
development of micro-finance and rural finance facilities, the team has proposed that the
renewable energy business association should accept as one of its roles the
development of marketing methods to encourage sales in rural areas that can utilize the
existing finance structures.
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Executive Summary
Capacity building
13. A survey was carried out of training and educational organizations that could
participate in capacity building activities in Samoa and Fiji. Also, information was
gathered regarding past efforts and of plans for future capacity building programs that
could impact on Fiji and Samoa, including APEC efforts in renewable energy training
certification processes developed by Australia for APEC’s Expert Group on New and
Renewable Energy.
14. In Fiji, the Fiji Institute of Technology (FIT), the Trades and Productivity Authority of
Fiji (TPAF) and the Centre for Appropriate Technology and Development (CATD) are
seen as being able to increase their renewable energy and energy efficiency training
roles. Each has expressed an interest in doing so.
15. FIT is well suited as a provider of certificate, diploma and degree programs in
electricity (for PV and energy efficiency training) and plumbing (for solar water heater
training). TPAF is well suited as a provider of specialist short courses in RET and EET.
FIT now has course modules in EET and RET and the REEP team supported their
efforts by providing an intensive two day training of trainers course in solar PV and
through the provision of curriculum materials and facility improvement recommendations
(See Appendix 8).
16. The primary capacity building effort by the REEP team in Fiji has been working with
the CATD to upgrade their solar PV technician training course through the updating of
their existing course materials, through their participation in REEP sponsored training
and workshop activities and through providing recommendations for the upgrade of their
PV training facilities. CATD is expected to be an important component for the support of
proposed large scale PV rural electrification using RESCOs and REEP training
enhancement efforts have focused on CATD for that reason.
17. In Samoa, the Samoa Polytechnic and the Don Bosco Technical Institute are
considered by the team to be the facilities that could provide needed training in RET and
EET. Since the only renewable energy technology that presently is used on any
substantial scale in Samoa is solar water heating, training through the plumbing trades
program of Samoa Polytechnic and the Don Bosco Technical Institute is appropriate.
Samoa Polytechnic now has a well developed program for solar water heating
technology training and Don Bosco has some aspects of that training within their
plumbing trades program. Samoa Polytechnic also includes aspects of EET within its
electrical trades curriculum. Don Bosco Technical Institute has no electrical trades
training at this time.
18. Therefore, as with Fiji, the REEP emphasis in Samoa is not primarily on new course
development but on evaluating existing curricula.
Project development approved and prioritized by the Fiji and Samoa REEP
Steering Committees
Sub-Regional (Samoa and Fiji)
Priority 1: Energy Efficiency Service Company development
19. The Steering Committees of both Fiji and Samoa agree that developing private
Energy Efficiency Service Companies (EESCOs) is the highest priority for energy
efficiency project development. Though there have been several local and regional
energy efficiency programs that emphasized energy audits, they have had little long term
effect and at best have impacted only a very few of the highest use customers. For there
to be widespread implementation of energy efficiency measures, the private sector must
participate in EE and a means to maintain the long term value of EE measures needs to
be in place.
viii
Executive Summary
20. The process that is proposed for the development of EESCOs in Samoa and Fiji is:
1) Determining if a sufficient market for energy efficiency services is present to
support EESCOs
2) Locating individuals and businesses that are interested in becoming EESCOs
3) Providing specialty training in EET for those individuals and businesses
4) Marketing EESCO services to industry, businesses and government
5) Providing energy audits and recommendations for improvements
6) Assisting clients specify equipment and locate finance for EE improvements
7) Installing the EE equipment and training users in its proper operation and
maintenance
8) Monitoring the equipment to ensure that it continues to provide the design
savings
21. Most of the serious barriers to success of EE efforts relate to finance and customer
confidence. The program that is proposed addresses the problem of obtaining finance
for EE measures by (a) providing financial institutions training in EET so that the
financiers will have more confidence in the process and (b) creating a loan guarantee
fund to lower the risk for the loans that are made for EET thereby improving both the
conditions of the loan and the ease of obtaining finance for the client.
22. The issue of customer confidence revolves around the accuracy of EESCO
projections of savings and the life of the equipment that provides the savings. This
problem is provided for in the project through the provision of a performance guarantee
fund that will cover a significant part of any difference between the performance
promised by the EESCO and that actually measured after installation.
23. A Technical Assistance (TA) project that determines the feasibility of EESCO
development in Fiji and Samoa was proposed by the team. If the concept is found to be
feasible, the TA will also design the specific structures needed for the project, train
businesses in EESCO activities and provide market development services to those
businesses. The estimated cost of the TA is US$615,000.
Fiji Renewable Energy Projects
Renewable Energy Priority 1: Namosi Hydroelectric Joint Venture
24. A joint venture (JV) for hydroelectric development has been formed that joins the
resources of the Namosi Province and its communities with a local engineering firm. A
prefeasibility study by a French consulting firm that was financed by the JV and
completed in 2004 indicates favorable conditions for development of over 10 MW of
hydro capacity in the Namosi/Naitisiri area of the main island of Viti Levu partly using
small impoundments and partly run-of-river.
25. The project concept is unique in Fiji for hydro energy development. In the past, the
Fiji Electricity Authority (FEA) has negotiated with land holders to lease the land
providing the resource but there have been many problems with land owners over the
quarter century since commercial hydro power has been developed in Fiji. In this project
the land owners are among the principal developers of the resource and share in the
profits and risks. The proposed structure allocates 80% of ownership to local
communities and the province.
26. The FEA has stated that it will accept electricity from the JV on its standard
Independent Power Producer (IPP) terms which include purchase guarantees and an
expected FJ$0.135/kWh purchase price provided the power produced meets FEA quality
standards.
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Executive Summary
27. The REEP team was requested by the JV, with support by the DoE and the REEP
Steering Committee, to assist in developing a business plan, in locating funding and in
assisting the JV to develop a project document for completion of a full feasibility study.
Those tasks have been completed to the extent possible and a project document has
been circulated for funding.
28. The estimated cost of the Namosi development at the Namado and Wairokodra sites
is US$24.6 million for an annual production of about 31.6 GWh. No village relocation
would be required and few environmental problems are anticipated
29. The Team has prepared a TA proposal for a full feasibility study followed by the
engineering design efforts. The total cost of the feasibility study and engineering design
is estimated at US$1.04 million.
Renewable Energy Priority 2: Rotuma Centralized Electrification Using Coconut Derived
Biofuel
30. Rotuma is an isolated island of 43 km2 located 465 km north of the main Fiji group of
islands. The island remains a major producer of copra though the price received by the
copra farmers is the lowest in Fiji due to the high cost of transport to the mill in Vanua
Levu. The cost of imported fuel is the highest in Fiji due to transport costs. Additionally,
shipping is irregular and fuel supplies are sometimes exhausted before a new shipment
arrives.
31. All villages are located along the coastal road and about 90% of households are
electrified from village generators that are operated independently of other villages. The
power supply is typically unreliable, the quality poor and is available only several hours
per day.
32. The Coconut Industry Development Authority (CIDA) requested the REEP team to
consider a project that would upgrade the Rotuma electricity supply to a centralized
system powered from diesel engines operating off locally produced coconut oil.
33. Since the Rotuma electrification project was not approved by the Steering Committee
until February, 2005, the preparation of the project was delayed relative to other REEP
projects but in November, 2005, a REEP team member visited Rotuma for a
prefeasibility study and obtained sufficient information for the preparation of the project
preparation document.
34. A TA is proposed for a full feasibility study and engineering design. The estimated
cost of the TA is US$558,000
Renewable Energy Priority 3: Geothermal Resource Investigation for Viti Levu and Vanua
Levu
35. The presence of numerous hot springs and other thermal phenomena on Vanua
Levu and Viti Levu indicate possible sources of geothermal energy for power generation.
Preliminary surface studies in the late 1970’s and in the early 1980’s, with some
supplementary studies in the 1990’s, have been generally favorable for Vanua Levu
development but provided only limited data for Viti Levu. Since capacity is needed
urgently for Viti Levu, further study of the possibility of geothermal development on Viti
Levu is needed. Further study of the Vanua Levu resource is also of interest since if the
resource is large enough, transmission of power between Vanua Levu and Viti Levu
could be economically reasonable.
36. FEA requested the REEP team to assist in the development of a project document
for Technical Assistance (TA) for a two phase study of the Fiji geothermal resource.
Phase 1 would be a review of existing data and new analysis of that data in light of
recent technical improvements and to undertake surface measurements of the
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Executive Summary
geological, geochemical and hydrogeological structures of Viti Levu. Phase 2 would
include more comprehensive studies on promising areas of Viti Levu and Vanua Levu
and, if it appears reasonable, would design a follow-on exploration drilling project for
final determination of the size and accessibility of the resource.
37. A TA project document has been prepared and approximately US$540,000 is
budgeted for the prefeasibility study.
Samoa Renewable Energy Projects
Renewable Energy Priority 1: Biomass and biofuel for EPC generation
38. The need for capacity increase at EPC means adding diesel generation since hydro
is seasonal and the capacity of the remaining practical hydro sites is insufficient. Given
the large generally unused coconut resource on Upolu along with the high cost of diesel
fuel, the REEP team was asked to assist EPC in developing a 3 MW diesel generation
facility with its fuel based on coconuts. The initial concept of coconut gasification was
found to be problematic and the project that was developed focuses on the use of
coconut oil as a fuel combined with the use of wastes for energy production or other
economic benefit.
39. In order to ensure continuous supply of coconuts, minimal transport cost, minimal
impact on other infrastructure and stable coconut oil fuel price the project will utilize the
government-owned 7,000 ha coconut plantation (operated by the Samoa Trust Estates
Corporation or STEC), near the major electrical loads of the International airport and the
new Aggie Grey’s Resort, has been chosen as the preferred site for the facility. The
location of the facility at the source of the coconut supply will avoid congestion of public
roads by vehicles transporting the coconuts to the facility.
40. Because of the need for good quality control and because all components of the
coconut will be used in the process, the facility will take whole coconuts to produce oil for
the diesel engines. The husks and shells are expected to be used as fuel in a boiler to
produce steam for drying the copra, for supplementary power generation and/or for other
economic activity.
41. Benefits from the project are expected to include:
•
•
•
•
•
•
•
Reduction in the rate of increasing dependence on imported oil
Reduction in the growth rate of greenhouse gas production in Samoa
Increased low skill employment
Increased high skill employment
3 MW of base load capacity for Samoa that is located in a high demand area
(Airport and Aggie Grey’s Resort)
Renovation of the coconut industry
Development of technology that can be transferred to other PICs.
42. The project is estimated to require an investment for the power generation
component, for the coconut processing component and for the rehabilitation of the STEC
plantation to the point where it can reliably provide the needed coconuts for 100%
operation of the power plant on coconut oil.
43. A TA project document has been prepared that combines the feasibility study and
engineering design for this project with those of Upolu hydro development study (below).
The total cost for both TAs is projected as US$781,000.
Renewable Energy Priority 2: Upolu hydro development feasibility study
44. Past hydro site identifications studies (HECEC in 1997 and JICA in 2003) indicate
there may be economically reasonable hydro sites near Lotofaga, Tatifoala and Namo
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Executive Summary
villages on Upolu. The preliminary hydrological and physical data indicate that a run-ofthe-river hydroelectric facility may be technically practical at the sites. A three phase
project is proposed as a TA that first includes a prefeasibility study of the three sites
followed by a full feasibility study of the best of the economically developable sites and
finally an engineering design for the installations.
45. A TA project document has been prepared that combines the feasibility study and
engineering design for this project with those of biofuel power development study
(above). The total cost for both TAs is projected as US$781,000.
xii
Executive Summary
RENEWABLE ENERGY AND ENERGY EFFICIENCY PROGRAM
FINAL REPORT
I.
INTRODUCTION
46. The Renewable Energy and Energy Efficiency Program commenced on 26 January,
2004 and had as its primary goal the development of projects and programs that will
result in increasing private sector activity that uses renewable energy and energy
efficiency technologies. The socio-economic goals of the program include poverty
reduction, rural development, reduced environmental impacts of energy use and the
reduction in the use of fossil fuels.
47. The REEP is a regional program and activities in the target countries are intended to
be useful examples for other countries in the Pacific Region.
48. The outputs include:
!
!
Review of lessons from past renewable energy and energy efficiency assistance
in the Pacific.
A project to develop appropriate policies, institutional arrangements,
legal/regulatory measures, capacity and the financial structure for promoting
commercially viable energy efficiency services. (See section VI - Sub-Regional
project in Energy Efficiency and Appendixes 3 and 4 )
!
Capacity building and training curricula for private and public sector key players
on renewable energy technologies. (See Appendix 8)
!
A pipeline of projects for funding by ADB, GEF, and/or other relevant financing
sources; and
!
Based on outcomes and progress made in the two selected countries, final
consultations and dissemination of lessons learned from the TA to other Pacific
Developing Member Countries (PDMCs) with a focus on establishing policy
frameworks, building capacity, and replicating and disseminating good practices.
49. The period 26 January, 2004 to 26 May, 2004, was the Inception period during which
the target countries were selected, the Steering Committees created and background
surveys initiated. The main implementation phase with actions focusing on Fiji and
Samoa commenced on May 26, 2004. A Mid-Term report was delivered four months
following commencement of country implementation and an Interim Report was
prepared that presented the status of the project implementation at the one-year mark.
This Final Report provides an overview of the REEP implementation and presents the
results of the program. The Final Report has two volumes with this Volume 1 containing
the overview of the REEP implementation and the results of the program. Volume 2
consists of technical assistance (TA) framework and financing requirements for each
priority projects in Samoa and Fiji following the ADB TA format and/or GEF format.
A.
Target Country Selection
50. The ADB’s Pacific Developing Member Countries (PDMCs) are Papua New Guinea,
Solomon Islands, Vanuatu, Fiji, Tonga, Cook Islands, Samoa, Tuvalu, Kiribati, Republic
of the Marshall Islands, Federated States of Micronesia, Nauru and Palau. In order to
ensure that the selection process was based on the most complete information and
knowledge of conditions in the PDMCs, a short list of four countries was selected using
criteria considered by the consultants as indicative of the likelihood of utilizing the TA
effectively.
1
1.
Criteria for Short List Selection
51. The REEP is an advanced Technical Assistance (TA) program and could not be
successful within the limited time available unless the target countries have sufficient
interest, capacity and experience in renewable energy and energy efficiency programs.
Therefore the selection of the two target countries was oriented toward those countries
that have demonstrated interest in these programs, have shown that energy has
sufficient priority by having responded to regional program efforts to develop energy
policy, and had sufficient available capacity in 2004-2005 to fully participate in the
REEP.
52. Using these criteria, the BURGEAP team evaluated each of the PDMCs. It was
recognized that the scoring would be necessarily somewhat subjective and would be
influenced by the availability of documentation, the experience of the consultants and
access to information about the current situation in the countries. Therefore the four top
ranking countries by this “desk” analysis were then short listed for field evaluation to
ensure that the information available to the consultants was up to date and accurate. On
that basis, the Cook Islands, Tonga, Samoa and Fiji were selected for field evaluation.
2.
Country Selection Survey
53. During the period 21 January to 20 February, the BURGEAP REEP team made
evaluation visits to the Cook Islands, Tonga, Samoa and Fiji. Through examination of
records and discussions with stakeholders, each country’s level of meeting the selection
criteria was estimated. Additionally, a letter indicating that there was no objection to the
program was requested from the government and from the national utility in each of the
four countries. Finally a letter indicating a willingness to provide the support resources
necessary for carrying out the program was requested from the utility or the government
energy agency designated as focal organization.
54. The final selection recommendation was based on ranking using the general
selection criteria with three criteria receiving extra weight in the evaluation. The three
criteria were:
(i)
(ii)
(iii)
The likelihood that the country would in fact use the information provided
through the REEP TA after TA completion.
The available capacity of the proposed TA focal organization, the utility and
the government to take advantage of the TA effectively.
The probability that the country would follow through with renewable energy
and energy efficiency project applications that could be financed by ADB,
GEF or other agencies.
55. Based on the visits, the consultants recommended Samoa and Fiji as the target
countries for REEP and ADB accepted the recommendation.
56. In May, 2004, a Steering Committee was established in each of the two target
countries for the development and prioritization of REEP project development activities.
II.
CURRENT RENEWABLE ENERGY AND ENERGY EFFICIENCY ACTIVITIES IN THE
PACIFIC REGION
57. There are many programs operational or planned for implementation in the Pacific
Region that focus on renewable energy and/or energy efficiency. Table 1 summarizes
the regional programs that are presently operating or whose results are complete but not
2
yet published and Table 2 summarizes the regional programs focusing on renewable
energy and energy efficiency that are in the planning stage.
Table 1 - Summary of Currently Active Regional RE & EE Activities in the Pacific Region
Name
Summary
Comments on RE / EE* Activities
Promotion of
Renewable
Energy Efficiency
and Greenhouse
Gas Abatement
(PREGA)
ADB program
concentrating on
greenhouse gas
reduction through
RET and EE
activities. In the
Pacific Region it is
only active in Samoa
Funded by the Netherlands, PREGA is intended to promote
investments in RE and EE technologies with the goals of
greenhouse gas abatement, increased access to power in rural
areas and by the poor and progress toward other strategic
development objectives. In Samoa, PREGA focuses on the
identification of environmental/social issues constraining the RE
projects and formulate strategies on how they can be
addressed.
Renewable
Energy and
Energy Efficiency
Project (REEP)
ADB; $0.6m;
2004 - early 2006
The REEP is providing assistance and training, and developing
investment projects for RE & EE. It provided lessons for PICs for
RESCO & EESCO development and possibly useful information
on outer island scale biofuel feasibility.
South Pacific
Applied
Geoscience
Commission
(SOPAC)
SOPAC is the lead
agency in Council of
Regional
Organizations of the
Pacific (CROP) for
energy sector issues
RE & EE actions for
Fiji & Samoa
A wide range of RE &
EE activities
Pacific Island
Energy Policies
and Strategic
Action Planning
project
(PIEPSAP)
UNDP
Samoa/SOPAC;
$1.6m; mid 20042007 through SOPAC
Pacific Power
Association RE &
EE activities
(PPA)
The PPA has advised
the region’s power
utilities since its
establishment in
about 1992 and has
carried out several
RE & EE studies
since 2000.
Secretariat for
the Pacific
Community
(SPC).
Biofuel, Wind and PV
for outer island
communities
ACP Five Country
RE and EE
Project
European Union
!11,4 million for
investment in
renewable energy
and energy efficiency
technologies
Energy Policy
planning advice
In addition to PIEPSAP (below), SOPAC has implemented a
large number of RE & EE activities. These include a UNDESA
demand-side management project ($0.2m; 2002-2005)
providing energy audits & training to Fiji & Samoa power utilities.
Progress in this project has been slow & intermittent. The
project may provide reasons why utilities fail to implement costeffective EE. In early 2005 SOPAC organized a workshop in Fiji
on biofuel development and has been working in conjunction
with the REEP on large-scale biofuel development in Samoa.
Over the years, SOPAC has carried out numerous studies on
geothermal, biomass, ocean thermal and seawave energy. It
has the largest core of energy experts in the PIC region.
This Danish-funded EUEI project has the mandate to assist the
PICs in developing and applying energy policies. Included in the
program are development of utility regulatory policy in Fiji,
examination of the PREFACE installed RMI PV project that has
had problems, and developing RE/EE polices, plans and
possibly regulatory structures for several Program countries.
Both Fiji and Samoa have draft energy policy documents now
under consideration by Government.
PPA carried out a supply-side EE study for PIC power utilities
(including Kosrae, Pohnpei & Palau) in 2001 and an
assessment of potential RE projects in Nauru & FSM in 2002.
There was a workshop in early 2005 on RE for the north Pacific
utilities with support from the E7 utilities, and a second one is
planned for the southern utilities in late 2005. In late 2005 or in
2006, the EU is expected to provide PPA with staff and funding
to increase their activities in renewable energy.
Although SPC no longer initiates regional energy programs,
renewable energy projects such as biofuel (Fiji), PV (Vanuatu,
Tonga, RMI) and Wind (Cook Islands) installed under SPC
management between 2000 and 2004 are still being operated
and evaluated. When evaluation is complete these projects
can be expected to provide useful lessons for the region.
The project is to be implemented through utilities in the
respective countries starting in 2006. Energy efficiency will be
the primary focus for Nauru and Palau and renewable energy for
FSM, Niue and RMI. The project will operate at least four years.
3
Table 1 – Continued
Comments on RE / EE* Activities
Name
Summary
Pacific
Islands
Renewable
Energy Project
(PIREP)
UNDP Samoa/GEF;
~$0.7m; 2003 - end
2005.
Assessments for
15 PICs.
Assessed energy sector issues with opportunities and
constraints for RETs investments to reduce GHG emissions.
15 national reports and regional overview were published in
2005.
UNDP
Several million US$
in the past decade
Development of RESCO structure for Fiji (2000-2003,
Evaluation of Fiji hybrid project, (2004) grid-connected PV in
Tokelau (2004-2005), PV SHS in Samoa (2004-2006, feasibility
studies for coconut oil biofuel for existing power generators in
Samoa and grid-connected wind in the Cook Islands (20042005) ). Plans include GEF RE based GHG mitigation in Palau,
RMI & FSM, & wind resource assessment in Samoa
UN Economic and
Social
Commission
for Asia & the
Pacific (ESCAP)
Various technical
assistance projects
and capacity building
programs
Review of RE energy activities in Tuvalu, Kiribati, Tonga & Cook
Islands with recommendations for future activities. Sponsorship
of training activities and studies directed toward capacity
building for RE in the Pacific. A review of renewable energy
capacity building requirements and facilities in PICs was
prepared in 2004 and a project document for a regional capacity
development program focusing on RETs was presented for
funding in 2005.
UN Asia-Pacific
Regional Energy
Programme for
Poverty
Reduction
(REP-PoR)
United Nations
regional project
based in Bangkok.
UNDP management.
To develop energy for productive use in order to provide for
poverty reduction, rural development and GHG control. Program
will not directly fund projects but is working with countries and
donors for project development.
UN Educational,
Scientific and
Cultural
Organization
(UNESCO)
2002-present &
ongoing
UNESCO / ESCAP
rural
electrification
study
UNESCO, ESCAP &
others;
late 2005-early 2006
Australian
Greenhouse
Office
Fiji Energy
Standards and
Labeling
Scheme
Australian
Greenhouse office
(AGO); Intermittently
from late 1990s –
present
Greenpeace
Pacific
Studies on
sustainable energy in
the PICs
Funding level
unknown.
RE training materials
Rural electrification
experience in Fiji
EE appliance
guidelines and
labeling
Since 2002, UNESCO has been developing a “toolbox” of
training materials for RE development including texts, videos &
other media for decision makers, energy planners, those who
install & maintain RETs and the general public. The focus is on
PICs. Future materials are planned on biofuels. UNESCO also
has co-funded with UNDP small scale RET activities in the
region.
A survey of small-scale rural power generation at Fiji sites with 5
or more years operational experience to provide useful
information on patterns of rural energy use, electrical appliance
use, productive uses of energy, actual costs, O&M problems,
etc. (2005-2006)
The AGO project is developing a common ‘Minimum Energy
Performance Standards’ and efficiency labeling system for
Australia, New Zealand and Fiji, with later extension to other
PICs. Initial coverage is limited to household refrigerators, later
to be extended to other appliances including air conditioning. In
2005, an agreement was signed between the Fiji Government
and the AGO to survey imported appliances and to develop
policies relating to appliance labeling and efficiency.
Greenpeace has prepared studies on opportunities for
renewable energy and improved energy efficiency for Niue, Fiji
and Samoa and has recently increased its activities in
association with RET development in PICs.
EUEI = European Union Energy Initiative; E7 = a power utility organization of the G8 countries (minus Italy);
O&M = operations & maintenance; PIC = Pacific Island Country; PV = photovoltaics; RE = renewable energy;
RET = Renewable Energy Technology; SHS = solar home system; UNDESA = United Nations Dept of Economic & Social
Affairs. ~ = approximately
4
Table 2 - Proposed New Pacific Regional RE or EE Activities:
Name
Summary
Pacific Islands
Greenhouse
Gas Abatement
through
Renewable
Energy Project
(PIGGAREP)
UNDP Samoa/GEF;
~ $5.3m; possibly from
2006 or 2007
Pacific Power
Association
(PPA)
EU; !1m; timing
uncertain, possibly from
2006 or 2007.
RET development for
GHG abatement
HRD, RE & EE
ESCAP
regional RE
training
programme
ESCAP & others;
~ $3.2m;
possibly 2006-2011
Sun Grant
Initiative
US Dept of Energy;
funds and timing
unknown
A.
PIGGAREP is a planned follow-up to PIREP for most PICs
including Nauru and Niue. PIGGAREP was provisionally
approved by the GEF Council in 2005. It is expected to
include a major RE capacity building component.
A ‘Human Resource Development, Energy Efficiency and
Renewable Energy within PIC National Power Utilities’ project
is being considered. It involves utility capacity building and
efforts to improve efficiency of power production, transmission
and distribution. An expert in RE utility operations is proposed
for a 3-year period.
ESCAP proposes an extensive RE training program in
cooperation with other agencies. It has been endorsed by
CROP but no firm funding has yet been identified.
RE capacity building
Development of
bioenergy
REEP follow-up
projects
Comments on RE / EE Activities
ADB; from 2006
RE & EE projects
A coalition of Pacific universities, including the College of
Micronesia and led by the University of Hawaii, plans to
research and develop bioenergy resources for FSM, Palau &
RMI. No details are yet available.
Depending on the results of the REEP, there may be a followup to design and implement several RE & EE projects in Fiji &
Samoa.
REEP team interaction with regional energy programs
58. A member of the REEP team worked closely with ESCAP in its work to develop a
regional project for renewable energy training. Team members also worked closely with
PIREP in its surveys of the PICs, with UNDP in its REP PoR baseline study and
UNDP/SOPAC in their energy related activities in Fiji and Samoa. The team maintained
close contact with the PIEPSAP project and their development of Fiji and Samoa energy
policy and with the Pacific Power Association (PPA) to ensure that REEP efforts did not
duplicate theirs.
59. The REEP team worked with SOPAC in developing and arranging biofuel workshop
and helped in the structuring of the CocoGen project of UNDP that examined the
possibilities for coconut oil use at the Samoa power utility. There has been close
cooperation between the REEP and the SOPAC teams to ensure that there was
maximum synergy and minimal duplication of efforts. SOPAC provided invaluable
assistance in the preparations for and operation of the REEP sponsored regional
workshop from 20-24 February 2006 in Fiji.
60. REEP team members have regularly consulted with senior staff of the International
Institute for Energy Conservation (IIEC), the organization providing services to Fiji and
Samoa under SOPAC’s United Nations Department of Economic and Social Affairs
(UNDESA) supported energy efficiency program. These consultations ensure that
programs developed under the REEP consider the lessons learned from earlier
programs and build on existing programs.
61. REEP team members worked closely with UNDP and its partner agencies in the
development of solar energy for Apolima, Samoa, and in the design and analysis of a
5
survey of rural electrification in Fiji to determine the real cost, productive uses, appliance
mix and other characteristics of diesel mini-grid, PV based and grid extension based
rural electrification.
Table 3 – Regional programs and Fiji/Samoa local programs that overlap REEP activities
REEP
Activities
Policy
Strategies and
Incentives
Establishment
of an
appropriate
institutional
framework for
RE and EE
activities
Regulatory
framework
establishment
Capacity
Building
Poverty
reduction and
rural
development
Financing
schemes
development
Preparation of
Pipeline of
REGA
Projects for
Samoa
Programs/Projects Implemented in Samoa and Fiji that Overlap REEP
(in all cases the Fiji DOE and the Samoa Energy Office within Treasury are recipients/counterparts)
Project Name
Activities similar to
Implementing Project
Date
Date of
Contact
or related to the
Agency
Sponsor
Started
Completi
Person/information
REEP
on
PIEPSAP
Generally identical
Independent
Denmark
2004
2007
Gerhard Zieroth
though broader ins
project
through
[email protected]
scope as it covers all
operated
UNDP
energy not just RET
within SOPAC
and EET
Regional Energy
Some training and
SOPAC
UNDESA 2002
Ongoing
Paul Fairbairn
Efficiency
information delivery
through
[email protected]
Project
IIEC
PIEPSAP
Appliance
labeling program
(initially limited to
refrigerators and
to be extended
to other
appliances
Regional RE
Training Project
Development
Regulatory structures
Independent
project in
SOPAC
Denmark
through
UNDP
2004
2007
Gerhard Zieroth
[email protected]
Support of standards
for EE actions
Australian
Greenhouse
Office (AGO)
Australia
2003
2006
Makereta Sauturaga
[email protected]
Determine the
ESCAP
ESCAP
2004
Ongoing
institutions that can
participate in RET
training and prepare a
project to provide
input for them to
develop an RET
training capability
REP PoR
Renewable energy
UNDP
UNDP
2005
Ongoing
and energy efficiency
development, poverty
reduction, rural
development
No overlapping regional programs though PREGA could be overlapping in the future for Samoa
Rikke Munk Hansen
[email protected]
PREGA
Samuel Tumiwa
<[email protected]>
Identification of
environmental/ social
issues constraining
the RE projects and
formulate strategies
on how they could be
addressed.
ADB
Holland
Apolima PV
electrification
Samoa PV
development
(Apolima)
UNDP
Fiji PV
development
PV installations for
RESCO operation on
Vanua Levu
Savai’i hydro
development
FS of Savai’i
Renewable Energy
Project (0.25 to 2 MW
run-of-river)
2001
Ongoing
Thomas Jensen (Pacific
representative)
[email protected]
Or the REACH
Secretariat at
[email protected]
2004
2005
Thomas Jensen
[email protected]
2005
2006
Makereta Sauturaga
[email protected]
2003
2005
Joseph Walters
[email protected]
6
62. Members of the REEP team maintained close communications with the EU
representatives in Fiji and EU contractors regarding their PV rural electrification project
in Kiribati, the development of the renewable energy and energy efficiency project for the
new ACP countries (Palau, Federated States of Micronesia, Marshall Islands, Nauru and
Niue) and future programs of the EU for regional energy development.
63. The APEC Expert Group on New and Renewable Energy, the APEC Energy
Standards Information System and the proposed UNDP Barrier Removal for the Cost
Effective Development and Implementation of Energy Standards and Labeling Project
are not specifically Pacific regional programs but were a source of information useful for
Pacific project development since they address similar issues as are being considered in
the Pacific.
7
III.
A.
NATIONAL PROJECT DEVELOPMENT AND ACTIONS
Fiji
1.
Steering Committee
64. After Fiji was selected as one of the two countries to take part in REEP, a steering
committee was formed in order to ensure that stakeholders had representation in the
project determination and project prioritization process. Five Steering Committee
meetings were held in Fiji and all proposed projects were reviewed by the Committee
and those that have appeared feasible were prioritized by the Committee. The projects
developed by the REEP team have been approved and prioritized by the Steering
Committee. The Steering Committee members include:
Name
Mr. Peter Johnston
Mr.Krishna Prasad
Mr. Mosese Qasenivalu
Mr. Jone Usamate
Mr. Bruce Clay
Ms. Suliana Siwatibau
Ms. Sharyne Fong
Mr.Horst Pilger
Mr. Abraham Simpson
Mr. Ron Steenbergen
Ms. Sala Nakeke
Ms. Makereta Sauturaga
2.
Sector
Organization
Private
Economic Planning
Economic Planning
Training
Private
Private
Banking
Donor community
Transport
Public Utility
Media
Energy
REEP Local Consultant (Chair)
Ministry of Finance and Planning
Ministry of Finance and Planning
Training & Productivity Authority
Clay Engineering
Independent Consultant
Colonial National Bank
European Union, Apia
Land Transport Authority
Fiji Broadcasting Corporation, Ltd.
Department of Energy
65. PIEPSAP has the responsibility in the Pacific sub-region for the development of
energy policy strategies and incentives and the REEP did not duplicate those activities.
3.
66. Three primary areas of institutional development were the REEP focus in Fiji:
• Development of the requirements for institutional structures that encourage the
development of private Energy Efficiency Service Companies (EESCOs).
• Assistance to the Fiji Department of Energy for the development of institutional
structures to oversee and promote energy efficiency and renewable energy
activities.
• Working with Fiji businesses for the development of a Renewable Energy
Business Association.
a.
Development of structures to support private EESCOs
67. Past energy efficiency efforts have typically been limited to energy audits with audit
recipients expected to proceed with the implementation of the recommendations
provided by the auditor. This has not generally resulted in long term improvements in the
efficiency of energy use. For energy efficiency measures to be properly carried out and
savings maintained for the long term, there needs to be an institutional structure that not
only provides energy audits but also encourages carrying out the energy saving
8
activities, continues to monitor their effectiveness and makes adjustments where
appropriate. The institutional requirements to develop mechanisms that support Energy
Efficiency Service Company activities include:
• Developing the structures necessary to provide specialist training to individuals
and companies wishing to act as EESCOs;
• Determining the regulatory requirements and developing the structure within
Government necessary to regulate EESCOs;
• Establishing the methodology and criteria for an independent agency to determine
the savings effect of equipment that has been installed to improve energy
efficiency;
• Creating a process allowing clients to borrow money for the finance of energy
efficiency improvements at a periodic cost equal to or lower than the periodic value
of the savings brought about by the installed energy efficiency equipment;
• Developing structures that provide performance guarantees to clients to increase
their confidence that the services would indeed provide the expected savings
initially and over time;
• Developing methodology and criteria for monitoring the program on a national
level;
68. These structures would be developed under the regional (Fiji and Samoa) project
prepared by the REEP.
b.
Regulatory and promotional framework development
i.
Appliance labeling
69. The Australian Greenhouse Office (AGO) has a program to assist the DOE in
developing a labeling and certification process that is consistent with that used in
Australia and New Zealand. An Australian volunteer was provided to the DOE and
provided support for this process. Therefore the REEP team did not take any action
regarding appliance labeling or energy efficiency certification in Fiji.
ii.
Renewable Energy Standards Development
70. The comprehensive 2000-2003 GEF project 1 that developed the institutional
structures for RESCO operation in Fiji included development of the structures and
processes for regulation monitoring and enforcement. As part of the regulatory structure,
the DOE has to have standards for the components and the installations and the
maintenance of the solar home systems (SHS). The GEF project included preparation of
the specifications for SHS components for the initial pilot project and those are being
used as standard specifications for the purchase of new equipment to expand that pilot.
The team has reviewed those specifications and though they may be suitable for exactly
replicating the first installations, they should not be considered standards for general
SHS implementation. Also, the GEF project team produced no written standards for the
installation or maintenance activities to be carried out by contracted RESCOs though
such standards are part of the regulatory structure specified under the GEF project.
71. Discussions were held early in the REEP with the DOE personnel responsible for
renewable energy regarding the need for solar PV standards to support the regulatory
1 GEF project FIJ/99/G45 - Renewable Energy Service Companies for Rural Electrification in Fiji
9
responsibilities of DOE. At that time, the REEP team was told that no input from the
team was needed with regards to standards for renewable energy. However, in March,
2005, the team was informed that input to DOE regarding standards for RESCO SHS
components, system design, installation and maintenance would be welcomed. Draft
standards based on those discussions have been developed by the REEP team and are
shown in Appendix 6 and Appendix 7. These standards are considered suitable as
guidelines for all SHS installations in Fiji though the numbers of non-RESCO based
government PV installations are expected to be quite small relative to the RESCO
managed installations. Formal regulation of private installations is not presently planned
by the DOE though the standards provide a useful guide for private PV developers.
iii.
Action plan of structures for promotion of RET and
EET
72. The institutional structures for promoting RET for rural electrification were well
developed under the 2000-2003 GEF project that created a structure and provided draft
legislation to support renewable energy service company operations in Fiji. Also efforts
by PIEPSAP and SOPAC have addressed policy and action planning that relates to
renewable energy development in Fiji by DOE and FEA. Therefore the REEP has not
duplicated those efforts. However, there has been no development of an action plan for
energy efficiency improvement in Fiji and Samoa. The EESCO project being developed
by REEP for both Fiji and Samoa includes the necessary institutional structures for their
implementation and technology promotion and is the core of the action plan for energy
efficiency improvement recommended by REEP. Although Fiji has an Australian
supported appliance energy labeling program, Samoa has not yet addressed that issue.
iv.
Development of a renewable energy association
Table 4 – Private companies specializing in RET or with a strong RET business component
Organization / Person
Contact
Interest
Renewable Energy Services, Ltd
Krishn Raj, Director
PO Box 5045 Labasa
resco@&connect.com.fj
Tel: 881 2618
Fiji’s only RESCO with operations on
Vanua Levu & Taveuni
Hydro Developments Ltd
Ross Brodie, Director
PO Box 3258 Lami;
[email protected]
Tel: office 330 1882
Proposed development of about 8-15
MW of hydropower in Fiji
Clay Engineering
Bruce Clay, Managing Director
PO Box 2395, Govt Bldgs, Suva Tel:
336 3880
[email protected]
Solar PV & wind energy equipment &
consulting services. Strong RESCO
interest.
Clean Energy, Fiji Ltd
Peni Drodrolagi, Director.
[email protected]
Biofuel technologies for outer islands;
solar PV. Agent for biofuel & PV
equipment. Strong RESCO interest
PacifcFree Energy Ltd.
Simon Boxer, Director
PO Box 3520 Lami
[email protected]
tel: 336 1849
Wing resource monitoring. Wind energy
consulting. Wind farm development (one
under development in Viti Levu).
Strong RESCO interest.
Advanced Power Systems, Fiji, Ltd.
Ray Bower, General Manager
PO Box 10376, Nadi Airport
Solar, wind & hybrid energy systems
Natural Power Ltd (subsidiary of
Asia
Pacific
Resources,
Ltd.)
Matthew Huggan, Managing Director
Natural
Power
Ltd,
Savusavu
[email protected]
Holder of license for geothermal energy
development at Savusavu, Vanua Levu
Solar & Alternative Energy Supplies
Peni Valevale
Lot 9, Kalabo Industrial Estate, Nasinu
339 8006
Solar PV sales and installations in
remote areas
[email protected]
10
73. Fiji has a number of private (Table 4) and public (Table 5) companies that have
strong ties with renewable energy and establishing a renewable energy association met
with general approval when discussed with most of them. Mr. Bruce Clay of Clay
Engineering has taken the lead and at the February 20-23, 2006 renewable energy and
energy efficiency workshop, a Renewable Energy Association was formed with Mr. Clay
acting as organizing secretary. A constitution was prepared and approved by the
founding members.
Table 5 – Public Companies with significant renewable energy activity or interests
Organization / Person
Contact
Tropik Wood Industries Ltd.
Interest
Private Mail bag, Lautoka
[email protected]
CEO Tel: 992 9778
Office: 666 1388
Woodwaste-based power generation. A
PPA has been signed with FEA to provide
several MW of additional wood-based
generation
Fiji Sugar Corporation Ltd
Ross McDonald, Chairman
Abdul Shamsher, Acting CEO
3rd floor, Western House, Lautoka
Head Office Tel: 666 2655
Chair Tel: : 330 5744
30 MW+ of bagasse-fuelled generation. A
FJ$50m upgrade planned using bagasse &
wood. Ethanol fuel under study
Coconut Industry Advisory Board
Ken Roberts, chair
John Teaiwa CEO
Gunu House, Gladstone Road, Suva
Tel: 330 0503
[email protected]
Has proposed to Fiji’s cabinet the
commercial development of coconut oilbased biofuel development
Rokoseru Nabalarua, CEO
2 Marlow Street, Suva
[email protected];
CEO Tel: 322 4301 & 999 2418
GM Tel: 332 4348
Over 80 MW of hydro in operation with
more planned. A 10 MW wind farm under
development. Small solar PV
demonstrations. Other RE under
consideration
Mr Alec Chang, CEO
Ron Steenbergen, General Manager
for Major Projects & Strategy
4.
a.
Renewable Energy
74. The team has interviewed the management of all commercial banks operating in Fiji
and the Fiji Development Bank. Though solar water heaters have been financed through
some banks, there is little activity by any financial institutions in Fiji related to renewable
energy or energy efficiency.
75. There is increasing activity in Fiji regarding micro-finance and rural banking services,
though to date there has been no attempt to market renewable energy to rural
households through these services. In 2005, with support from UNDP, the ANZ Bank
began a “roaming” banking facility that includes a specially equipped van to visit rural
areas and provides banking services to rural customers on a schedule. The service is
too new to evaluate but is expected to provide small rural loans in the future.
76. The National Centre for Small and Microenterprise Development (NCSMED) has a
nation-wide micro-finance program, the National Micro Finance Unit (NMFU). The goal
of the micro-finance program is to “create an enabling environment of a micro-finance
industry, which will focus on providing financial services specially designed for the poor
and disadvantaged households in the country”. The NMFU does not itself provide microfinance services. It creates and works with NGOs that have as their specialty the
delivery of micro-finance services to rural Fiji.
77. Since there is already a well developed micro-finance structure in Fiji, the REEP
team is not working to establish micro-finance but worked with local renewable energy
companies and NGOs to encourage them to establish marketing programs that could
take advantage of already available rural finance for the purchase of renewable energy
11
systems. This is expected to be continued as an early activity of the Renewable Energy
Business Association.
b.
Energy Efficiency
78. There are many opportunities for investments in energy efficiency improvements
both at the domestic and the commercial levels but there is little experience with
financing such investments. Interviews with commercial finance providers indicate that
they have little knowledge regarding the risks associated with energy efficiency
investments.
79. At the household level, the largest improvement in energy efficiency is from
replacement of incandescent lamps with more efficient compact fluorescent lights
(CFLs). The primary barrier to the adoption of the high efficiency CFL bulbs is not the
specific cost of the CFLs as they are well within the budget of the majority of Fiji
households. The barriers to their purchase include:
• CFLs are more expensive that the cheapest incandescent lamps. Consumers have
higher priority uses for the immediate cash that is saved by choosing the low cost
bulbs.
• Energy cost savings from use of CFLs is not known to most consumers
• Bulbs that are available in the Fiji market are not always suitable for direct
replacement of household incandescent bulbs due to size or the base
configuration.
• Availability is generally limited to large grocery and hardware “super” stores.
Neighborhood stores rarely stock anything but incandescent bulbs.
80. The problem at the household level is technically not one that relates to the
availability of unconventional finance. However special financing programs can be
developed that provide high efficiency lighting through the FEA with payment for the bulb
through a charge to the customer lower than the savings that has accrued through the
replacement of the light. In essence such programs are actually more to change the
perception of customers than to overcome true financial barriers.
81. In April, 2005, the REEP team discussed this concept with FEA management and
provided FEA with calculations that demonstrated significant economic benefits of such
a program to FEA as well as to its domestic and commercial customers. FEA
management then indicated that if FEA internal analysis shows a similarly high level of
benefit as indicated by the REEP team calculations, FEA will develop the idea internally
without any need for external funding. Subsequently, FEA began subsidizing CFLs
imported by a private company (Poly Products, which has a commercial office at FEA
headquarters). In late 2005/early 2006, FEA/Poly Products have made CFLs available at
selected outlets to consumers on a two-for-the-price-of-one basis. The program has not
been evaluated but has apparently been successful with sales reportedly over 100,000
units over the time period of the subsidy.
5.
Capacity building
82. A continuing problem facing the development of large scale renewable energy and
energy efficiency programs is the lack of training courses for the technicians who will be
installing and maintaining the equipment associated with the programs. In particular, the
12
plans for large scale solar based rural electrification based on the RESCO model will
require a continuing access to training for field technicians and installers.
83. The REEP team has worked with the institutions that have a mandate for technical
training to determine their needs and to provide capacity building and program support
for renewable energy development if needed. The goal is to create a continuing, locally
supported training for renewable energy development. This will particularly focus on
solar photovoltaics since that appears to be the technology most likely to require
technical training support in the near term.
84. Of the four main educational institutions in Fiji that provide post-secondary education
and vocational-technical training courses (Table 6), the REEP team concentrated on
cooperation with the Fiji Institute of Technology (FIT), the Trade and Productivity
Authority of Fiji (TPAF) and the Centre for Appropriate Technology and Development
(CATD) since all have an interest in increasing and improving their existing renewable
energy and energy efficiency course content. The University of the South Pacific (USP)
provides tertiary degrees in academic areas that include technical content relating to
renewable energy and energy efficiency but do not need inputs from the REEP.
Table 6 – Post-Secondary Education and Vo-Tech Training institutions in Fiji
Institution
University of the South Pacific (USP)
Fiji Institute of Technology (FIT)
Trade and Productivity Authority of Fiji
(TPAF)
Centre for Appropriate Technology
Development (CATD)
a.
Primary Function
Comments
Post secondary education through the
PhD level. USP is the largest
university complex in the Pacific and
serves most of the PICs as a regional
university with costs shared by
member countries.
Public post-secondary institution
providing certificates, diplomas and
degrees in technology and vocational
technical training.
Government institution primary to
support industry in both technical and
non-technical training.
Includes renewable energy and
energy efficiency in its technical
curriculum. USP has developed formal
courses in RE and issued MSc
degrees in energy-related areas.
REEP input not required.
Includes programs that have
components relating to renewable
energy and energy efficiency.
Government (Ministry of Fijian Affairs)
training facility concentrating on the
development of maintenance and
repair skills for rural Fijian students
Programs concentrating on short
courses provided in response to the
expressed needs of business and
industry. Few permanent staff, most
courses provided by instructors under
short term contract
Has included solar PV technician
training in its curriculum since 1989.
Interested in upgrading PV training
facilities and course content.
Training for renewable energy technicians
85. Given the resources available to the REEP team and the expectation of rapidly
increasing solar PV for rural electrification through RESCOs, the team concentrated on
supporting the CATD in their program to provide short courses for RESCO technician
training. CATD has been the primary PV technician training facility for Fiji for over 15
years. Also, CATD has no access to substantial technical, financial and staff resources
as FIT and TPAF have thus, will benefit most from the modest assistance the REEP can
provide. The team was asked to assist CATD in preparing a proposal for locating funding
in the amount of approximately $15,000 for PV training facility improvement, including
replacement of training equipment (primarily solar panels, batteries and controllers)
provided by a UN program in 1989 and in the construction of a small structure for
practice installation of solar home systems (see Appendix 9 for details). The team,
however, continued to work closely with FIT and TPAF in the development of course
materials and instructor training for course development.
13
86. As part of that development, a two-day training course was provided for FIT, TPAF
and CATD trainers in February 2006. Details of that training of trainers course and the
PV training curricula at FIT are shown in Appendix 8
87. It is likely that FIT will become a centre in the South Pacific for general RET and EET
training while TPAF limits its training to Fiji. CATD is expected to maintain its specialty
role as provider of training for PV technicians both in Fiji and other PICs.
b.
Other renewable energy capacity building programs for the
Pacific that will affect Fiji
88. In 2004, ESCAP funded a review of training facilities in the Pacific and of the needs
for renewable energy training in the PICs. PIREP also included renewable energy
capacity building requirements as part of the survey of the PICs in 2003 and 2004. As a
part of its program, ESCAP developed a concept for a renewable energy capacity
building regional program that was approved during the 2004 Regional Energy Meeting
(REM) and later by the CROP. A project document was prepared for funding in 2005.
The concept includes a proposed budget of around US$3 million for a three to five year
program that could cover all the PICs including Fiji and Samoa. No funding is yet
identified or allocated.
89. Also in the pipeline is a GEF proposal, the Pacific Island Greenhouse Gas and
Renewable Energy Programme (PIGGAREP), as a follow on to the Pacific Islands
Renewable Energy Project (PIREP). Capacity building is a major component of that
proposal and the resulting project would include Samoa and Fiji. If all approvals are
received, implementation is not likely in the PICs before 2007.
c.
Energy Efficiency training
90. It is noted that at present neither the ESCAP nor PIGGAREP capacity building efforts
includes development of energy efficiency technology training. The Team considers the
development of a training component within the proposed sub-regional EESCO
development project as vital to its initial and long term success and to the further
development of energy efficiency measures in Fiji and Samoa. The training materials to
be prepared under that project are expected to be appropriate for distribution to the rest
of the PICs.
91. The current FIT and TPAF curricula include components on energy efficiency
measures and there is interest in cooperating with programs that can provide facilities
and support to the further development of EE training at FIT. The sub-regional program
for EESCO development that is proposed elsewhere in this report (Section IV) includes a
training component that will include FIT and TPAF as training facilities that can be
developed for ongoing energy efficiency training courses. Although not officially a
regional institution, FIT effectively serves several countries, (e.g. Tuvalu and Kiribati),
and the number of persons who can be expected to participate in energy efficiency
training should be large enough to warrant a specialist course, though probably not a full
diploma program in energy efficiency.
92. TPAF has provided short courses in energy audits and other aspects of energy
efficiency technology and will continue to do so provided suitable instructors can be
located and there is sufficient interest by businesses and industry. TPAF has managed
an effective 2005 energy efficiency demonstration program supported by the Asian
Productivity Organization (APO) at a Suva-based steel mill and is preparing training
materials based on this experience. The proposed EESCO sub-regional program is to
14
include training of trainers to support both FIT and TPAF in further development of EE
training capacity.
6.
Regional activities by the REEP team.
93. The REEP supported one presenter with travel from Europe for the “Towards
Increased Use of Biofuels In Fiji” workshop sponsored by SOPAC in Suva, March 2005,
and the Fiji local REEP consultant attended the workshop.
94. A final regional workshop on renewable energy and energy efficiency that included
all PICs, regional organizations and donor agencies was organized by REEP with the
assistance of SOPAC from 20-24 February 2006 at CATD (see Appendix 10).
95. Team members maintained continuing consultations with:
• IIEC in Bangkok regarding their Pacific activities, the practical aspects of EESCO
formation for the PICs, the history of the current EE project in Fiji and other
supporting information;
• SOPAC regarding their activities in Fiji, in particular as relates to EE and capacity
building, and discussions regarding areas where the REEP can cooperate and
coordinate;
• PIEPSAP concerning their activities in Fiji in supporting the development of a
national energy policy;
• The EU delegation in Suva regarding their activities and REEP cooperation with
their programs.
7.
Project development
96. A major goal of the REEP was to prepare at least one project proposal for renewable
energy and one project proposal for energy efficiency that had strong support by
stakeholders and which can serve as a replicable model for further development. In Fiji,
the FEA and the DOE are the primary implementers of renewable energy and energy
efficiency programs and any project development by the REEP had to be appropriate to
their capacity and needs.
97. In Fiji, the primary cause of delay in the development of projects was the repeated
changing of priorities and direction proposed for REEP project development by FEA and
delays in receiving adequate information from FEA about the background for the
renewable energy projects they have proposed. Of the projects proposed by DOE, their
initial top priority project (100% conversion to renewable energy for the island of Moala)
was found to be impractical for development under the REEP and, in early 2005, was
changed to coconut oil use for fuel in Rotuma causing that project to begin development
late in the program. Project priorities and content were finally fixed by the Fiji Steering
Committee in February, 2005. All projects listed below were approved and prioritized by
the Steering Committee.
15
8.
Priority 1 Project in Renewable Energy: Namosi hydroelectric joint
venture
a.
Project concept and objectives
98. The projections for the Viti Levu electrical demand and capital investment programs
by the FEA indicate a continuing dependency on diesel generation and imported fuel for
the foreseeable future. Although FEA proposes investing heavily in hydro, is committed
to a modest investment in wind power and is likely to begin using biofuel for diesel
generation in the near future, the importing of diesel fuel is expected to remain a
significant requirement for power generation for at least 20 years and probably longer.
99. To encourage private investment in electricity production, the FEA has recently
developed a new policy for accepting energy from Independent Power Producers (IPP).
In the past, FEA only purchased energy that was surplus to the needs of large
companies such as Emperor Gold Mines, Tropik Woods and the Fiji Sugar Corporation.
100. To take advantage of this policy, a joint venture has been formed, Namosi Hydro
Ltd., that includes the land-owning communities of the Namosi area, Namosi province
and a local engineering company. The Joint Venture, Namosi Hydro, Ltd., has been
formed specifically to develop the hydro resources of the Namosi region as an IPP for
the sale of electricity to FEA with benefits intended for the economic development of that
rural region. In 2004, the joint venture commissioned a pre-feasibility study,2 the results
of which indicate favorable conditions for economically reasonable development of the
resource to make available more than 10 MW of capacity.
101. The expected results of the project are closely aligned with the objectives of the
REEP and the Government of Fiji. The project uses only renewable energy, provides for
rural development, is private sector sourced and provides for poverty reduction in the
affected areas. Therefore following approval by the Steering Committee with support by
the Fiji Department of Energy (DOE), the REEP team assisted the Joint Venture in
structuring its proposal and developed a project concept for the funding of a full
feasibility study. If that study indicates economic viability, follow-on funding of an initial
phase of project construction can be obtained from private sources or through an
international finance organization.
102. The project concept is unique in Fiji and the Pacific Region for hydro energy
development. In the past the utility and government have negotiated with land holders to
lease the land providing the resource rather than involving them in the ownership of the
power development. Since a hydro facility is expected to be in operation for many
decades, the terms negotiated at the time of installation are often not considered
adequate in later years. For example, land owners associated with the 1983 Monasavu
hydro development now feel that the terms negotiated in 1983 are no longer appropriate
when viewed in the light of changing economic conditions. For the Namosi project, the
land holders are among the principal developers of the resource and share in the profits
and risks, curtailing future alienation of landowners from the project. The proposed
shareholder structure is shown below. The Namosi Development Company represents
the interests of the communities and the Namosi Province as well as those of Hydro
Development Ltd., the local engineering company that will provide the technical support
for the project.
2 “Prefeasibility Study for Mini Hydro schemes in Namosi, and Naitasiri Province in Viti Levu, and in Taveuni Island”
Report N° 1 36 0220 R1, SOGREAH (France), April 2004
16
SHAREHOLDER STRUCTURE
Namosi
Development
Company
80%
Hydro
Development Ltd.
10%
5%
Ratu Suliano Matainitoba
Namosi Hydro Ltd.
5%
Ratu Kini Viliame Taukenikoro
103. The viability of the project concept is dependent on the willingness of the FEA to
purchase all the power produced by the facility and on the price per kWh that is paid.
FEA has provided a letter to the Joint Venture indicating their willingness to purchase
energy from the project provided the quality of power and operational arrangements of
the project meet FEA standards. The expected purchase price based on the FEA
proposal is FJ$0.135 per kWh. Though FEA at this point will not provide a purchase
quantity guarantee, the FEA system has a load that is projected to continue growing at
4.5% annually in demand and 5.5% annually in energy over at least the next decade 3
and is presently operating near capacity with a significant portion of its energy generated
by high cost diesel generators 4. There is therefore good reason to assume that a
relatively small project of this type can sell all the power it produces to FEA for the
foreseeable future while offsetting the high cost of diesel power production.
b.
Location and site characteristics
104. The prefeasibility study for the project included sites in both the Namosi and
Naitisiri provinces of south eastern Viti Levu. Figure 1 indicates the overall catchment
area for those sites and the small insert shows the relative location of the project in Fiji.
The long term plan is for development of both Namosi and Naitisiri sites. Initially, only
the Namosi development is being proposed as it is easily accessed and is closest to the
substation where the transmission line from the project will connect to the FEA grid.
105. Though only the Namosi component of the project is covered under this
proposal, the transmission line will be designed to have sufficient capacity to handle the
output from all the Namosi and Naitisiri sites that have been considered in the
prefeasibility study (Appendix 1) as they are intended to be developed over the longer
term.
106. The project area is mountainous and mostly forested with the population
concentrated in permanent villages along the rivers. There is minimal economic
3 FEA Corporate Plan of 2004-2006 dated March 2004; Information Dossier for investors, dated March 2005
4 FEA is just now in the process of installing an additional 30MW of capacity on Viti Levu in the form of four 7.5 MW
Caterpillar diesel gensets.
17
development in Namosi and the local economy is heavily subsistence oriented. Cash
income is largely from the sale of agricultural products in the Suva market.
107. Lands downstream of the project sites are mainly used for agriculture. Stream
flows are not expected to be affected by the project as there will be no major
impoundments. Water quality will remain the same and will not affect the existing
subsistence economy of the villages.
i.
Geology
108. Mr. Geoff Taylor of PacAu (Fiji), Ltd., carried out a geological survey report for
the Joint Venture in February 20045 and found no reason to consider the sites as
geologically unsatisfactory for the type of hydro development proposed though he notes
that auger soil grids should be done for the sites to accurately determine the depth of
soil cover. A more comprehensive geological study is included in the feasibility study
project proposal.
ii.
Hydrology
109. The flow characteristics of the streams were estimated on the basis of rainfall
data and very limited hydrological data. A number of years ago, some stream gauging
was done in the area and the data was purchased from the Fiji Government though
much of the data was not received until after the prefeasibility study was completed. A
preliminary analysis of that data was supportive of the prefeasibility conclusions though
there remained gaps in the gauging network that needed to be filled. In 2005, the Joint
Venture purchased and installed additional stream gauges in areas where insufficient
prior data has been obtained and by the commencement of the feasibility study,
sufficient data are expected to be available to provide acceptable accuracy in
hydrological analysis. Until better data can be obtained, there is significant risk that the
stream flow estimates used for the financial analysis are too high and cause an
overestimation of the income from the project.
c.
Project Background
i.
Prefeasibility
110. A prefeasibility study (See Appendix 1) of seven sites was carried out in early
2004 by Mr. Jean-Paul Huraut of SOGREAH (France) for sites in the Namosi and
Naitisiri provinces as listed in Table 7. A site in Taveuni was also examined in the study
but is not included in this table. For each site, the consultant defined the catchment area,
estimated the hydrological and geological characteristics, proposed a dam and power
house location, indicated a suitable route for access, estimated the total cost and
estimated the annual power and energy production that could result.
Table 7 – Summary of Prefeasibility Study Site Estimates
Site
Waimanu
Namado
Waisoi
Waivaka
Wairokodra
Wailutulevu
Wainikovu
Estimated Power
Estimated Energy
(MW)
GWh/year
3.2
10.5
7.7
24
4.9
16.3
4.2
13.5
2.4
7.6
Not recommended for development at this time
Not recommended for development at this time
Estimated Cost
millions of USD
12.3
17.5
11
11.6
7.1
5 “Preliminary Geological Investigation of Five Hydro Dam Sites in the Namosi and Naitisiri Provinces Viti Levu Fiji” Geoff
Taylor, PACAu (Fiji), Ltd., 06 February, 2004
18
Figure 1 - Catchment Area Map of the Proposed Namosi and Naitisiri Hydro Development Sites.
ii.
Financial
111. The Namado and Wairokodra sites are proposed to be the Phase 1 development
for a total estimated cost of US$24.6 million and a total annual energy production of 31.6
GWh representing annual gross revenue of approximately US$2.8 million of which 80%
of net profits would go to the communities of the affected region.
112. The Joint Venture has developed financial spreadsheets that indicate a FIRR of
over 7% based on soft loan funding and imply an EIRR substantially greater than that
due to the considerable economic benefits for the region that are expected to accrue
through the project. The accuracy of these values, however, is very dependent on the
accuracy of the hydrological estimates and a more complete hydrological analysis that
includes the data now being collected is needed before there is adequate assurance that
19
the FIRR and EIRR are sufficient to proceed with the construction of the project. That will
be a component of the proposed feasibility study.
iii.
Environmental Impact
113. The area is thinly populated and the impoundments relatively small. No major
agricultural areas are affected though some pasture land would be flooded. No villages
will be flooded and there are expected to be few problems associated with relocation of
the small number of households that have residences or actively engage in agriculture in
the areas that would be flooded. It is noted that some of the upper Navua River wetlands
has been listed as a Ramsar site but the site does not overlap the catchment area of the
proposed project.
d.
Next Steps
114. To obtain funding for the construction of the proposed power development, a
comprehensive feasibility study and engineering design study will be necessary. Since
there is considerable overlap in the skills needed for a feasibility study and for the
engineering designs, the REEP team has developed a project document for these as
one combined technical assistance (TA) project thereby reducing the total cost of project
preparation.
i.
Feasibility and Engineering Design Study Technical
Assistance project outline
115. The Namosi feasibility and engineering design study will be implemented in two
stages: (i) stage 1 ensures that a power development strategy and a lowest cost/benefit
ratio option is followed that will maximize economic, social and poverty reduction
impacts and (ii) stage 2 develops the design for those hydropower projects suitable for
financing by ADB and/or other external funding.
116. Phase 1 will: (i) review relevant studies on power demand and supply in Fiji and
for the Namosi hydropower development; (ii) establish a Steering Committee within 4
weeks after commencement that includes representatives from all key stakeholders; (iii)
formulate the lowest cost/benefit ratio hydropower development scheme in Namosi
Province in consultation with stakeholders; (iv) undertake a detailed socio-economic
survey, environmental impact assessment, and land acquisition and resettlement plan in
accordance with requirements of local regulations, ADB safeguard policies and those of
other external funding agencies that may be associated with the hydro development; (v)
assess existing institutional arrangements and identify measures to enhance project
management; (vi) analyze FEA power purchasing policies and their financial and
economic impact on the proposed Namosi project; and (vii) assess and identify a
financing scheme suitable for the joint venture arrangement, Government, ADB and
other funding sources expected to be associated with the project.
117. Based on the results of Phase 1, Phase 2 will develop the hydropower supply
project suitable for external financing as follows: (i) assessment of highest priority
components of the project for ADB financing; (ii) preparation of an engineering design of
the proposed small scale hydropower projects; (iii) preparation of a project design
document for Clean Development Mechanism (CDM) approval; (iv) development of a
business plan for the project developer/owner, i.e., Namosi Hydro Ltd.; and (v)
preparation of documents needed in project financing and for negotiations with FEA for a
power purchase agreement.
20
118. The TA is estimated to cost US$1,040,000 equivalent, with a foreign exchange
cost of US$555,000 and a local currency cost of US$485,000 equivalent Local funds are
available to provide part of the local currency cost equivalent to US$300,000. Funding
for the remaining US$740,000 is being actively sought but no commitments have yet
been received.
119. Namosi Hydro Ltd. will be the executing agency of the TA. Namosi Hydro Ltd. will
provide overall supervision and help ensure adequate cooperation from the Government
and non-government organizations as well as villages in the project area. Namosi Hydro
Ltd will recruit/hire a project manager with qualifications acceptable to ADB.
120. The TA will require about 18 person-months of international consultant services
composed of a hydropower planning engineer, an economic and financial analyst, a
private sector/institutional specialist, an environmental and social assessment specialist
and other short-term specialists as identified during Project implementation (e.g., for
geological and hydrological assessments). Domestic consultants will be hired, equivalent
to 14 person-months, consisting of a community development and resettlement planning
expert and other short-term specialists as identified during Project implementation (e.g.,
a local environmental specialist). TA implementation will be assisted by a team of
international and domestic consultants.
121. The TA will be implemented over a period of 20 months with the time about
equally divided between Phase 1 and Phase 2 assuming that the results of Phase 1 are
favorable to the project continuing.
21
9.
Priority 2 Renewable Energy: Rotuma electrification using biofuel
a.
122. In October 2004, the Coconut
Industry Development Authority (CIDA)
recommended Rotuma to the REEP
Steering Committee as a site for
renewable energy development using
coconut oil as a replacement for diesel fuel
for power generation.
Figure 2 – Rotuma Location Map
123. After receiving the support of the
DOE, the Steering Committee approved
the concept in February 2005. A site
survey by the REEP Fiji local consultant
was carried out in October 2005 and
further data were gathered after the
survey.
124. Rotuma is the most remote island
of the Fiji group located over 450 km to the
north of the main islands The island has a
total population of about 2,500. The
primary fuel used for electricity generation
is imported diesel fuel. The remoteness of
the island resulted in shipping costs of
products in and out of the island being the
highest in Fiji. This includes importation of
diesel fuel oil and shipping of copra
products to Vanua Levu.
Likewise,
irregular deliveries of these products occur
Source: http://www2.hawaii.edu/oceanic/rotuma/os/hanua.html
due to bad weather conditions or when cargo loads are not enough to justify shipment.
125. Rotuma copra sent to Vanua Levu has the highest shipping cost for copra in Fiji.
If that copra could be converted to fuel to replace the diesel fuel imports that also have
the highest fuel shipping costs in Fiji, there would be substantially greater returns to local
copra producers and lower costs for electricity. A project to develop the private, local
production of biofuels on Rotuma therefore fit the REEP objectives of rural development,
poverty reduction and private investment in renewable energy and energy efficiency.
126. A TA project has been prepared to determine the economic and technical
feasibility of (i) producing coconut based biofuel on Rotuma in sufficient quantity to
provide for the majority of power generation needs on the island; and (ii) upgrading the
power system to a central generation system to use the biofuel in the most efficient and
cost effective manner.
b.
Project proponents
127. The CIDA was the official proponent of the project and has considered Rotuma
with its high per-capita copra production and the dual benefit from the project – the
elimination of shipping costs for both fuel and copra – as being most likely for local
biofuel production to be economically and technically reasonable.
22
128. The concept of the project was strongly supported by the Rotuma Island Council.
They felt it could dramatically improve the reliability, quality and cost of producing
electricity on Rotuma. Discussions with households on Rotuma also indicated almost
universal support for utilizing locally produced fuel for electricity production.
129. The project was endorsed in principle by the Office of the Prime Minister, the
Ministry of Finance and Planning (MOFP) and the DOE.
c.
Project Background
130. Rotuma is volcanic, 44 km2 in land area (14 km long by 4.3 km at its widest) with
central hills (see Figure 4) reaching 262 meters in height and abundant coconut trees.
An unpaved road circles the island linking all villages. Until recently there were twiceweekly 2" hour flights from Fiji’s capital Suva by small turboprop aircraft but due to a
problem between the Fiji Government and the air carrier over the payment of subsidies,
flights were reportedly stopped in April 2006 so the only access is the irregular ocean
transport that sails every 4-6 weeks with a 36 hour transit time from Suva to Rotuma.
131. On paper, nearly 90% of the island’s population is electrified using numerous
independent diesel generators feeding small underground village grids but often many of
these are not operational, sometimes for long periods. In October 2005, only 73% of
village households had a connection to a functioning electricity system.
132.
Service is typically provided for 4-6 hours each day with extended periods
without service due to lack of fuel or mechanical problems. In 2004, the island was
reportedly without fuel for two months due to shipping problems and during 2005 there
were numerous periods where power was restricted for both the government system and
communities, sometimes due to slow fuel delivery and sometimes to lack of funds to
purchase fuel.
i.
Government Station Electricity Supply
133. There is a government station that includes the postal service, satellite
telecommunications center, hospital, administrative centre, school and government
offices. Affairs are managed by an elected council of traditional chiefs, the Rotuma
Island Council (RIC), for a three year period. The RIC has about 22 members that
include chiefs and sub-chiefs from all districts plus several Fiji government officials.
134. A highly subsidized Government power system serves the government station
and nearby households, reaching about 10% of the island’s population using a small
diesel generator and underground distribution. The system serves the government
complex at Ahau and nearby housing that includes eleven civil servants’ quarters, seven
private homes and a church at Tieri village 1 km south and another nine private houses
between 0.2-0.8 km to the north. The government system normally operates for eight
hours daily from 08:00-12:00 and 18:00-22:00. When there is ample fuel, it also runs
from 05:00-08:00 but when fuel supplies are low, operating hours are reduced.
135. There are no records of kWh of energy produced nor maintenance schedules at
the Rotuma government power house. However, fuel consumption was reported as an
average of 350 liters of diesel fuel per week or about 18,000 liters per year. According to
the Public Works Department (PWD) Water Supply Office, an additional 48,000 liters of
fuel are used each year for three gensets for electric water pumping. That makes a
government total of 66,000 liters of diesel fuel per year for power generation. An
additional 50,000 liters per year is estimated for village electrification making a total of
116,000 liters (116 KL) of diesel fuel per year used in Rotuma for power generation.
23
ii.
Existing Village Electrification
136. By far the largest population concentration (887 persons in 2003) is in Itu’ti’u in
the general vicinity of the government centre. Away from Ahau, electricity is generated
by many small diesel gensets operated by users or a local committee. There are several
privately-owned solar PV electricity systems at homes and shops.
137. In October 2005 the visit by the REEP consultant included a detailed survey of
the electricity use in three villages, visits to all electrified villages, and interviews with
operators. The survey found 470 homes connected to 19 generators of which 389
actually had electrical service the day of the visit (See Appendix 2 for details).
138. The village power systems are usually operated only at times of peak need, the
quality of power is typically poor and system reliability is low. Long periods without power
are common due to delays in ordering and receiving repair parts, lack of village funds for
purchasing replacement parts or fuel and at times delayed fuel deliveries. The fuel
efficiency of the village generators is very low.
Figure 3– Village and Pumping Station Locations on Rotuma
Modified by REEP from map at http://www2.hawaii.edu/oceanic/rotuma/os/hanua.html.
139. During October 2005, the REEP also arranged a detailed household survey of
appliance use, electricity use and attitudes toward electrification in 51 households in
three communities all of which had been electrified for at least five years and
presumably had reached some stability in electricity use patterns. There was little to
suggest that villagers expect a significant increase in electricity use through the
purchase of new appliances or the establishment of new businesses. However the
experience in several other PICs indicates that shifting from a part-time electricity supply
to a 24 hour supply does significantly increase the use of refrigerators and freezers and
this should be expected in Rotuma.
iii.
Diesel Fuel Supply and Cost
140. Fuel is purchased, shipped and stored in 200 liter drums, the most expensive
storage arrangement used in Fiji, since tanker access to bulk storage was destroyed in a
cyclone. In October 2005, villages reported paying FJ$1.70-1.83 per liter of diesel fuel.
Several communities reported paying FJ$1.80 per liter even when purchasing a full 200
liter drum. In addition to the fuel cost, Rotuma is subject to charges from the supplier for
damaged drums. Each drum carries a deposit of FJ$50, returnable if the drum is sent
back undamaged. Damage is reportedly common and adds significantly to the cost of
fuel supply.
24
iv.
Load forecast
141. There are no historical data available from which to estimate the future growth in
demand. There has been no population census since 1996 but population is said to be
stable. There are plans to construct a new air-conditioned hospital in 2006 but the plans
have not been made available, so it is difficult to estimate the impact on demand though
it will increase considerably.
142. Overall, power demand is expected to grow slowly due mainly to increasing
appliance ownership by households (refrigerators, freezers, washing machines, irons,
TVs) and the development of new government facilities. A change from several hours
per day of unreliable village power to a 24-hour service will also increase demand,
especially with the satellite television service that was recently introduced by Fiji TV to
Rotuma and the 24-hour operation of the refrigerators/freezers. The magnitude of
increase cannot however be accurately predicted, until a reliable baseline data on
current electricity use is available.
143. A centralized system would require about 100 kVA for the current government
load (power distribution and electric water pumping) and a similar capacity for rural
electrification, excluding back-up requirements. Present indications are therefore that
Rotuma will need roughly 250 kVA to cover the existing customers. Additional capacity
will be needed for back-up and for the consumption of the proposed coconut oil mill.
v.
Coconut Resource and Coconut Oil Potential
144. There has been no recent survey of the coconut resource in Fiji or Rotuma in
particular. In 2006, the SOPAC agreed to arrange high-resolution satellite imagery to
provide an accurate current assessment of the resource and its availability for transport.
That assessment should be available late in 2006. A 2004 report prepared for CIDA
indicated that in December 1999 Rotuma had somewhat less than this: 2,615 hectares
or 59% of land area under coconuts, 100% of which were of a productive age. Sources
in Rotuma suggest a potential output of between 11,610 and 12,550 metric tons of copra
(10% moisture content) from 2615 ha, an average of 12,080 metric tons. It is therefore
assumed for prefeasibility purposes that the maximum yield of copra with the current
resource is on the order of 12,000 metric tons per year.
145. Most of the lower parts of the island are covered in coconut trees. Although
Rotuma is hilly, most coconut trees are near the coast and nearly all of the area planted
in coconuts is said to be readily accessible. In 2005, CIDA reported that the island has
the capacity to produce 1,500 metric tons of copra per year equivalent to 900 metric tons
of coconut oil and has the potential to double output to 1,800 metric tons of oil without
new planting.
Figure 4 – Ahau and Northwest Rotuma from Maka Bay
Photo: P Johnston October 2005
25
146. From 1970 through 1980, copra production averaged 1,300 metric tons per year.
In the past five years, copra production has never exceeded 1,500 metric tons per year,
and has generally been declining, presumably due to the poor price of copra.
147. In principle, based on the CIDA data, a preliminary estimate suggests that
Rotuma-produced coconut oil should be able to displace 81% (94 KL / 116 KL) of the
diesel fuel now used to produce electricity with no additional effort by coconut suppliers.
Without new planting, but with a much higher, but still quite practical, rate of collection of
available nuts, Rotuma should be able to produce about 162% of current diesel fuel
demand. To displace all 116 KL of diesel fuel, Rotuma would need to produce about 122
KL of coconut oil. That would require about 1846 metric tons of copra or less than 16%
of the estimated maximum copra production of 12,000 metric tons from all of the 2615
ha of land currently under coconut trees.
148. The current efficiency of conversion of diesel fuel to electricity is very low, partly
due to poor engine maintenance but mainly to the use of over 20 small generators that
have inherently low fuel efficiencies. The project should see major improvements in fuel
efficiency through centralization of power generation allowing the present volume fuel
use to cover substantial increases in energy demand.
vi.
The Economics of Coconut Oil Production in Rotuma
149. Coconut oil is not produced commercially in Rotuma. Approximately 14
conventional biomass-fuelled copra driers produce small quantities of copra, often at low
quality, for sale to Three Sisters, the local copra purchasing and shipping company.
There are also two solar driers, a large one (5 metric tons capacity) at Kalvaka, Noa’tau
District, built around 1994 which is used intermittently to produce a higher-grade of copra
and a small one (0.5 metric tons capacity) at Maf’toa, Itu’muta, which is used regularly.
Most copra is produced by Three Sisters itself using a biomass-fuelled drier.
150. The world price of coconut oil exported from Fiji in 2005 was US$620 per metric
ton (about FJ$1,000/metric tons) or FJ$0.91/litre. This has been fairly static for some
months but is higher than the medium to long-term projections of US$400-600/metric
tons. The real value of oil to Fiji as an export commodity is somewhat lower as freight,
insurance and other charges to transport the oil to market must be paid. The removal of
the high cost of shipping copra to Suva (FJ$84/metric ton), and then on to Savusavu (on
Vanua Levu) for processing into oil will provide substantially increased benefit to local
producers.
151. The combination of Rotuma having the highest diesel fuel cost and the lowest
effective copra price in Fiji makes it the most likely site in Fiji to find the use of coconut
oil for power generation an economically sustainable endeavor.
d.
Next Steps
152. To obtain funding for the construction of the proposed power development, a
comprehensive feasibility study and engineering design study will be necessary. Since
there is considerable overlap in the skills needed for a feasibility study and for the
engineering designs, the REEP team has developed a project document for these as
one combined technical assistance (TA) project thereby reducing the total cost of project
preparation.
26
i.
153.
Scope of the Project
The proposed project has two major components:
1) It centralizes generation and connects all the island’s villages through an 11kV
grid eliminating the numerous mini-grids now in place and dramatically improving
the fuel efficiency for power production.
2) It develops the capacity to locally produce all the biofuel needed to power the
centralized electricity supply, including water pumping.
154. In effect the project completely replaces the patchwork electrification that is now
present and develops a local capacity to produce coconut oil based biofuel in sufficient
quantities to fuel the central generator.
ii.
Feasibility and Engineering Design Study Technical
Assistance project outline
155. The TA will address issues regarding public-private sector partnerships, land
acquisition, environmental impacts and social acceptability. The TA will identify suitable
financing schemes and develop a business plan for any private sector component to
ensure low/manageable project risks to ADB and/or other funding institutions as well as
the project recipients.
156. The assistance will be implemented in two stages: (i) formulation of a Rotuma
power development strategy and a least cost/benefit ratio option that will optimize
economic, social and poverty reduction impacts and (ii) development of a rural power
project suitable for financing by ADB or other external funding agency.
157. Phase 1 will: (i) include a review of relevant studies on rural power demand and
supply in Fiji in general and on Rotuma specifically; (ii) include the creation of a Steering
Committee within 4 weeks after commencement that includes representatives from key
stakeholders; (iii) in consultation with stakeholders formulate the least cost/benefit ratio
coconut oil fuelled power development scheme for Rotuma; (iv) undertake a detailed
socio-economic survey and environmental impact assessment (EIA) in accordance with
the requirements of local regulations, ADB safeguard policies and those of other
agencies to be approached for funding; (v) assess the coconut resource and the
economic and physical feasibility of accessing sufficient coconuts on a continuing basis
to provide fuel for the power system; (vi) assess existing institutional arrangements for
rural power delivery in Fiji and on Rotuma and develop a structure that is technically,
socially and economically optimized for the operation and maintenance of a coconut oil
fuelled centralized power system for Rotuma that draws on the strengths of both the
public and the private sectors; and (vii) assess and identify a financing scheme suitable
for the Rotuma Island Council, Fiji Government, ADB and other funding sources.
158. Based on the results of Phase 1, Phase 2 will include: (i) preparation of an
engineering design for the complete power system including generation, power
distribution and the facilities needed to produce coconut oil suitable for engine fuel using
whole coconuts as the raw material; (ii) preparation of a coconut purchasing plan
addressing the logistics of nut delivery to the processing site and the maintenance of an
acceptable price for whole coconuts over the long term; (iii) development of an
institutional structure that optimizes inputs from the public and the private sectors; (iv)
preparation of a business plan for any private partners; and (iv) preparation of
documents needed for project financing.
27
159. The TA is estimated to cost US$558,000 equivalent, with a foreign exchange
cost of US$313,000 and a local currency cost of US$245,000 equivalent.
160. The DOE would be the executing and implementing agency of the TA since this
project is classed as rural electrification. CIDA will provide technical support as
necessary. The Rotuma Island Council would support the TA in Rotuma. The Island
Council will arrange for overall support of the TA and help ensure adequate cooperation
from the Government and non-government organizations as well as villages in the
project area.
composed of a small diesel system power engineer, an economic and financial analyst,
a private sector/institutional specialist, a biofuels specialist with coconut oil experience,
an environmental and social assessment specialist and other short-term specialists as
identified during Project implementation (e.g., for design and specification of the coconut
processing component). Domestic consultants will be hired, equivalent to 4 personmonths, consisting of a community development expert and other short-term specialists
as identified during Project implementation (e.g., a local environmental specialist). TA
implementation will be assisted by a team of international and domestic consultants.
162. The TA will be implemented over a period of 8 months. About 5 months will be
required for Phase 1 and 3 months for Phase 2. The TA is expected to produce design
and analytical results that fully comply with all relevant ADB policies.
28
10.
Priority 3 Renewable Energy: Geothermal resource investigation
a.
163. FEA has stated that the development of renewable resources, including
geothermal, is its highest priority and tabled a request for the REEP to assist in
developing a TA project for a prefeasibility study of the Viti Levu resource with the
objective of determining whether or not it is reasonable to pursue further development of
geothermal to offset the growth of use of imported fossil fuels and slow the growth of
CO2 emissions by FEA’s diesel based generation.
164. In February 2005, the Steering Committee agreed that this request should be
included in REEP submissions but at a priority lower than that of Namosi Hydro and
Rotuma Coconut Oil project development.
165. The concept of the project is to determine whether or not the resource in Fiji can
be developed to warrant a full feasibility study that includes expensive deep well drilling.
The studies of the 70s and 80s were not conclusive and it is expected by the team that
the use of modern equipment and techniques will allow a clearer understanding of the
geological structures involved. FEA has estimated the cost of a full feasibility study at
over FJ$3 million making it worthwhile to carry out a relatively expensive prefeasibility
study to lower the risk of very expensive drilling operations.
b.
Project background
166. The presence of hot springs in Fiji has long created interest in development of
geothermal resources. In the late 1970s, the Department of Mineral Resources began a
series of studies of geothermal surface phenomena and determined that the Savusavu
and Labasa areas of Vanua Levu show strong indications of the presence of a relatively
shallow geothermal resource. The presence of hot springs and other evidence of shallow
geothermal resource in the Ba, Tavua and Soa areas of Viti Levu is also noted but those
areas have received much less study than the more obvious sites of Vanua Levu.
167. FEA’s preliminary desk study in 2004 suggests that a 20 MW facility at a site with
a good resource may need an investment of approximately FJ$105 million (US$61m)
equivalent to an electricity cost of FJ$0.074-FJ$0.109/kWh, with a base case price of
FJ$0.102/kWh. This is well below FEA’s current marginal cost of production and below
the current price at which it is willing to purchase power from new IPPs (around
FJ$0.135/kWh). FEA feels that a larger development on the order of 50 MW is
preferable and should the development be on Vanua Levu, a 50 MW development might
justify the cost of under sea transmission from Vanua Levu to Viti Levu.
168. Between 1978 and 1983, there were various geothermal investigations near
Labasa and Savusavu, the main towns of Fiji’s second island of Vanua Levu. These
were mainly preliminary geophysical and geochemical studies. Further geochemical
studies and a resistivity survey were carried out in Labasa in the early 1990s.
169. A 1996 report assessing the results of work in Fiji concluded that “geothermal
resources [on Viti Levu] have not been investigated because of the existence of
inexpensive hydropower. However, on … Vanua Levu, very little hydropower can be
found, but the hottest geothermal fields are located there. The highest assessed
subsurface temperatures occur on Vanua Levu (maybe 160oC), and there are industries
that could use process heat, whether or not the resources are suitable for electrical
power generation. A 1994 consultants' report reviewed the information available in the
29
areas of Savusavu and Labasa … and recommended a deep drilling program to allow
measurement of reservoir conditions down to 800 meters. Slimhole technology is the
preferred method with three holes to be drilled on each area at an estimated cost of
approximately US$2.5 million.”
170. FEA wishes to include Viti Levu in any new assessment of geothermal potential
because: (i) the bulk of Fiji’s demand is on that island; and (ii) the only remaining large
undeveloped hydro resource, the Ba/Sigatoka scheme (~50 MW; ~100 GWh; ~FJ$125m
incl. transmission) is expected to be developed within a few years, leaving no large,
reasonable-cost hydro options for the future.
c.
Next Steps
171. In early 2004, FEA issued a ‘Request for Proposal’ for geothermal assessments.
Based on information contained in the submissions from five companies (PB Power (NZ)
Ltd, Sinclair Knight Merz (SKM) Ltd, Worley Pty Ltd, Century Drilling & Energy Services
(NZ) Ltd and Pacific Island Power) FEA estimated that a prefeasibility study (in 2004 Fiji
dollars) would cost about FJ$950,000. The Terms of Reference included a study of Ba,
Tavua, Rabulu, Busa, Sabeto sites on Viti Levu and the Labasa area on Viti Levu. The
work included desk studies of existing information, carrying out further geochemical and
geophysical tests and ranking their technical and economic potential. FEA did not
include Savusavu in the proposal because the Fiji Government had previously granted
Natural Power Ltd., (NPL), a subsidiary of Asia Pacific Resources, Ltd., a special
prospecting license for geothermal exploration in the Savusavu area. NPL proposed that
they would do exploratory drilling at an estimated cost of FJ$2 million (US$1.2 m) should
a mine at Wainivesi be developed. Approval for mine development has not yet been
provided.
172. The REEP project follows generally the same approach as the FEA tender in that
both Viti Levu and Labasa are included in the survey and the emphasis is on
consolidating and interpreting existing data and adding new measurements where gaps
exist. Savusavu exploration may no longer be exclusive to NPL by the time this study is
mounted, so if that is the case Savusavu should be included. Only the Initial
Investigation is included under this TA project.
i.
•
•
•
Initial investigation component (6 months)
Viti Levu. Review existing studies (including hydrological and petroleum studies,
hold discussions with MRD, SOPAC etc.) to determine prospective sites. Carry out
preliminary geological, geochemical and hydrogeological studies at sites that
warrant further study. Rank the sites based on likely technical and economic
geothermal potential. Recommend further assessment at sites with favorable
characteristics and specify the studies most appropriate considering the cost of the
studies and the likelihood of finding a commercially viable resource.
Vanua Levu. Determine the appropriateness of including both Labasa and
Savusavu in geothermal investigations. Re-interpret the earlier Labasa (or, if
appropriate Labasa and Savusavu) studies of the past 30 years using up-to-date
analytical methods. Assess the need, if any, for further geological, geochemical,
hydrogeological and geophysical studies and specify the studies most appropriate
considering their cost and the likelihood of their use locating a commercially viable
resource for electric power development.
General. Advise on the desirability, cost, risks and anticipated results of further
exploratory geothermal study in Fiji. To the extent practical, advise on the magnitude
30
of the resource, or resources in Fiji that are possibly suitable for power development.
Develop the TOR for a possible phase 2. Advise on whether a Vanua Levu resource
appears to be sufficiently large to consider power transmission to Viti Levu, and if so,
determine the approximate costs.
173.
Phase
1
2
It is proposed that the prefeasibility study proceed in several stages as follows:
Activities
Initial investigations. Review existing documentation for Vanua Levu & Viti
Levu. Rank sites for further study. Prelim. geological, geochemical &
hydrogeological studies on Viti Levu. Refine phase 2 costs & develop TOR.
Prefeasibility including further geochemical and physical studies.
Geochemical and geophysical studies, Viti Levu. Possibly supplementary
geochemical / geophysical studies, Vanua Levu. General prefeasibility study.
US$
~ 150,000
~ 390,000
174. If the results are favorable at the conclusion of Phase 2, FEA would request
funding for a full feasibility study, including exploration drilling on both Viti Levu and
Vanua Levu, at an approximate cost of US$5.7 million (FJ$10 m).
31
B.
Samoa
1.
Steering Committee
175. After Samoa was selected as one of the two countries to take part in REEP, a
Steering Committee was formed in order to ensure that stakeholders had representation
in the project determination and project prioritization process. Six Steering Committee
meetings were held in Samoa and all proposed projects were reviewed by the
Committee. The projects developed by the REEP team have been approved and
prioritized by the Steering Committee. The Steering Committee members include:
Name
Papalii Tommy Scanlan
Muaausa Joseph Walter
Sector
Ministry/Ministry
Governor, CEO
SC Chairman
CEO Electricity Utility
SC Deputy Chairman
Papalii Grant Percival
Commerce & Industry
Tuuu Ieti Taulealo
Environment
Mosese Vitolio Tui
Sili’a Kilepoa Ualesi
Thomas Jensen
Steven Rogers
Bola Nacanieli
Fiu Mataese
Fuimaono Falefa Lima
Atanoa Crichton
Technical Training
Government Energy
Sustainable Energy
Donor community
Petroleum
NGO and community
Finance
Media
Central Bank of Samoa
Electric Power Corporation
Samoa Association of Manufacturers and
Exporters
Ministry of Natural Resources &
Environment
Principal, Don Bosco Technical School
Energy officer, Ministry of Finance
UNDP Samoa/UNESCO Apia
European Union, Apia
Private
Le Siosiomaga Society
Development Bank of Samoa
Samoa Broadcasting Corporation
176. Mr. Fiu Mataese formally resigned from the Committee and was not replaced.
Other persons were invited to participate when items of special interest to them were on
the agenda of the Committee.
2.
177. The regional PIEPSAP project is handling energy policy development and
regulatory issues that the REEP initially was expected to cover. The REEP team has
discussed policy issues, particularly as regards utility regulation and the appropriate
components for a national energy policy for renewable energy and energy efficiency,
with the Ministry of Finance (MOF) and PIEPSAP and did not separately address these
issues. The Team indicated to the Samoa Energy Officers and senior MOF staff that the
REEP team was available for further support of policy efforts if Samoa desires additional
input either in the form of additional policy advice or in the form of a review of the
proposed policies developed under PIEPSAP. No assistance was requested and the
REEP team took no further action. A Samoa national energy policy has been developed
with the assistance of PIEPSAP and is now in the review stage.
3.
178.
Three primary areas of institutional development have been the REEP focus:
• Development of institutional structures to encourage the development of private
Energy Efficiency Service Companies (EESCOs).
• An action plan for development of institutional structures to oversee, regulate and
promote energy efficiency activities.
32
• Working with businesses for the development of a Renewable Energy Business
Association.
a.
Development of private EESCOs
179. Past energy efficiency efforts have typically been limited to energy audits
performed by EPC with audit recipients expected to proceed with the implementation of
the recommendations provided by the auditor. This has not generally resulted in long
term improvements in the efficiency of energy use. For energy efficiency measures to be
properly carried out and savings maintained for the long term, there needs to be an
institutional structure that not only provides energy audits but also supports carrying out
the energy saving activities, continues to monitor their effectiveness and makes
adjustments where appropriate. The structure that is proposed for Samoa is to develop
mechanisms that support energy efficiency service company activities as a component
of existing technical companies and the EESCO approach proposed for Fiji is followed.
However, the demand for EESCO services in Samoa is not considered sufficient to
support a business only providing EESCO operations, so in Samoa the expectation is
that technical companies may include a component for EESCO type activities but may
not need to specialize in energy efficiency services. Specific needs for institutional
development to support this activity include:
• Developing the structures necessary to provide specialist training to individuals
and companies wishing to act as EESCOs
• Developing the structures in government necessary to regulate EESCOs
• Establishing the methodology and criteria for an independent agency (expected to
be EPC) to determine the savings effect of equipment that has been installed to
improve energy efficiency
• Creating a process allowing clients to borrow money for the finance of energy
efficiency improvements at a periodic cost equal to or lower than the periodic
savings brought about by the installed energy efficiency equipment
• Developing structures that provide performance guarantees to clients to increase
their confidence that the services would indeed provide the expected savings.
• Developing methodology and criteria for monitoring the program on a national
level.
180. These structures would be developed under the regional (Samoa and Fiji) project
prepared by the REEP for the development and support of EESCOs.
b.
Regulatory and RET promotion framework development
i.
Appliance labeling
181. Team members have discussed the use of standards and the use of
standardized appliance labels to inform consumers of the relative energy efficiency (and
therefore cost of operation) of appliances sold in Samoa. Discussions have been held
with importers, retailers, and the Government. Specific problems that Samoa must
overcome for energy efficiency labeling of appliances to be effective include:
33
• Lack of testing facility. It is impractical for Samoa to establish its own testing
facility for appliances and it must therefore depend on external testing for labeling
of appliances;
• Imported appliances have diverse testing and labeling schemes. Though
most of the countries that supply appliances for Samoa import have labeling
schemes in place, they do not all use the same procedures for test and the labels
are not consistent in the way efficiency information is presented;
• Consumers unfamiliar with energy efficiency issues. Consumers are generally
not aware of the considerable difference in cost of operation of appliances seen in
different models of the same appliance and are not familiar with energy efficiency
labeling systems. Retailers are not encouraged to provide that information even
when appliances have been rated by the exporting country as is the case with
many appliances coming from the US, Japan, New Zealand and Australia.
182. As shown in Appendix 3, the REEP team has proposed an action plan for
Government for the development of energy efficiency based appliance labeling and its
implementation. To implement the plan an institutional structure specializing in energy
efficiency development and implementation should be in place. To date, no institutional
structures have been formed by the Government that focuses on regulating the energy
efficiency of imported equipment or on the development of efficiency standards, labels or
certifications. Thus, the Steering Committee agreed to propose and seek approval from
Government for the establishment of a multi-sectoral committee to commence the
process of energy efficiency standards and certification development. A formal request
was sent to Government in March 2005 by the Governor of the Central Bank (also the
Chairman of the REEP Steering Committee). The request is currently being considered
by Government.
183. Since establishing an entirely new governmental structure is a matter of years,
not months, the REEP cannot do more than get the process started. Should the regional
EESCO project that is being proposed be implemented, that will help continue the
momentum for the development of energy efficiency structures that are being supported
by the REEP.
184. The proposed regional EESCO project includes the development of institutional
structures for the regulation and support of EESCOs including finance, a performance
guarantee fund management structure and a structure for the independent auditing of
EESCO energy efficiency implementations (see Section IV of this report).
ii.
Renewable Energy Standards Development
185. Unlike Fiji, there is almost no opportunity for
photovoltaics as a rural electrification technology and the
allow grid connected solar PV to become a large scale
Therefore, the development of standards and other
implementing solar PV are not needed in Samoa.
the development of solar
economic climate does not
power source at this time.
regulatory processes for
186. Under the project for the development of coconut oil for EPC generation,
standards for fuel quality, its storage and its transport will need to be applied. Those
standards can be imported from other countries without modification so no
developmental process is needed. As EPC will be the only user of the fuel, the
responsibility for those standards will be best maintained at EPC, not Government. The
34
specific process that should be followed will be identified during the feasibility study for
the project.
187. The lack of national standards for solar heaters does not appear to be a barrier to
their use since there is no local manufacture of solar water heaters. The imported units
are all from New Zealand and Australia where adequate standards and certification
systems are applied. Thus the cost of developing and the bureaucracy for implementing
such standards for what is still a small market does not appear to be justified. Should a
local manufacturer of solar water heaters commence operations or should the domestic
market for solar water heaters dramatically increase, it is recommended that the
Australian standards and certification system be applied.
iii.
Action plan for promotion of RET and EET
188. The EESCO project being developed by REEP for both Fiji and Samoa includes
the necessary institutional structures for its implementation and technology promotion.
189. The primary area that has been requested by the Steering Committee for
institutional development is the development of an action plan for the implementation of
energy efficiency labeling of household appliances, particularly refrigerators and freezers
which appear to be the largest users of electricity in the domestic sector.
c. Development of a renewable energy association
190. Currently, there are no businesses in Samoa specializing in renewable energy
equipment or services. The only renewable energy components being sold by Samoa
businesses are solar water heaters. They are “off-the-shelf” commercial items imported
from Australia and New Zealand and their sale represents only a small part of the
businesses selling the units.
191. Though the team could find no interest in forming a separate renewable energy
association in Samoa, both the Samoa Association of Engineers and the Samoa
Manufacturer’s Association have indicated that if in the future there is sufficient interest
by individuals or businesses to establish an energy sub-section within either of those
associations, both associations would be willing to provide an organizational umbrella.
4.
a.
Renewable Energy
192. The team has interviewed the management of all the commercial banks and the
Samoa Development Bank. Though a few solar water heaters have been financed
through the banks, there is essentially no activity by any financial institutions in Samoa
related to renewable energy or energy efficiency. Mainly it appears that is because there
has been no demand for such finance.
193. Since nearly all households are electrified, there is no justification for rural microfinance for renewable energy. Such renewable energy applications as exist, primarily
solar water heating for hotels and businesses, can be financed by existing commercial
banks or by larger businesses that have ready access to commercial and, in some
cases, low cost international finance for economically justifiable investments.
194. The commercial market for the finance of renewable energy projects that cannot
be financed through existing channels is very small and development of special financial
schemes for those projects does not appear to be justified.
35
b.
Energy Efficiency
195. Unlike renewable energy, there are many opportunities for investment in energy
efficiency improvements both at the domestic and at the commercial level. There is little
experience with financing energy efficiency improvements in Samoa. Interviews with
commercial finance providers indicate that they have little knowledge regarding the risks
associated with energy efficiency investments.
196. At the household level, the largest improvement in energy efficiency is from
replacement of incandescent lamps with more efficient compact fluorescent lights (CFL).
The primary barrier to the adoption of the high efficiency CFL bulbs is not the specific
cost of the CFLs as they are well within the budget of the majority of Samoan
households. The barrier is that the CFLs are typically several times the cost of the
cheapest incandescent bulb and that there are higher priority uses for the immediate
cash that can be saved by choosing low cost bulbs and prefers it than long-term energy
cost savings from purchasing the expensive but high efficiency bulbs.
197. The problem of energy efficiency at the household level is technically not one
that relates to the availability of finance, it is more a lack of confidence that the extra
expense will be returned in savings. Persons interviewed feel that it would be risky to
buy them since there is no assurance that they will last long enough to pay the initial
investment in energy cost savings. Also, high efficiency bulbs are not available in
neighborhood shops, only large retail stores in Apia. There is little incentive to make the
special effort to find and purchase the high efficiency units for savings that can amount
only to a dollar or two a month for most households. However special financing
programs can be developed that provide high efficiency lighting through EPC with
repayment for the more expensive CFL through a charge to the customer lower than the
savings that has accrued from the replacement incandescent bulbs. In essence such
programs are actually more to change the perception of customers than to overcome
true financial barriers.
198. The team has discussed this concept with the Energy Unit and EPC, and offered
to prepare a concept paper but no request was made since EPC claims to be familiar
with the concept. A program of this type can be done by the Government or EPC and is
not expected to require external funding.
5.
Capacity building
199. Of the four main educational institutions outside of primary and secondary
schools (Table 8), the USP facility concentrates on agriculture and the National
University of Samoa provides tertiary degrees in academic areas that do not include
technical content relating to renewable energy and energy efficiency. The REEP team is
concentrating on cooperation with the Samoa Polytechnic (combined institutionally with
the National University of Samoa (NUS) in 2006 as the Institute of Technology under the
University) and the Don Bosco Technical Centre since both have interests in increasing
their existing renewable energy and energy efficiency course content. The merging of
the NUS and Samoa Polytechnic is not expected to affect the proposed capacity building
activities with Samoa Polytechnic nor its usefulness in the future when implemented.
36
Table 8 – Post-Secondary Education and Vo-Tech Training institutions in Samoa
Institution
University of the South
Pacific School of
Agriculture
National University of
Samoa
Primary Function
Comments
Post secondary degree education with the Samoa
campus focusing on agriculture (primary campus
in Suva, Fiji)
Post secondary degree general education. In the
process of merging with Samoa Polytechnic
Not presently providing courses relating to
energy. No program that could be quickly
developed for RE and EE training
No engineering program or other program
that could be quickly developed for RE
and EE training
Some RE and EE content in existing
courses for electrical trades and plumbing
Post-Secondary Vocational-Trades school with
programs that include electrical and plumbing
trades. Now merging with the University of
Samoa
Private Secondary school level Vocational-Trades
school with programs that include plumbing
trades but not electrical trades.
Samoa Polytechnic
Don Bosco Technical
Centre
a.
Solar water heater installation included in
the plumbing program
Training for renewable energy technicians
200. The team has visited the two technical institutes in Samoa, Don Bosco Technical
Institute (private) and Samoa Polytechnic (Government), and discussed the REEP
program and how the program could work with them in developing course materials
needed to support renewable energy and energy efficiency programs.
201. Don Bosco Tech presently does not have a program for electrical trades, though
it does have a plumbing trades program that includes the basics of solar water heater
installation. The Principal is a member of the REEP Steering Committee and has direct
access to information about the program.
202. Samoa Polytechnic has a full vocational trades program including electrical and
plumbing trades training. The facilities are being upgraded through Japanese funding
and are expected to be among the best in the region when completed. The plumbing
program already includes considerable student work with solar water heating (courses
PL201 and PL211). An evaluation of the program was made by the team and no further
curriculum development support appears to be needed in that area at this time. Should
there be a major increase in the market for solar water heaters in Samoa, as could be
the case if incentives for household use of solar waters were provided by government, a
future expansion of the solar water heater course content could be warranted.
203. As there are almost no solar photovoltaics used in Samoa presently and little
expectation of solar photovoltaics being used significantly in the foreseeable future,
there is little interest in adding a full module on solar PV to an already crowded electrical
trades program at Samoa Polytechnic. However there is interest by the head of the
Electrical Division regarding solar PV technology. As a result the head of the electrical
trades section was invited to participate in the REEP sponsored renewable energy and
energy efficiency workshop held in Fiji and was provided with the PV curriculum
materials used at FIT.
204. For the trade schools to gain experience with renewable energy, the REEP team
leader has proposed to UNDP and EPC that selected Don Bosco School building trades
instructors and students and selected Samoa Polytechnic electrical trades instructors
and students participate in the construction of the 10kW solar PV system that is to be
constructed for Apolima (a small island with 9 households that is located between Upolu
and Savai’i) in 2006. UNDP and EPC have responded positively to the proposal and will
work with the two training institutions during the implementation of the Apolima project.
37
b.
Energy Efficiency training
205. There is interest at Samoa Polytechnic to expand the contents of the energy
efficiency course materials for the electrical trades program when Government begins to
actively promote energy efficiency measures sometime in the future. The sub-regional
program for EESCO development that is proposed elsewhere in this report (Section IV)
includes a training component that will include Samoa Polytechnic as one of the training
facilities to be developed for ongoing energy efficiency training courses. For Samoa, the
number of persons likely to require specialist energy efficiency training is not expected to
be large enough to warrant a specialist course as is proposed for Fiji. Components
focusing on basic training in energy auditing and methods of increasing the efficiency of
energy use will, however, be relevant.
206. REEP cooperated with SOPAC regarding their demand side management (DSM)
training in Samoa in July, 2005 through the selection of additional participants and a
review of the program.
c.
Other renewable energy capacity building programs for the
Pacific that will affect Samoa
207. In 2004, ESCAP funded a review of training facilities in the Pacific and of the
needs for renewable energy training in the PICs. As a part of their program, ESCAP
included the development of a concept for a renewable energy capacity building regional
program that was approved during the 2004 Regional Energy Meeting and later by the
CROP. The concept included a budget of around US$3 million for a five year program
that could cover all the PICs including Fiji and Samoa. A complete project document
based on that concept paper was prepared and submitted to donors in late 2005. No
funding is yet allocated.
208. PIREP also included identification of renewable energy capacity building
requirements as part of their survey of the PICs in 2003 and 2004. The results were
used in the development of the PIGGAREP project proposal that is in the GEF pipeline.
Capacity building is a major component of the proposal and will include Samoa and Fiji
though implementation is not likely to begin before 2007.
209. It is noted that at present neither program includes development of energy
efficiency technology training. The Team considers the development of a training
component within the proposed sub-regional EESCO development project as vital to its
long term success and to the further development of energy efficiency measures in Fiji
and Samoa. However, energy efficiency training in Samoa has too limited a clientele to
permit the training institutions to develop specific programs concentrating on energy
efficiency, though if the sub-regional EESCO development project is carried out, limited
short course development for Samoa should be included. For the foreseeable future, it
will be more cost effective for Samoa to send trainees to facilities outside Samoa for any
long term training specializing in energy efficiency technology.
d.
REEP activities for capacity building
210. Because of the very limited time and financial resources available to the REEP,
the capacity building strategy has been to work on training development only in areas
where there is an immediate need for support. In Samoa the technical needs for RE
technology support is mainly for installation and maintenance of solar water heaters and
that appears to be adequately covered in the existing training programs considering the
small market for those skills in Samoa.
38
6.
Dissemination of activities in Samoa
211. REEP team members have provided formal presentations disseminating
information about REEP activities in Samoa at:
•
a meeting of the Samoa Chamber of Commerce and Industry (2005) where a
team member explained the activities under the REEP and how they can support
private business in Samoa;
• a meeting of the Samoa Engineering Association encouraging participation in
developing the EESCO concept in Samoa and outlining the technical programs
under the REEP (2005).
• Steering Committee meetings
• A UNDP project planning meeting held in Apia 5-7 September, 2005.
212.
Team members have had continuing non-government consultations with:
• IIEC in Bangkok regarding EESCO formation, the history of the current EE project
in Samoa and to obtain other supporting information and to get IIEC opinion
regarding the sub-regional EESCO project being proposed by the REEP;
• SOPAC regarding their activities in Samoa, in particular as relates to EE and
biofuels, and discussions about where the REEP could cooperate and coordinate
programs with SOPAC;
• PIEPSAP concerning their activities in Samoa in supporting the development of a
national energy policy;
• The EU office in Apia regarding their activities in Samoa and how the REEP can
cooperate and complement their work.
7.
Project development
213. A major goal of the REEP is to prepare at least one project proposal for
renewable energy and one project proposal for energy efficiency that has strong support
by stakeholders and which can serve as a replicable model for further development. In
Samoa, the EPC and the MOF are the primary implementers of renewable energy and
energy efficiency programs and any project development by the REEP had to be
appropriate to their capacity and needs.
214. In Samoa, there were several months of delay in the progress of the REEP due
to the need to change the top priority project design from biomass gasification
technology to biofuel. This was because the team determined late in 2004 that the
gasification technology being proposed was not fully commercialized and also that the
cost of electricity using that technology would likely be substantially higher than that of
existing diesel generation or power development using biofuel.
215. Projects developed and proposed below have all been approved and prioritized
by the Steering Committee.
39
8.
Priority 1 - Renewable Energy: EPC generation using biofuel and
biomass
a.
216. The concept of the project is to provide new power generating capacity using
locally produced biofuel derived from coconuts to reduce poverty and accelerate rural
development. The objectives are: (i) provide 3MW of new capacity for EPC and (ii)
replace imported diesel fuel with biofuel to provide increased energy production without
a corresponding increase in greenhouse gas production.
b.
Project background
217. As with most of the more developed PICs, the coconut industry in Samoa has
been in trouble for many years for a number of reasons but mainly because the
expected hourly income for rural workers has risen above the world market price of
copra making its production less attractive to farmers. The Government of Samoa has
placed the rehabilitation of the coconut industry as a priority activity to make better use
of the existing massive investment in coconut trees and to increase the income
generation possibilities of rural Samoans. The concept of using coconut oil as a
replacement for diesel fuel has been considered for several decades, and was actually
used for a short time in the 1980s by EPC during periods of diesel fuel shortages and
high prices, but in general the cost of production of a liter of coconut oil suitable for
engine use has, until recently, been significantly higher than the cost of imported diesel
fuel. The petroleum product price hikes in 2004 and 2005 have now made it possible for
coconut oil to be directly competitive with imported diesel fuel provided a high efficiency
process is used for oil production.
218. Clearly the two key issues for successful use of coconut oil by EPC as a diesel
substitute are (i) that there has to be a confirmed and reliable supply of coconut oil of an
acceptable quality and (ii) that the biofuel price is acceptable when compared with
imported diesel fuel. Therefore the project design must address these issues for the
results to be applicable.
219. Discussions with Ministry of Agriculture personnel working toward coconut
industry rehabilitation indicate that the low utilization of the coconut resource has several
reasons. Important ones are:
• The work of extracting coconut meat and drying it into copra is boring, low skill
labor and the amount of money that can be offered for preparing copra provides an
hourly wage few persons in Samoa are willing to accept.
• Payment for copra is not made upon delivery and copra providers often have a
long wait to get their money.
• A significant portion of the coconut resource in Samoa has reached an age where
productivity is falling. The cost of replacement of these senile trees is not viewed
as profitable for copra producers under present market conditions.
220. For biofuel use, another issue is quality control of the end product whether the
coconut oil is to be used directly as a diesel replacement, blended with diesel fuel or
esterified. The quality of the oil is directly affected by the processes of drying the coconut
meat and storage of the resulting copra. Individual small scale producers have not
provided consistent copra quality because of poor control of the drying process and poor
40
storage methods. As a result it has proven difficult for the Samoa oil mill (now closed) to
maintain a consistent oil quality.
221. A major concern of EPC is the long term price of the coconut oil and the reliability
of the supply of coconuts. In particular there is a concern that once EPC becomes a
major coconut buyer, local producers will raise the price of nuts both due to market
pressures brought about by the dramatically increased market provided by EPC and due
to the perception that EPC has “deep pockets” and once it has made a major investment
in coconut oil based generation, EPC will have to pay whatever farmers ask.
222. Reliability of supply is an issue related to competition for the resource – in
particular, the desiccated coconut production facility is hoped to expand demand rapidly
as overseas markets are developed – and to loss of coconut production for months due
to damage to coconut trees by tropical cyclones.
i.
Sizing
223. The peak power to be available from the generation facility is to be at least 3 MW
upon completion. This capacity is consistent with the forecast requirements and the
location of the power plant. Using the assumptions in Table 9, the facility will require
around 900,000 coconuts a week (47,000,000 nuts a year) if the fuel is made 100%
from coconut oil and is not to be a blend of coconut oil and diesel fuel.
Table 9 – Operational Characteristic Assumptions
Value
3.8
3.0
70%
2.1
18,000
4,800,000
10
Units
Characteristic
kWh/liter
MW
Percent
MW
MWhr/year
Liters/year
Whole nuts
ii.
Generator Efficiency
Peak capacity
Average load percentage
Average power level
Annual Production – constant average load
Annual fuel requirement
For 1 liter of coconut oil
Coconut supply
224.
To address the supply issues, it is proposed that the EPC purchase whole nuts,
paying on delivery, and control the entire process of extraction of coconut meat, drying it
into copra and pressing the copra into oil. This is expected to make the labor more
acceptable since only collection of whole nuts would be required, not the considerable
work involved with producing copra. Further, quality control of the oil production process
would be much easier since the entire process would be under EPC direct control. With
the large volume of nuts to be processed, mechanization of the copra preparation
process is possible which will improve the possibilities for quality control and further
reduce the labor intensive components of oil production.
225.
The main disadvantage of using whole nuts by EPC is the problem of transport.
Whole nuts are much bulkier than copra and transport logistics will be a major issue
when over 100,000 nuts must be processed each day. The project will propose to site
the EPC facility within the Government owned Samoa Trust Estates Corporation (STEC)
coconut plantation and for STEC to provide all coconuts needed under long term
contract. That will make transport of coconuts to the processing facility less than 1 km
without using public roads making it practical to use specialized transport equipment that
41
cannot be operated on public roads (e.g. trailer trains). For shorter distances very
energy efficient conveyors can be used for moving the coconuts to the processing site.
Also locating the power plant within the plantation will provide a permanent sound and
visual buffer zone around the plant that cannot be developed for residences or tourist
facilities.
226. The STEC coconut plantation, located adjacent to the International Airport and to
the new Aggie Grey’s Resort, has approximately 7,000 ha of land area of which less
than 2,000 is currently being even minimally harvested. Using the theoretical production
assumptions used to prepare Table 10, the STEC facility has a maximum production
capacity of nearly three times the production needed to meet the 3MW project goal
though in practice the actual production is unlikely to ever be more than half the
theoretical maximum unless a major replanting program is undertaken. The 45 nuts per
tree per year production estimates are based on Samoa Tall type trees, some hybrid
varieties can produce more than 150 nuts per
Table 10 - Theoretical Production by
year though with a lower yield of oil per nut.
STECA
227. The current low production at STEC, less
Quantity
Units
than 5,000,000 nuts a year, is due to a weak
7,000 Ha available
market for copra that has allowed only a fraction
80% % useable for trees
of the plantation, around 2000 ha, to remain in
5,600
Total ha for trees
production. STEC management estimates that
520 Trees/ha
with no investment in renovation, the facility
2,912,000
Total trees
could deliver only around 15,000,000 nuts a
45 nuts per tree/yr
year, sufficient to cover about a third of the
needs of the proposed EPC plant. Much of the
131,040,000 Total nuts/yr
problem is that heavy ground cover has grown
over most of the plantation and that means missing many coconuts during the walk
through for picking up nuts. In those parts of the plantation not currently active,
uncontrolled vegetation growth has reached almost jungle conditions. Also replanting
has not been carried out in much of the plantation so there is a significant percentage of
trees that are senile or approaching senility. Major rehabilitation of the STEC facility,
particularly clearing of ground cover, “volunteer” trees and heavy underbrush, will be
necessary to meet production requirements for EPC generation. Planned replanting will
also be necessary for reliable long term production. Therefore the project will need to
include loan funding to Samoa for STEC rehabilitation concentrating initially on the areas
where replanting is not yet needed since that will allow an immediate increase in
production. Roughly 3,000 ha of fully productive plantation populated by Samoa Tall
trees would be the minimum needed to reliably provide sufficient fuel for the full 3 MW of
capacity desired.
228. Because it will take several years to bring the STEC capacity to that needed to
fully supply the required number of coconuts, it is anticipated that the power plant will
initially operated with a blend of coconut oil and diesel fuel with the percentage of the
blend being coconut oil increasing as STEC productivity increases. By the end of three
years of operation, the facility should be running on 100% coconut oil. By using a
modular design for the coconut processing components, investment in coconut
processing equipment can be staged to coincide with increased production needs.
iii.
Waste processing
229. The bulk of the coconut consists of husk and shell. With nearly a million nuts per
week being processed, waste material will be generated on the order of 1,000 metric
tons per week. The large volume of waste makes it practical to burn the husk and shell
42
residue in an efficient boiler and to dry the coconut meat under controlled heat
conditions using heat from a combination of exhaust heat from the burner, exhaust heat
from the diesel engines and steam heat from the boiler. Initial indications are that there
will be a substantial heat surplus that can be used for further power production using a
steam turbine in the order of 500 kW or more at full production.
230. For years to come, the rehabilitation of the STEC plantation will yield large
quantities of biomass in the form of senile trees, underbrush and other trees that have
grown to maturity in the plantation area. That biomass can be added to the processing
waste to provide additional biomass for combustion and steam generation. Estimates of
the volume of this secondary biomass source and its heat content are not available but
indications are that at least another continuous 500 kW of capacity can be provided from
this source for sufficient time to make it economically reasonable to increase the
electrical generation capacity to one megawatt or more. This option should also be
considered in the final project design.
231. It is noted that coconut shells are an excellent source of activated charcoal for
the purification of water and air, coconut husks can be converted into geotextiles
(biodegradable mats to limit erosion of soil in new construction areas until ground cover
vegetation is mature) or other woven products or ground into mulch. Portions of senile
coconut trees can be used for lumber that can be used for construction or high quality
furniture production. These uses of by-products of the copra producing process should
be investigated as alternate economic inputs to EPC/STEC during the feasibility study.
232. The material that remains after pressing oil from copra has a ready market as
animal feed and its sale can also help offset the cost of oil production. Whether the
Samoa market can absorb the quantity that will be produced has yet to be fully
evaluated, however.
iv.
Type of fuel
233. Three types of fuel could be produced under this project, (1) coconut oil filtered
and lightly processed; (2) coconut oil blended with diesel fuel; and (3) coconut oil
chemically modified as a methyl or ethyl ester which closely emulates the characteristics
of diesel fuel.
234. Any of the three types of fuel could be produced under this project concept, (1)
coconut oil filtered and lightly processed; (2) coconut oil blended with diesel fuel; and (3)
coconut oil chemically modified as a methyl or ethyl ester which closely emulates the
characteristics of diesel fuel. Each type of coconut oil based fuel has advantages and
disadvantages that will need to be weighed in the feasibility study before a final decision
is made regarding the fuel production process that is finally used.
235. Sustainability and flexibility are both requirements for long term success.
Sustainability depends largely on the ability of EPC to manage the interlocking
processes of obtaining sufficient nuts, processing the nuts into oil, managing the waste
products and maintaining all the equipment. Flexibility is required because the project is
moving into operational areas not yet tried in the Pacific and it is likely that improved
efficiency of operation will be possible through operational changes after sufficient
experience is gained in project operation.
236. In general, the simpler the overall process, the more likely it is that maintenance
can be handled in a developing country context and the easier it will be to make changes
to the process to take advantage of operating experience for efficiency improvements.
Therefore emphasis on project design should be for maximum simplicity, minimal
43
dependence on high technology and be of modular construction to provide physical and
management flexibility.
237. Another characteristic of the project that is important is expandability and
replicability. If the project is successful and coconut production rises due to increased
interest by farmers in rehabilitating plantations, expanding the facility would be
reasonable. Being able to replicate the project in other countries of the Pacific will also
be an important project characteristic under the REEP.
v.
Possible equipment suppliers
238. Although coconut oil has long been known to be practical as a replacement for
diesel fuel, manufacturers of engines have only recently begun to offer fully warranted
engines intended for the use of 100% coconut oil as a fuel. The REEP team located two
manufacturers who indicated that they could provide the necessary 3MW of generation
capacity with engines that would be fully warranted for coconut oil fuel. Suppliers of
other components needed for the facility were also located. Table 11 lists those
suppliers.
Table 11 – Suppliers of equipment for use in the 3MW coconut oil fuelled power development
project
Coconut Oil Fuelled Engine Manufacturers
Company
Address
ENERGIE RELAIS
WARTSILA
Company
DE
ROSEDOWNS
SMET
MECANIQUE
MODERNE
Company
ETP
Contact person
Rue Denis Papin
Mr. J. Bigot
Parc industriel
28639 Gellainville
France
Les collines de l’arche
Mr. A. Gouet
Immeuble Opera E
92057 PARIS La Defense
cedex
FRANCE
Coconut oil expelling equipment
Address
Contact person
Cannon Street
E. Yorkshire HU2OAD
UK
Mr. Barker
ZAC Artoipole
BP 42015
62060 ARRAS cedex 09
France
Mr. J.P.Vasseur
Contact information
Ph:33.2.37.30.70.30
Fax:33.2.37.30.00.39
[email protected]
Ph:33.1.47.76.89.37
Fax:33.1.47.76.89.21
[email protected]
Contact information
Tel: 44.1482.329864
Fax: 44.1382.325887
[email protected]
om
Tel:33.3.21.55.36.00
Fax:33.3.21.24.04.34
Filtration and Conditioning Units for Coconut Oil use as
Address
Contact person
Centre d’innovation
Mr. P. Bourgeois
14-16 rue Léonard de Vinci
45074 ORLEANS cedex 2
France
Company
METHOD
MACHINE
WORKS
Fuel
Contact information
Tel: 33.4.99.62.00.96
Fax: 33.4.99.62.00.97
Coconut Dehusking and Deshelling Machines
Address
Contact person
Contact information
Level 26, Menara IMC
N/A
Tel: 60.3.2039.4763
NO. 8 JALAN SULTAN
Fax: 60.3.2031.8359
ISMAIL
Email:
Kuala Lumpur 50250
[email protected]
Malaysia
m
44
vi.
Private Investment possibilities
239. The possibility of local private sector investment in all or part of the coconut oil
fuelled power development project, possibly combined with ADB equity was proposed.
The lack of prior experience by EPC, the relatively large size of the investment relative to
Samoa’s private investment capacity, the availability of higher return investments in the
rapidly expanding tourism industry, and the lack of experience with private power
development in Samoa all combine to make it unlikely that the power plant can be
privately financed. However, the coconut processing component may be possible for
private investment. EPC has already agreed to having a private contractor operate the
coconut processing facility under EPC oversight and the level of investment for the
processing facility is probably within the capacity of local investors, particularly if ADB
equity investment funds are included. Additionally there is considerable local experience
with coconut processing industries. This possibility should be further developed by the
feasibility study. The investment would probably not be large and secure enough or
provide a high enough rate of return to attract foreign investors, however.
c.
Project preparation
240. Due to the overlapping of a number of activities and technical requirements and
the fact that both projects are under EPC, the proposed feasibility study for the EPC
Biofueled Power Development Feasibility and Design study is proposed to be combined
with the Upolu Hydro Development Prefeasibility/Feasibility Study into one Technical
Assistance Project.
241. The study will be carried out in two phases. Phase 1 will: (i) include a review of
relevant studies on power supply and demand on Upolu and of the state of the coconut
industry and the coconut resource with special focus on STEC; (ii) in consultation with
stakeholders create a conceptual design for the least cost/benefit ratio 3 MW coconut oil
fuelled base load power development scheme for Upolu that includes sufficient whole
coconut processing capacity to provide 100% of the fuel needs for the power plant and
sufficient fuel storage to avoid shortages due to adverse weather slowing fuel
production; (iii) undertake a detailed socioeconomic survey and environmental impact
assessment (EIA) in accordance with the requirements of local regulations, ADB
safeguard policies and those of other external funding agencies likely to be approached
for funding; (iv) review assessments of the coconut resource at STEC and determine the
economic and physical feasibility of rehabilitating the plantation sufficiently to ensure the
production of sufficient coconuts to provide all fuel for the 3 MW base load power plant
on a continuing basis; (v) assess existing institutional arrangements for power
generation and delivery in Samoa and develop an institutional structure for the proposed
coconut processing and power generation facility that draws on the strengths of both the
public and the private sectors while being technically, socially and economically
optimized for the operation and maintenance of the coconut oil fuelled power generation
system; and (vi) assess and identify a financing scheme suitable for STEC, EPC, Samoa
Government, ADB and other funding sources.
242. Based on the results of Phase 1, Phase 2 will include: (i) preparation of an
engineering design for the complete power generation facility including generation,
connection to the existing grid and the facilities needed to produce the required quantity
of coconut oil suitable for engine fuel using whole coconuts as the raw material; (ii)
preparation of a rehabilitation and investment plan for the STEC plantation to bring
production to the level required for the continuous operation of the 3 MW power plant on
coconut oil fuel; (iii) preparation of a coconut collection and transport plan addressing the
45
logistics of nut collection and delivery to the processing site including plans for any road
or other infrastructure development needed on the STEC plantation to support the
collection and delivery plan; (iv) detailed development of an institutional structure for the
entire facility that optimizes inputs from the public and the private sectors; (iv)
preparation of a business plan for any private partners; and (v) preparation of documents
needed for project financing.
243. The TA (combined for both the 3MW biofuel power development and the Upolu
hydro development studies) is estimated to cost US$781,000 equivalent, with a foreign
exchange cost of US$582,000 and a local currency cost of US$199,000 equivalent. The
biofuel project is approximately 60 percent of the total TA cost.
244. The MOF will be the executing agency and EPC will be the implementing agency
of the TA. The EPC and the MOF will arrange for local support and help ensure
adequate cooperation from the Government and non-government organizations as well
as villages in the project area.
245. The TA will be implemented over a period of 8 months. Within 5 months after
commencement of the TA, the consultants will submit a draft final report for Phase 1 of
the biofuel power development component including the feasibility study report,
environmental impact assessment reports, and land acquisition and resettlement plan
(LARP). If Phase 1 results indicate project viability, Phase 2 will commence and 8
months following initiation of the TA the consultants will submit an engineering design
report for review.
i.
246.
TA funding
As of early 2006, no funding had been located for the project.
46
9.
Priority 2 Renewable Energy: hydro-electric development for Upolu
a.
247. Hydro-electric development for Upolu is a high priority for the EPC as their load
grows and the percentage of generation from high cost diesel increases. The objectives
of the project are to determine the feasibility of supplying additional energy from hydro
power on Upolu. Developing hydro power on Upolu is an activity that is consistent with
the REEP objectives of increased renewable energy use and rural development.
b.
Project location
248. A review of the 1997 Hydro-Electric Commission Enterprises Corporation
(HECEC) study and the 2003 Japan International Cooperation Agency (JICA) study
show that there are three potential sites on Upolu: Lotofaga, Tatifoala and Namo village
areas. A visit to the site of Lotofaga was done on March 12, 2005 by a REEP consultant
along with the EPC Engineering Manager and members of his staff. Included also was
the Fichtner consultant (Mr. Hubert Hildebrand) who was then carrying out the feasibility
study of the Savai'i hydro project.
249. After a few hundred meters of walking up the Leafe river it was obvious that the
preliminary designs presented in the JICA study were based on desk studies and had
not been assessed on the field. With the JICA recommended site, a project would be
very difficult to achieve technically as there are very steep slopes where the penstock
was to be located and the site is inaccessible by truck. The implementations proposed
by the HECEC study were much more remote and not accessible to the REEP team
without a much longer preparation time.
250. It is clear that the existing documentation is inadequate to justify proceeding with
a full feasibility study. Therefore it was proposed to EPC that the REEP developed TA
project have two components, a more complete prefeasibility study and then a feasibility
study covering the site determined as most appropriate from the results of the
prefeasibility study. The General Manager and the Engineering manager of EPC
approved the concept that the TA should consist of two phases:
!
Phase 1: Complete the prefeasibility studies for the areas near Lotofaga,
Tatifoala and Namo villages, including new on site data collection, technical
implementation and design estimates, environmental impact assessment and
social assessment
!
Phase 2: Complete a feasibility study of the best of the 3 schemes as determined
by the prefeasibility study. In addition, new measuring equipment would be
provided to EPC and/or Apia Observatory to support their monitoring activities.
!
A Phase 3 is proposed by the REEP team to prepare the actual engineering
design should the feasibility study indicate that the project should proceed. This
is proposed because the personnel needed to do the engineering design will be
on site for the feasibility study and the design can therefore be done at
considerable cost savings when compared to a stand-alone design consultancy.
47
Figure 5 – Lotofaga site proposed by the JICA study
251. Also, because many of the same skills are needed for the feasibility study for the
3 MW biofueled power development for EPC, it is proposed that the two feasibility
studies be combined into one renewable energy power development TA for EPC.
252. No realistic estimates of the site’s power producing potential can be made
without further study though it is known that the resource is seasonal (as with other
Samoa hydro development) and adding the site to the Upolu generation mix will not
significantly offset the firm capacity requirements of the EPC as the project will not
include water impoundment. Its economics will be primarily dependent on the cost of the
diesel fuel that it can replace.
c.
Project Preparation
253. The study will be carried out in three phases. Phase 1 will: (i) ensure that a
reasonable power development strategy and a lowest cost/benefit ratio option is followed
that will maximize economic, social and poverty reduction impacts; (ii) review the
HECEC and JICA studies of the proposed sites and all available background data on
48
their topography, hydrology and geology; (iii) visit the Lotofaga, Tatifoala and Namo river
sites and prepare concept designs for the sites that are technically developable; (iv)
prepare estimates of the cost of construction including access development, annual
energy production and peak power capacity for each of the sites; and (v) prepare a
report of the findings and rank the sites as to their appropriateness for development.
254. 14.
Phase 2 will: (vi) in consultation with stakeholders, determine the lowest
cost/benefit ratio hydropower development site among the technically developable sites;
(vii) assess existing institutional arrangements and identify measures to enhance project
management and lower future risk; and (viii) assess and identify a financing scheme
suitable for the EPC, Government, ADB and other funding sources.
255. 15.
Based on the results of Phase 2, Phase 3 will prepare the feasibility study
for the hydropower site considered by the prefeasibility study as most suitable for
development. The study includes: (ix) preparation of an engineering design of the most
economically attractive of the small scale hydropower sites; (x) undertaking a detailed
socio-economic survey, environmental impact assessment, and land acquisition and
resettlement plan in accordance with requirements of local regulations, ADB safeguard
policies and other external funding agencies; (xi) assessing the highest priority
components of the project for ADB financing; (xii) preparation of a project design
document for Clean Development Mechanism (CDM) approval; (xiii) development of
economic, financial, cash flow and power production projections for 15 years; and (xiv)
preparation of documents needed in project financing.
256. The TA (combined for both the 3MW biofuel power development and the Upolu
hydro development studies) is estimated to cost US$781,000 equivalent, with a foreign
exchange cost of US$582,000 and a local currency cost of US$199,000 equivalent.
257. The MOF will be the executing agency and EPC will be the implementing agency
of the TA. The EPC and the MOF will arrange for local support and help ensure
adequate cooperation from the Government and non-government organizations as well
as villages in the project area.
258. For the hydro development component, within 3 months after commencement of
the TA, a draft prefeasibility report will be submitted. Within 7 months after TA
commencement a draft feasibility report will be submitted for review. If the project is not
considered feasible, the draft feasibility report will be considered the draft final report. If it
is considered feasible, the engineering design report will be submitted 9 months after
commencement of the TA.
i.
259.
TA funding
As of early 2006, no funding had been located for the project.
49
IV.
SUB-REGIONAL PROJECT IN ENERGY EFFICIENCY (FIJI AND SAMOA)
A.
Project Concept and Objectives
260. The concept of this project is to develop a private sector capability for the design
and implementation of electrical energy efficiency improvements in the industrial,
commercial and government sectors. The objective is to improve the efficiency of energy
use with the long term goal of reduction of fossil fuel dependence and to help reduce the
rate of growth of the generation of greenhouse gases in Samoa and Fiji.
B.
Project Background
261. It has been recognized for decades that significant improvements in the
efficiency of energy use are possible in the PICs. Practical energy efficiency savings
estimates for individual PICs ranging from 4% to 30% of total energy use were cited by
the PIREP reports in 20046. The overall potential for total energy saving in the Pacific
sub-region through efficiency measures averaged approximately 10% with Fiji at 4% and
Samoa at 13%. These figures are considered conservative since: (i) they do not
represent maximum possible energy efficiency improvements but rather easy energy
savings that have a high rate of return and are technically practical with technologies
and human resources available in the Pacific; and (iii) energy efficiency opportunities
were only considered after renewable energy opportunities had been assessed. (ii) the
percentages are based on total energy use, which includes traditional biomass. The Fiji
figure is particularly low because the indigenous use of biomass for cooking is a major
energy use that has proven to be very difficult to reduce through efficiency improvement
programs. When only electricity use is considered, opportunities for electricity use
efficiency improvements, in terms of percentage of usage reduction, are expected to be
far greater than that when considering all energy sources.
262. Though Fiji and Samoa have not had surveys of the industrial/commercial sector
in recent years, the growth rate of tourism exceeds overall economic growth in both
economies. That implies that there is a significant and increasing market for energy
efficiency improvement services in air conditioning, lighting, water heating and support
services, all of which are heavily used by the tourist industry.
263. Government has buildings and pumping stations on their lists of top users of
electricity by the government sector in both Fiji and Samoa. In Samoa, church facilities
are among the “top 20” electrical energy users. Banks are in the Fiji “top 40” users list.
Fiji includes some industrial users among the top 40, though commercial and
government users dominate electrical energy use. Samoa has few industries so
commercial and government users are expected to be the primary target for energy
efficiency efforts. Both Fiji and Samoa are likely to have the greatest need for energy
efficiency services in commercial and government facilities, mostly relating to energy
efficiency improvements in buildings, though in Fiji there will also be some need for
industrial energy efficiency services.
264. A number of small national and regional projects have addressed energy
efficiency through the provision of energy audits for government, commercial and
industrial energy users and through limited public information efforts. Unfortunately, the
effect of these programs has been small and the energy savings that did result often
disappeared after a few years. A number of reasons have been cited:
6
PNG was not included due to lack of energy use data.
50
• The cost of energy for most commercial and industrial businesses of the types
found in Samoa and Fiji is typically less than 15% of the total cost of operations;
therefore improving energy efficiency has a lower priority than reducing costs in
other areas of the business. In mining, cement production and steel processing
activities in Fiji energy is a significant cost and there have been investments in
energy efficiency improvements though further investment may well be needed.
• The technical competence of most businesses does not include the installation,
operation and maintenance of energy saving equipment; therefore the equipment
is often operated incorrectly, maintained poorly and not replaced when worn out.
• Government polices and incentives for tourism and other business investments do
not include any provisions that encourage energy efficiency or discourage energy
waste.
• Programs carried out by a utility or a Government energy office have limited
capacity and can reach only a few energy users.
• Businesses are reluctant to make major investments in energy efficiency
improvements without assurance that they will indeed save the amounts projected
by the energy audits.
• Once installed, energy efficiency savings need to be monitored to ensure that
efficiency improvements are being maintained. Programs have not included any
long term follow-up and monitoring.
• The small size and isolation of PICs and the generally small size of local
businesses prevents international energy service companies from entering the
local market for any but the largest projects.
• Lending institutions are not familiar with financing energy efficiency improvement
equipment and may refuse finance or offer finance on unfavorable terms due to
the unknown risks.
• Utility and Government programs have limited lifetimes and once the programs are
ended, the public information programs and implementation programs also stop.
265. The REEP team and the Steering Committees have considered various
approaches to overcome these problems and have concluded that the development of
independent, private Energy Efficiency Service Companies (EESCOs) that address
energy efficiency issues for commercial, industrial and government clients have the
greatest potential for developing long term energy efficiency improvements in Fiji and
Samoa. The characteristics of energy efficiency processes carried out by an EESCO
include:
• Clients receive an energy audit and recommendations regarding the scope and
type of investment needed to provide cost reduction benefits through energy
efficiency measures.
• The EESCO works with a funding institution that has experience and knowledge
regarding finance of energy efficiency investments to obtain finance for the
investment at good terms, typically with periodic payments lower than the savings
projected to be provided by the investment.
51
• In association with the client’s technical staff, the EESCO implements the energy
efficiency measures with an independent body (typically the utility) providing a
“before” and “after” measurement of energy use of the process being improved to
ensure that the projected savings actually occur.. If not, then payments are
adjusted to fit the actual savings with a performance guarantee fund covering part
of any extra interest cost and added finance costs with the EESCO paying the rest.
• The EESCO works with the client to monitor and maintain the energy efficiency
improvement over time.
• The amount of payment to the EESCO for its services is contingent on clients
receiving energy efficiency improvements at the cost calculated by the EESCO.
• An EESCO has a strong incentive to continually provide public information about
energy efficiency improvements as part of its marketing efforts.
266. In both Fiji and Samoa, energy costs are high and the utilities are having
problems developing capacity to meet the growing electrical loads. It is clear that to
mobilize sufficient effort for the large-scale energy efficiency improvements that are
needed and justified economically and financially, the limited utility and government staff
available for energy efficiency improvements are inadequate. The private sector will
need to be directly involved in energy auditing and assisting companies in determining
the best investments for improving energy efficiency. Therefore, the Steering
Committees of both Samoa and Fiji have positioned the development of Energy
Efficiency Service Companies as the top priority for REEP energy efficiency
development. Through this process it is intended that a number of benefits would accrue
including:
• slowing the growth of diesel fuel imports and the related economic and political
burden,
• delaying or reducing the need for increased investment in generation,
• developing existing and creating new local, technical businesses and financial
services,
• improving the profitability of local companies through more efficient use of
resources,
• reducing the environmental impacts of energy use, in particular local pollutants
and GHG emissions, and
• over time, including the provision of energy efficiency services to smaller
neighboring countries that could not afford to develop such services themselves.
267. Since both Fiji and Samoa have requested that essentially the same concept be
developed as a priority for energy efficiency improvement, development of a subregional project that can support the private development of EESCOs in both Fiji and
Samoa is proposed for funding. This allows the consolidation of finance, capacity
building and other components resulting in more efficient use of funds and lower per
country program costs than required by development of individual programs for Fiji and
Samoa. Establishing the program for the sub-region also will make it much easier to
expand to other countries if the concept proves a success in Samoa and Fiji.
52
C.
Project proponents
1.
Fiji
268. The relatively large size of Fiji and the presence of several fairly large (by Pacific
standards) businesses and industries has allowed the development of a number of local
engineering and technical support companies in Fiji. Table 12 summarizes those
companies and individuals who have been interviewed by members of the REEP team
and who have expressed an interest in establishing EESCO operations. A few of these
companies have provided energy audits to clients and have assisted clients in selecting,
installing and establishing maintenance arrangements for equipment to improve energy
efficiency in the client’s business operations. However, none have yet developed a full
measure of services specifically oriented toward energy efficiency improvement for their
clients.
269. This is not an exhaustive list as it only identifies companies with offices in Suva
though that is where the bulk of the energy efficiency improvement opportunities lie. It is
expected that several companies or individuals in other areas of Viti Levu and in Vanua
Levu may also be interested in developing an EESCO capacity if the business can be
shown have a likelihood of being profitable.
270. The Chairman of the FEA Board indicated to the team that some thought has
been given to establishing an EESCO subsidiary of FEA. For the short term, this does
not appear likely since energy efficiency development activity at FEA is clearly very low
in priority with only one junior staff person and a JICA volunteer assigned to the task and
no working funds dedicated for future EE development.
Table 12 – Fiji Businesses and Individuals with EESCO Interests
Maurice Ruggiero, Managing Director, Tritech Consulting
152 Ragg Avenue; 332 2503 [email protected]
Bruce Clay, Managing Director, Clay Engineering
PO Box 2395, Govt Bldgs, Suva Tel: 336 3880 ; [email protected]
George Peterson & Warren Yee , Partners,
19 Domain Road; 330 2619 [email protected]
Irwin Alsop Consulting Engineers
Robert Pole, President, Fiji Institute of Engineers
Ian MaCallan Engineering Consultants; 340 Waimanu Road (near main Suva hospital)
Tel: 3313388 [email protected]
Robin Palmer, Managing Director, Ian MaCallan
Ian MaCallan Engineering Consultants; 340 Waimanu Road
Engineering Consultants
Tel: 3313388 [email protected]
Mr. Peni Drodrolagi, Managing Director,
Tel: 9920 504; [email protected]
Clean Energy, Fiji Ltd.
Mr. Amit Prakash,
Tel: 331 5770 [email protected]
Sinclair Knight Merz Engineering (SKM)
Mr. Jitendra Mehta, Managing Director, Poly Products
PO Box 5171 Raiwaqa; Tel: 338 5544 [email protected]
Mr. Tony Sansom, Sansom Design Architecture
17 Naimawi Street, Lami; [email protected] Phone: 359 0025; mobile:
9922120
2.
Samoa
271. The Team was unable to identify any existing technical companies that are
presently engaged in energy auditing and energy efficiency activities. However, several
individuals and one local consulting firm have indicated an interest in establishing an
EESCO capacity and, if appropriate support mechanisms and incentives are developed
for Samoa, establishing a small business or developing an existing business that
includes EESCO operations.
53
272. The Team also held discussions with several larger businesses in Samoa and all
agree that they would welcome the services of an EESCO to help lower operating costs.
In February, 2005, a team member presented a talk to the Samoa Association of
Engineers about energy efficiency and EESCO type operations and the response was
favorable.
273. Since the opportunities for EESCO type work in Samoa are much more limited
than in Fiji, developing businesses that specialize in EESCO operations will require more
external inputs for capacity building and Government will need to provide a favorable
environment for EESCO operation, for example through financial incentives, and – as
the largest sectoral user of electricity – by itself accepting EESCO services to improve
Government’s own efficiency of electrical energy use.
D.
Project Activities
274. For this concept to work, there are seven important factors that need to be
present. There must be:
1. a market for the services sufficiently large to justify the private development of
EESCOs.
2. local individuals willing to attain the necessary level of technical skill and then
develop an existing business or form a new business that can act as an EESCO;
3. an easily accessible and cost effective means of obtaining the necessary skills;
4. availability of acceptably priced finance for the implementation of energy
efficiency measures;
5. the presence of a performance guarantee mechanism external to the EESCO to
provide confidence to customers that the projected savings will be met;
6. an independent agency to determine the actual benefits provided by energy
efficiency measures and a clear, generally accepted methodology for that
determination;
7. strong support within the government and the utility to support EESCO business
development through complementary programs such as financial incentives,
marketing of energy efficiency measures, public information, etc.
275. In both Fiji and Samoa all these factors need further development though Samoa
is much weaker than Fiji in terms of local technical capacity and market.
1.
Capacity development
276. With the possible exception of a small number of Fiji Engineering firms that have
experience with energy auditing and the installation of energy efficiency improvement
measures for their clients, a well developed training program will be needed to upgrade
the capacity of interested companies and individuals to competently provide EESCO
services in both Fiji and Samoa.
277. Although the Fiji Institute of Technology (FIT) has an introductory module on
energy audits in its electrical training program, the module is not sufficiently specialized
or advanced enough to provide the level of training needed. There is no energy
efficiency training provided in Samoa though Samoa Polytechnic does have an electrical
program that could incorporate such training.
278. The proposed project therefore includes the provision of a training program for
Fiji and Samoa by an outside agency, such as the International Institute for Energy
Conservation (IIEC) or another organization that has an appropriate EE training
capacity. The external agency would be expected to identify and train EESCO
54
candidates and assist Fiji training institutions (FIT and/or TPAF) and, if there is sufficient
interest the Institute of Technology in Samoa, in developing an ongoing training program
for energy auditing and the development of energy efficiency improvement measures.
279. The Governments of Fiji and Samoa would be expected to provide participants
some “hands on” experience through the development of energy efficiency
improvements for selected Government facilities by participants while still under the
supervision of the trainers.
280. Since the cost of bringing Samoa trainees to Fiji is likely to be greater than the
cost of bringing trainers to Samoa, separate training programs for Fiji and Samoa are
proposed. This also allows trainers to focus on the specific problems of each country in
the training process and for the “hands on” component to be done in the target country.
281. It is recognized that no training program can cover all the aspects of EESCO
technical operations and support from external experts will be needed for at least the
initial years of program operation. Although much of this external expert support can be
provided through electronic communications, at least once per year for the first three
years of program operation, a visit by an external expert to both Samoa and Fiji is
proposed. This visit would be to upgrade training for both EESCOs and training
institution instructors and to review the prior year’s operations by EESCOs, help them
evaluate their work and propose improvements in their work processes.
2.
Implementation loan guarantee
282. Readily available finance at acceptable terms will be needed in both Fiji and
Samoa. Discussions with existing commercial lending institutions indicate that those
institutions have little experience with the finance of energy efficiency improvements and
have little concept of the relative risks involved. As a result, loans for energy efficiency
improvements can be expected to have more strict collateral requirements, higher
interest rates and generally poorer terms than those offered for more common
commercial investments.
283. To reduce this barrier, the proposed project would take two actions: (1) as part of
the capacity building process, local lending institutions would be provided training in the
basics of energy efficiency investments and in evaluating the risks of those investments,
and (2) a loan guarantee fund for energy efficiency investments would be established
that would act to reduce the risk of energy efficiency finance. The loan guarantee fund
would be intended to lower the perceived finance risk for energy efficiency investments
and provide incentives for local financial institutions to gain experience in EE investment.
The fund would be fully in place for three years and slowly phased out over the 4th
through 8th year after program commencement.
284. This fund would be managed through a contract with a single financial institution
for both Fiji and Samoa and could be expanded to other countries in the region.
3.
Performance guarantee
285. For the EESCO efforts to be accepted, they must be able to guarantee the
performance of the proposed energy efficiency investment at least for the period of any
loans received for implementation. Since most of the EESCOs will be small businesses
and will have very limited resources, they will not be able to provide a performance
guarantee that clients are likely to consider credible. To increase the confidence of
clients, an externally managed performance guarantee fund would be established to
supplement the resources of the EESCOs in the case of an installation failing to meet
55
contracted savings and implementation costs. The presence of this fund would also help
encourage the development of EESCOs since their payment is to be dependent on
performance.
286. Should performance be lower than contracted, the performance guarantee fund
would pay part of the difference between the contracted amount and the measured
amount. The EESCOs would lose the income not covered by the performance
guarantee. Initially external financial input would be required but EESCOs would be
expected to contribute to the fund, based on the size of their project portfolio so that in
the long term, the fund would be self-perpetuating. It is proposed that the same financial
management firm that handles the loan guarantee fund would manage the performance
guarantee fund.
4.
Independent auditing of performance
287. Since the EESCO would be paid on the basis of the actual energy savings
resulting from a proposed investment, some process that is independent of both the
EESCO and the client must be in place for determining the actual savings. For Fiji and
Samoa, the FEA and EPC are proposed as the independent auditors of performance for
energy efficiency installations as they are the only existing organizations with the
necessary skills and facilities. The independent auditor would be expected to monitor the
energy usage for a period immediately before and an equivalent period immediately after
the installation and would issue a report that indicates the actual performance of the
installation.
288. The methodology to be used would be developed under the project in association
with the FEA and EPC and would, where possible, be designed using the experience of
other countries with similar performance measurement requirements. Training in the
methodology would be provided to FEA and EPC under the project.
5.
Government support
289. In the early stages of EESCO development, it will be important that Government
provide support through incentives and programs directed to prospective clients (e.g.
subsidies for interest charges on EE finance, covering the cost of the utilities providing
independent performance measurements, public information services that emphasize
EESCO use and energy efficiency in general). Also, as Government in both Fiji and
Samoa is a major user of energy and also the owner of companies that are major energy
users, a program by Government to use the services of the new EESCOs would provide
a strong incentive for companies to start EESCO operations as well as resulting in major
energy savings for government and its corporations.
E.
Project preparation components
290. Although this project concept has been used in other parts of the world, for
example in Sri Lanka, India and China, it is new to the Pacific and care must be taken to
ensure that the project is designed to best fit the small island context as exists in Fiji and
Samoa. All the factors are not yet sufficiently determined to estimate the amount of
external funding needed to establish the loan guarantee fund, the performance
guarantee fund, provide the needed capacity building and support the availability of
external expert assistance during the initial years of operation. However, because the
funds strongly leverage external commercial finance, a total initial investment of less
than US$2 million is presently anticipated as needed to provide the training, external
expert support services and initial fund inputs.
56
291. Using additional information obtained during a September 2005 visit of an
International Team member to Samoa and Fiji and building on the information gleaned
from the Bangkok 2005 ESCO conference, the team considers the approach to be
sufficiently promising to develop a proposal for a TA to complete the feasibility study
initiated by the REEP team and to preparing a detailed project design suitable for
funding by ADB or another funding agency.
1.
Proposed TA activities leading to a project design suitable for
funding
292. The assistance will be implemented in two stages. In Stage 1 the TA will prepare
an estimate of the market for energy efficiency improvement and a determination of the
sector(s) that should be the initial focus of an EESCO-managed energy efficiency
improvement program for Fiji and for Samoa and a determination of the feasibility of
EESCO-implemented energy efficiency programs for Fiji and Samoa. If considered
feasible, Phase 2 will include the preparation of a detailed structural design of an
EESCO development project for ADB or another funding agency support.
293. Phase 1, lasting 4 months after commencement, will: (i) review existing and past
energy efficiency programs in Fiji and Samoa regarding their scope, structure and
effectiveness; (ii) establish a Project Steering Committee in each country that includes
representatives from key stakeholders; (iii) consult with the Fiji Electricity Authority (FEA)
and other stakeholders to select at least six representative major electrical energy users
in each of the government, industrial and commercial sectors; and in Samoa consult with
the Electric Power Corporation (EPC) and other stakeholders and select three
representative major energy users in each of the same sectors; (iv) through on-site
surveys of the representative major energy users, determine their responsiveness to and
the probable net benefits of EESCO support for energy auditing, implementation finance,
performance guarantees and ongoing contracted services; (v) based on the surveys and
discussions with key stakeholders, estimate the percentage savings that can be
economically realized in electrical energy for each sector and the cost to achieve that
level of savings; (vi) assess the capacity of the private sectors in Fiji and Samoa to
develop competent EESCOs, assuming specialist training will be provided under the
program; (vii) assess the capacity of the financial institutions in Fiji and Samoa to
provide finance of the type needed for implementation of an EESCO program in each
country; (viii) assess the capacity needed at SOPAC to manage an EESCO
development project that includes provision of training (for prospective EESCOs, FEA,
EPC and financial institutions), overseeing the management of a regional EESCO
performance guarantee fund and supporting Fiji and Samoa governments in the
implementation of any policy, regulatory, monitoring and support structures required
under such a project; (viii) determine and prepare specifications for any hardware and
software needed to support energy savings calculations and the monitoring of energy
savings; and finally (ix) determine the economic, financial and capacity feasibility of
development of EESCOs for electrical energy efficiency improvement in Fiji and Samoa.
294. Based on the results of Phase 1, Phase 2, lasting 4 months after completion of
Phase 1, will include: (i) the detailed design of an EESCO development project taking
into consideration requirements for public and private sector capacity building, regulatory
requirements, any needs for legislation, market development needs and requisite
financial components; (ii) preparation of an implementation plan for the project; (iii)
preparation of a pro-forma business plan for a typical EESCO; and (iv) preparation of
documents needed for project financing.
57
a.
Cost and Financing
295. The TA is estimated to cost US$615,000 equivalent, with a foreign exchange
cost of US$434,000 and a local currency cost of US$181,000 equivalent.
b.
Implementation Arrangements
296. As the program is sub-regional in nature and only SOPAC has the mandate and
capacity to manage and implement a program of this type at the sub-regional level,
SOPAC is expected to be the executing and implementing agency of the TA with local
support by country contacts determined by SOPAC based on stakeholder consultations.
Country contacts are expected to be the Fiji Department of Energy and the Samoa
Energy Unit within the Ministry of Finance.
composed of an EESCO development specialist (team leader), an economic and
financial specialist and a private sector/institutional specialist. Other international and
short-term specialists as identified during Project implementation (e.g., fund
management specialist, technical trainers, energy use monitoring specialist) may be
included. Additionally, local consultants will be hired, equivalent to 3 person-months,
consisting of short-term specialists as identified during Project implementation (e.g.,
information gathering and survey support). TA implementation will be assisted by a team
of international and domestic consultants.
298. The TA will be implemented over a period of 9 months. Within 4 months after
commencement of Phase 1 of the TA, the consultants will submit a draft final feasibility
study report for Phase 1. If the program is considered feasible and there is a Phase 2
under this TA, the TA draft final report will be submitted within 8 months from the
commencement of the TA. If Phase 1 efforts determine that the program is not feasible,
the draft final feasibility study report will be considered the TA draft final report.
58
V.
DISSEMINATION OF RESULTS
299. The REEP team members have disseminated their findings regarding renewable
energy and energy efficiency in the Pacific region through:
• Preparation of this final report for distribution in the region and for posting on an
ADB approved website.
• Dissemination of results in Fiji and Samoa through the Steering Committee
members to the sectors they represent. Steering Committee meetings were held
during each visit of the REEP consultants to Fiji and Samoa. At each meeting
detailed findings of the REEP team were presented and discussed. Additionally
there were frequent communications between the REEP team members and
Steering Committee members during the periods between visits to provide new
information or to discuss specific actions needed.
• The REEP sponsored a resource person from Europe to support a sub-regional
biofuels workshop held in Fiji on 16-17 March 2005.
• A REEP team member provided a presentation at the Pacific regional energy
officials meeting held in Suva from 8-10 November 2005
• The REEP team provided a two day solar technology course (9-10 February 2006)
for trainers at FIT, Fiji DOE, TPAF and CATD (See Appendix 8 for details)
• The REEP sponsored and organized a 15 country regional renewable energy and
energy efficiency workshop that included presentations by REEP team members
on specific findings of the REEP (20-23 February 2006), See Appendix 10 for
details).
• The REEP sponsored and organized a donor and regional agency meeting where
REEP team members provided Pacific regional agency and donor representatives,
details of the REEP project proposals (24 February 2006) (See Appendix 10 for
details).
59
VI.
CONCLUSIONS AND NEXT STEPS
A.
Attainment of intended outputs from the REEP
300.
The intended outputs from the REEP were:
(i)
review of, consultations on, and dissemination of lessons from past
renewable energy and energy efficiency assistance in the Pacific
(ii)
an action plan for the adoption of appropriate policies, institutional
arrangements, legal/regulatory measures, and financial schemes including
venture capital, as well as private sector and household-level incentive
mechanisms for promoting commercially viable renewable energy and energy
efficiency services;
(iii)
a training needs analysis and training curricula for private and public sector
key players in the two PDMCs
(iv)
a pipeline of projects for funding by ADB, GEF, and/or other relevant
financing sources
(v)
based on outcomes and progress made in the two selected countries, final
consultations and dissemination of lessons learned from the TA to other
PDMCs with a focus on establishing policy frameworks, building capacity,
and replicating/disseminating good practices.
301. The REEP has completed these outputs with the exception of the following items
which were prepared under other programs that were functioning at the time of the
REEP activity and were therefore not duplicated by REEP:
!
Lessons learned regarding renewable energy were reviewed and disseminated in
detail through the country and regional reports of the PIREP project of SPREP in
2003-2004. The REEP team provided a review only of energy efficiency projects
and lessons learned as those were not included in the PIREP.
!
ESCAP prepared and disseminated a detailed analysis of training needs in
renewable energy for the Pacific region, including Fiji and Samoa, in 2005 thus
the REEP team concentrated only on curriculum reviews and training of trainers
in Fiij and Samoa.
!
The PIEPSAP project under SOPAC is specifically for energy policy development
and both Samoa and Fiji are engaged with that program for the preparation of
National Energy Policies and other policy efforts. Therefore the REEP did not
include policy and institutional development beyond the narrow areas of energy
efficiency development that included Fiji and Samoa energy efficiency action
plans and the institutional development for those plans.
302. The REEP went beyond the initial Terms of Reference with regard to project
pipeline development in that the requirement was for one renewable energy and one
energy efficiency project for each target country. The REEP prepared three renewable
energy projects for Fiji (hydro, biofuel and geothermal) and two renewable energy
projects for Samoa (biofuel and hydro) and a major sub-regional project for energy
efficiency (EESCO development).
303. The REEP also went beyond the Terms of Reference with regards to training and
information dissemination in that:
60
!
a two day training of trainers course on solar energy was prepared and delivered
to trainers at FIT, TPAF and CATD in Fiji
!
The REEP expanded the final workshop beyond just a dissemination of REEP
results. A four day renewable energy and energy efficiency workshop attended
by 15 Pacific Island nations was sponsored under the REEP with the support of
the Technical Centre for Agricultural and Rural Co-operation CTA where the
results of the REEP were disseminated as well as providing participants with the
most up to date information on renewable energy and energy efficiency
applications appropriate to the Pacific region (See Appendix 10 for details).
B.
Next steps
1.
Project pipeline
304. 304. The REEP provided prefeasibility studies for the Fiji and the Samoa
biofuel projects and the sub-regional EESCO development project. The next step is a full
feasibility study for those projects. Likewise, the promoters of the Namosi hydro project
provided a prefeasibility study and the next step for that project is also a full feasibility
study. However, the Upolu hydro development and the Viti Levu geothermal
development projects both require additional prefeasibility studies before a commitment
should be made for the more substantial cost of a full feasibility study for each of those
projects. The PIEPSAP project has indicated that it will fund a feasibility study for the
Rotuma biofuel project but the other proposed projects do not yet have committed
funding for the completion of feasibility studies. The Governments of Fiji and Samoa and
the proponents of the projects have been advised that they need to actively pursue the
necessary funding for the PPTAs needed to complete the feasibility study phase of
project implementation.
2.
Policy and institutional development
305. 305. Neither Fiji nor Samoa have yet committed to a National Energy Policy
(NEP) though the policies are in the last stages of development. An NEP and the
development of a consistent strategy for its implementation are considered vital to the
rational development of renewable energy and energy efficiency efforts in the two
countries. Additional policy and institutional structures that are needed in the near term
for further development of RETs and EETs include:
!
IPP policies that favor renewables. The utilities in Fiji and Samoa do not yet
have economically rational policies for accepting power from IPPs and are
unlikely to develop such policies without government intervention. The
development of a policy for Independent Power Producers using renewable
energy that reflects the national priorities for renewable energy development and
the real marginal, economic cost of new generation by the national utility is
essential for the private sector to become fully engaged in the development of
renewable energy resources for power production.
!
Building codes that include energy efficiency considerations. The rapid
increase in the use of air-conditioning in the past 15 years has been a major
contributor to increased electrical demand. The existing building codes do not
consider energy efficiency and most new office buildings and many tourist
facilities are continuing to be built using designs that could have their energy
efficiency easily and cost effectively improved through minor design changes
61
before construction but once built, improved energy efficiency will be much more
costly to achieve.
!
Legislation for renewable energy and energy efficiency regulation.
Regulation of imported products with regards to their energy efficiency,
particularly of motor vehicles and major electrical appliances, is necessary if
efforts at improving the national efficiency of energy use is to be achieved. A
legal basis for that regulation is necessary if it is to be consistently applied for the
long term and is to be effective. Also, in Fiji if the concept of a Public Private
Partnership for rural electrification (through the use of RESCOs) is to be
effective, the DOE must have the legislated powers to perform the activities
needed to act as the public component of that partnership. Those include the
large scale leasing of energy production equipment to the private sector and the
regulation of the use of that equipment for the public benefit.
!
An updating of the Fiji Rural Energy Policy. The 1993 rural energy policy of
the DOE needs to be updated with regards to electrification technology in order
to properly reflect the real cost of rural electrification. The existing policy strongly
favors diesel based rural electrification for off grid use because the cost to the
recipient village for electrification is based on a percentage of the capital cost.
Diesel electrification has the lowest capital cost but generally a much higher life
cycle cost than renewable energy technologies such as solar PV and village
scale hydro power. The policy needs to be redesigned to reflect life cycle cost
rather than just capital cost and to better fit national priorities for reducing
dependence on fossil fuels and for environmental benefits.
!
Better dissemination of renewable energy and energy efficiency project
results within the Pacific Region. Renewable energy and energy efficiency
projects continue to be designed that use methods and components that have
been shown through experience in other Pacific nations to be inappropriate. This
appears to be partly due to a lack of a systematic collection and dissemination of
information about Pacific renewable energy and energy efficiency projects and
partly due to reluctance on the part of project developers to discuss problems
with their projects. A consistent process for the evaluation of RET and EET
projects in the region and for the dissemination of information about both success
and failure modes for those projects would help avoid the repetition of failures
and help promote the replication of successes in the region.
62
APPENDICES
Appendix 1
Namosi, Naitisiri Hydro Project Prefeasibility Study
Appendix 2
Prefeasibility study for the Electrification of Rotuma Based on
Locally Produced Coconut Oil
Appendix 3
Proposed Energy Efficiency Action Plan for Samoa 2006-2008
Appendix 4
Review of Past and Present Fiji DOE Energy Efficiency Activities
and Recommendations for the Future
Appendix 5
Survey of Standards and Certification Systems for Energy
Efficiency and Renewable Energy
Appendix 6
Proposed Standards for RESCO SHS Installation and
Maintenance
Appendix 7
Proposed Standard Specifications for RESCO managed Solar
Home Systems (SHS)
Appendix 8
Training Course for Solar Photovoltaics Instructors in Fiji (9-10
February, 2006). Curriculum for Solar PV at FIT (2005)
Appendix 9
Facility Requirements for PV Technician Training
Appendix 10
Regional Workshop on Renewable Energy and Energy Efficiency,
Fiji, 20-24 February, 2006
Appendix 11
Case Studies of Renewable Energy and Energy Efficiency
Financial Mechanisms Around the World
Appendix 12
Persons Contacted in the Course of REEP Activities
Appendix 13
Terms of Reference for the Renewable Energy and Energy
Efficiency Program
63
APPENDIX 1 - I
APPENDIX 1
NAMOSI, NAITISIRI HYDRO PROJECT PREFEASIBILITY STUDY
APPENDIX 1 - I
TABLE OF CONTENTS
TABLE OF CONTENTS ................................................................................... I
PREFEASIBILITY STUDY FOR MINI-HYDRO SCHEMES IN THE NAMOSI
AND NAITASIRI PROVINCES IN VITI LEVU AND IN TAVEUNI
ISLAND................................................................................................... 1
1.
GENERAL ........................................................................................................ 1
1.1.
1.2.
2.
BACKGROUND .................................................................................................................... 1
PURPOSE OF THE PRE-FEASIBILITY STUDY.......................................................................... 1
BASIC DATA .................................................................................................... 1
2.1.
READILY AVAILABLE HYDROLOGICAL DATA ........................................................................ 1
2.1.1.
2.1.2.
DATA RELATED TO VITI LEVU ............................................................................................. 1
DATA RELATED TO TAVEUNI ............................................................................................... 2
2.6.1.
2.6.2.
EXISTING .......................................................................................................................... 3
CARRIED OUT DURING THE MISSION .................................................................................... 3
2.2.
2.3.
2.4.
2.5.
2.6.
2.7.
3.
PRINCIPLES OF HYDROELECTRIC SCHEMES ........................................................................ 4
GENERATED ENERGY PLACING .......................................................................................... 4
TRANSMISSION LINES ......................................................................................................... 5
PRELIMINARY ECONOMIC EVALUATION ............................................................... 6
4.1.
4.2.
5.
GEOLOGICAL DATA ............................................................................................................ 4
HYDROSCHEMES CONSIDERED AT THIS PREFEASIBILITY STAGE ............................ 4
3.1.
3.2.
3.3.
4.
HYDROLOGICAL DATA EXISTING AT THE HYDROLOGICAL DEPARTMENT ............................... 2
RUNOFFS AND FLOODS ....................................................................................................... 2
MONTHLY RUNOFFS............................................................................................................ 3
FLOODS ............................................................................................................................. 3
TOPOGRAPHICAL DATA....................................................................................................... 3
UNIT RATES ........................................................................................................................ 6
PRELIMINARY COSTS .......................................................................................................... 6
CONCLUSIONS AND RECOMMENDATIONS ............................................................. 6
DESCRIPTION OF THE HYDROSCHEMES .................................................. 7
WAIROKODRA ............................................................................................... 8
1.
HYDROLOGICAL DATA ...................................................................................... 8
1.1.
1.2.
2.
3.
3.1.1.
3.1.2.
RUNOFF ............................................................................................................................. 8
FLOODS ............................................................................................................................. 8
GEOLOGICAL CONDITIONS ................................................................................. 9
PRINCIPLE AND SIZING OF THE SCHEME .............................................................. 9
3.1.
DAM ................................................................................................................................... 9
3.2.
WATERWAY ...................................................................................................................... 10
SERVICES PROVIDED BY THE DAM ....................................................................................... 9
DAM STRUCTURE .............................................................................................................. 9
APPENDIX 1 - II
3.3.1.
3.3.2.
3.3.
POWER PLANT ................................................................................................................. 10
EQUIPMENT .....................................................................................................................10
STRUCTURE .....................................................................................................................10
4.
5.
6.
ACCESS ROADS ..............................................................................................10
TRANSMISSION LINE ........................................................................................11
PRELIMINARY EVALUATION ...............................................................................11
WAIVAKA...................................................................................................... 12
1.
HYDROLOGICAL DATA......................................................................................12
1.1.
1.2.
2.
3.
RUNOFF ........................................................................................................................... 12
FLOODS ........................................................................................................................... 12
GEOLOGICAL CONDITIONS ................................................................................13
PRINCIPLE AND SIZING OF THE SCHEME .............................................................13
3.1.
DAM ................................................................................................................................. 13
3.1.1.
3.1.2.
SERVICES PROVIDED BY THE DAM ......................................................................................13
DAM STRUCTURE .............................................................................................................14
3.3.1.
3.3.2.
EQUIPMENT .....................................................................................................................14
STRUCTURE .....................................................................................................................14
3.2.
3.3.
4.
5.
6.
WATERWAY ...................................................................................................................... 14
POWER PLANT ................................................................................................................. 14
ACCESS ROAD ................................................................................................14
WAISOI.......................................................................................................... 16
1.
1.1.
1.2.
2.
3.
INFLOW ............................................................................................................................ 16
FLOODS ........................................................................................................................... 16
PRINCIPLE AND SIZING OF THE SCHEME .............................................................17
3.1.
DAM ................................................................................................................................. 17
3.1.1.
3.1.2.
SERVICES PROVIDED BY THE DAM ......................................................................................17
DAM STRUCTURE .............................................................................................................17
3.3.1.
3.3.2.
EQUIPMENT .....................................................................................................................18
STRUCTURE .....................................................................................................................18
3.2.
3.3.
4.
5.
6.
WATERWAY ...................................................................................................................... 18
POWER PLANT ................................................................................................................. 18
ACCESS ROAD ................................................................................................18
WAILUTULEVU............................................................................................. 20
1.
2.
3.
POSSIBLE SCHEME PRINCIPLE ..........................................................................21
1.1.
1.2.
RUNOFF ........................................................................................................................... 20
FLOODS ........................................................................................................................... 20
APPENDIX 1 - III
NAMADO....................................................................................................... 22
1.
1.1.
1.2.
RUNOFF ........................................................................................................................... 22
FLOODS ........................................................................................................................... 22
2.
3.
PRINCIPLE OF THE SCHEME ..............................................................................23
4.
5.
3.1.
3.2.
3.3.
DAM ................................................................................................................................. 23
WATERWAY ...................................................................................................................... 23
POWER PLANT .................................................................................................................. 23
WAINIKOVU.................................................................................................. 25
1.
1.1.
1.2.
2.
3.
RUNOFF ........................................................................................................................... 25
FLOODS ........................................................................................................................... 25
WAIMANU ..................................................................................................... 27
1.
HYDROLOGICAL DATA .....................................................................................27
1.1.
1.2.
RUNOFF ........................................................................................................................... 27
FLOODS ........................................................................................................................... 27
2.
3.
4.
5.
6.
ACCESS .........................................................................................................29
3.1.
3.2.
DAM ................................................................................................................................. 28
POWER PLANT .................................................................................................................. 29
SOMOSOMO................................................................................................. 30
1.
2.
PROJECT PRINCIPLE .......................................................................................30
COMPONENTS OF THE SCHEME .........................................................................31
2.1.
2.2.
2.3.
3.
STUDIES TO BE CARRIED OUT ...........................................................................32
3.1.
3.2.
4.
WATER INTAKE ................................................................................................................. 31
PENSTOCK ....................................................................................................................... 31
POWER PLANT ................................................................................................................. 31
DEMAND STUDY ............................................................................................................... 32
ENVIRONMENT STUDY ...................................................................................................... 32
PRELIMINARY EVALUATION ..............................................................................32
DATA TO BE ACQUIRED DURING THE COMING WET AND DRY
SEASONS ............................................................................................ 33
1.
HYDROLOGICAL DATA .....................................................................................33
1.1.
1.2.
DATA TO BE ACQUIRED FROM THE HYDROLOGICAL DEPARTMENT OF THE MINISTRY OF
PUBLIC WORKS ................................................................................................................ 33
DISCHARGE MEASUREMENTS............................................................................................ 33
APPENDIX 1 - IV
1.2.1.
1.2.2.
1.2.3.
WAIROKODRA, WAIVAKA AND WAILUTULEVU SCHEMES ......................................................33
NAMADO SCHEME ............................................................................................................35
MEASUREMENTS PROCEDURES .........................................................................................35
1.3.
1.4.
2.
3.
RAINFALL DATA ................................................................................................................ 35
STAGE DISCHARGE RELATIONSHIP .................................................................................... 35
TOPOGRAPHICAL DATA TO BE ACQUIRED ..........................................................36
GEOTECHNICAL DATA ......................................................................................36
APPENDIX 1 - 1
PREFEASIBILITY STUDY FOR
MINI-HYDRO SCHEMES IN THE NAMOSI AND NAITASIRI
PROVINCES IN VITI LEVU AND IN TAVEUNI ISLAND
1.
GENERAL
1.1.
BACKGROUND
Further to a review of the potential hydro-schemes sites in the Namosi and Naitasiri Provinces in the south
eastern part of the island of Viti Levu, and in the Taveuni Island, Fiji, several sites have been preliminary
retained for further consideration by a specialised organisation.
All the potential schemes are located in areas with considerable rainfall (4 to 6 m/year for the schemes in
Viti Levu, to 10 m/year for the Taveuni scheme), and most of the schemes take benefit of significant to
large heads over short river reaches, conditions that are a priori favourable for the development of
hydroelectric schemes.
As a result and despite of small catchment basins (6 to 120 square kilometres), the hydraulicity and
available heads allow envisaging the construction of schemes with installed capacity of 1.5 to 7 to 8 MW.
1.2.
PURPOSE OF THE PRE-FEASIBILITY STUDY
A first assessment of the hydro potential of the various sites, together with a definition of the principle of the
schemes and a preliminary evaluation of the related construction cost is required to be carried out by a
professional Consulting Engineer with international experience in the study design and construction of
similar schemes, to confirm the potentialities of the sites and allow for the mobilisation of the needed
financial resources to carry out a proper feasibility study before proceeding with the final design and
starting the construction activities.
The intent is therefore to proceed as soon as possible with this full feasibility study to establish the actual
technical, economical and financial viability of the envisaged projects.
2.
2.1.
BASIC DATA
READILY AVAILABLE HYDROLOGICAL DATA
2.1.1.
DATA RELATED TO VITI LEVU
A.
Global hydrological data and records
Global hydrological data have been reported on the Hydrogeological Map of Viti Levu, issued by the
Mineral Resources Department, Fiji.
These data include
–
the average monthly rain at Laucala Bay, near Suva,
–
the monthly evapotranspiration,
–
the map of the isohyets covering Viti Levu.
–
the annual rainfall at Laucala Bay from 1942-43 to 1988-89.
APPENDIX 1 - 2
These data allows a reasonable determination of the monthly runoff available in a given catchment basin,
but not the related cumulated discharge curve, nor the instantaneous discharge variation within the month.
Hourly discharge records are existing at gauging stations in the area of the schemes (Wainikacau, Namosi
(records available until 1985 ? only), Waimanu and Somosomo creek) but they are not readily available
and have not been used for this evaluation.
A request for obtaining these data has been made to the Hydrological Department of the Ministry of public
works, but the related data are still awaited.
Except for the Waimanu river, no records exist in the rivers retained for the study of the envisaged
hydroelectric schemes.
It is therefore necessary to initiate at the earliest regular measurements of the discharges wherever
possible in those rivers.
B. Hydrological Study for Monasavu Hydroelectric Scheme Project
A detailed hydrological study has been carried out by SA Gibb and Merz & McLellan around years 19781980 within the framework of the study of the Monasavu Hydroelectric Project. This study covers general
considerations on the Hydrology of Viti Levu, and more detailed study of the rainfall, runoff and rainfallrunoff correlations and floods on the Nadrau Plateau.
In the absence of more detailed data collected in the Namosi study area, it has been considered justified to
make use, in the present prefeasibility study, of the data collected and analysed in the Gibb study.
In particular, measurements on two gauging stations allow a first approach for the determination of a
standard cumulated discharge curve.
2.1.2.
DATA RELATED TO TAVEUNI
Data relatqed to Taveuni include daily flow duration of the Naibili Creek and of the spilling of Lake
Tagimocia, which have been subject of regular measurements carried out from 1981 to 1982 within the
framework of a feasibility and detailed study.
2.2.
HYDROLOGICAL DATA EXISTING AT THE HYDROLOGICAL DEPARTMENT
The following records related to the project area have been indicated to be available at the Hydrological
Department of the Ministry of , most of them on an hourly basis (Chief Hydrologist Richi Raj, meeting on
Feb 23):
1) Discharge records:
–
Waynicacau
–
Namosi
–
Waimanu
–
Somosomo creek - Taveuni
2) Rainfall
–
Nasevu
–
Wainicavu
–
Waimanu
–
Wainaboro
–
Nabukaluka
–
Wainivra
–
Des Voeux Peak - Taveuni
Partial records are available only for the Namosi gauging station.
However, these data do not appear to be readily available, as they require some works to be carried out
before they can be released, which requires time and proper order.
2.3.
RUNOFFS AND FLOODS
At the present preliminary stage of the study, it is necessary to get a reasonable estimate of the inflow
available for each envisaged scheme, at least on average and on a monthly basis, as well as of the large
floods.
APPENDIX 1 - 3
MONTHLY RUNOFFS
2.4.
A.
Determination procedure
The data provided by the Hydrogeological Map of Viti Levu allow the determination of the monthly inflows
for each catchment, by application of the following procedure:
–
The isohyets give the distribution of the average yearly rainfall over a given catchment
basin, which allows the determination of the weighted average of the rainfall over the
basin,
–
The monthly runoff in the catchment is obtained by rating the monthly rainfall at
Laucala Bay proportionally to the yearly average rainfall in the catchment and to the
annual distribution of the rainfall at Laucala Bay, and deducting, for each month, the
corresponding monthly evapotranspiration which is considered constant for each
month of the year.
B.
Estimation of available runoff
The average runoff determined by this procedure amount to 2100 to 3000 mm/year for the schemes in
Namosi province.
For the Somosomo scheme inTaveuni, the runoff is probably higher than 8 meters/year.
2.5.
FLOODS
The rains and floods of the Hurricane Bebe, which caused large amounts of rainfall on Viti Levu on October
23 and 24, 1972, are well documented and described in the Gibb and Merz & McLellan’s report on the
Monasavu study. They are convenient to evaluate the maximum floods to take into account for the
preliminary design of new hydroelectric schemes.
The maximum flood considered for the sizing of the Monasavu Dam spillway has been determined through
a maximisation process. It retains a 732 m3/s peak discharge for a 62.5 km² catchment basin.
For the present preliminary evaluation of the characteristics of the dams of the various schemes under
consideration, we shall consider the Monasavu peak discharge factorised proportionally to the 0.75 power
of the related catchment area.
TOPOGRAPHICAL DATA
2.6.
2.6.1.
EXISTING
No specially made survey data are available for the various sites of Viti Levu, and the only available
sources are:
–
Standard 1:.50 000 scale topo maps,
–
Standard aerial photos at 1:50 000 scale,
–
Colour aerial photos at 1:40 000 scale.
Topographical data related to the Somosomo project in Taveuni are available in the Detailed Design and
Tender Documentation prepared by Beca Worley for the construction of a 350 kW scheme.
2.6.2.
CARRIED OUT DURING THE MISSION
Limited survey works have been carried out during the mission on March 4 by a team of Wood and Jepsen
Consultants:
1) Namadu Scheme
–
Cross section at provisional dam axis
–
Levels at various points along the river course, including the site provisionnaly
retained for the power plant.
2) Wainokodra Scheme
–
Cross section at provisional dam axis;
–
Cross section of bridge.
APPENDIX 1 - 4
2.7.
GEOLOGICAL DATA
Preliminary geological investigations have been carried out by Mr Geof Taylor of PACAu (Fiji) Limited on
five sites of the Namosi and Naitasiti Provinces (Winikovu, Mado Gorge, Wainarava, Wairokodra and
Waimanu).
These investigations are subject of a report entitled “Preliminary Geological Investigations of Five Hydro
Dam Sites in the Namosi and Naitasiri Provinces Viti Levu, Fiji”, dated 06 February 2004.
3.
HYDROSCHEMES CONSIDERED AT THIS PREFEASIBILITY STAGE
Eight small scale hydroelectric schemes have been considered and briefly studied at this stage, based on
the data available and a visit to the sites. These hydroschemes are located in the Namosi and Naitasiri
Province in Viti Levu and in the Taveuni Island.
A Namosi Province
Wairokodra
Waivaka
Waisoi
Waivutulevu
Namado
Wainikovu
B Naitasiri Province
Waimanu
C Taveuni
Somosomo
These schemes will be briefly described and compared in the present section. A more detailed description
and analysis of the various schemes is available in the following section.
3.1.
PRINCIPLES OF HYDROELECTRIC SCHEMES
It is known, and easily verifiable, that the discharge of the rivers in Fiji is very variable at the hourly scale,
with rather low minimum or baseflow.
Except for cases where the power plant is sized to serve the local demand and where the head and the
minimum discharge of the site is sufficient to install a small power plant commensurate with this demand,
this highly variable discharge generally precludes the choice of pure run-of-river schemes.
Indeed, where it is wished to make use of the major part of the river inflow, the schemes will have to
include a reservoir with a minimum size to allow for the storage of the discharge peaks at a scale of a few
days, and will be equipped with generating units able to absorb a discharge in excess of the average of
that of the wet months so as to allow the partial emptying of the reservoir after wet episodes to build some
capacity to store part of the next discharge peak.
A more precise sizing of the required reservoir volume will be determined when more detailed data related
to actual flow histories are known. In the meantime, we have retained the following criteria for the sizing of
the schemes:
–
Active volume of the reservoir equal to a few days (large catchment basins) to one
week (small catchment basins) of inflows during the wettest month of the year (April),
–
Maximum discharge capacity of the power plant equals to 1.25 times the average
discharge of the wettest month.
This arrangement would lead to the capacity to catch a proportion estimated at 90 % of the total runoff, but
results in a plant factor around 0.42. This corresponds to a certain oversizing of the projects, that may be
reduced at the next stage of study, according to the final data acquired during the prefeasibility study.
3.2.
GENERATED ENERGY PLACING
With the characteristics of the schemes retained at this stage, the dependable energy available during the
driest month is in average 22% of the energy produced by the plant running at full power, and the energy
guaranteed 95% of the time is 20% of the that of the plant running at full power, meaning that the power of
the plant is guaranteed at least 5 hours per day during the driest month with a confidence of 95%.
APPENDIX 1 - 5
The main generating plant in Viti Levu is the Monasavu hydroelectric scheme. Its installed capacity is 72
MW, for an average production of 420 GWh, representing respectively… % of the installed capacity and
72% of the energy consumed in the island in 2002.
The storage capacity of the Monasavu reservoir corresponds to 160 GWh, and the plant factor of the
scheme is 0.71, giving to the scheme the capacity to provide base flow throughout the year together with
important peaking capacity.
In these conditions, the capacity of the proposed hydroelectric schemes appears very favourably. They
provide a significant amount of energy throughout the year and offer peaking facilities during the dry
season, which allows large possibilities for optimising the cumulated resource of Monasavu reservoir and
all other energy sources available in the island.
The proposed general arrangement with a reservoir of moderate size based on a week inflow of the wettest
month being sufficient to ensure adequate peaking facilities, it is likely that the evaluation of the result of
coordinated operation of these schemes with the large reservoir Monasavu scheme will show that there is
no reason to increase the size of the reservoirs and associated dams to provide an annual regularisation of
the flow.
3.3.
TRANSMISSION LINES
A. Namosi province
The various schemes envisaged in the Namosi Province includes
–
power stations close to the Waidina river between Namosi and Naseuvu (Wairokodra,
Waivaka and Waisoi, total installed power 11 to 12 MW)
–
power stations close to the Navua river between Nakavika and Nukusere (Namado,
installed power around 7 MW, and Wainikovu, installed power still to be determined,
probably not exceeding 3 MW, but with very uncertain economical attractiveness).
The Waivutulevu site, that may be developed as very small plant only, is considered marginal at this stage.
The geographic position of these power stations allow their connection to a single transmission line to be
installed along the Waidina river, and extended towards west to Namado site. This 16 kV transmission line
will be in 33 kV, and its installation is very easy along a communication road.
The closest connexion of this transmission line to the national grid is to the Suva-Deuba 33 kV transmission
line, through a 18 km long double circuit 33 kV line, with a connexion to this Suva-Deuba line in the vicinity
of Nabukavesi Village, 10 km NW of Navua.
The capacity of the existing line to carry the load remains to be verified, depending on the present and
future load flow of this line and its technical characteristics.
A reinforcement of the capacity of this line over 25 km between Nabukavesi and Suva may become
necessary.
The alternative consisting in a transmission line from Namado to the Deuba power station and switchyard,
requires long portions in the bush, which requires the building and maintenance of a specific construction
track, and resulting much higher installation and maintenance cost.
B. Naitasiri Province
The only scheme envisaged at this stage in Naitasiri Province is the Waimanu scheme, which retains at
this stage a power plant with an installed power evaluated at 3 MW. The power station is envisaged to be
placed on the Waimanu river, on the upstream branch of the large oxbow which lays 14 km east of the
confluence of the river with the Rewa river.
Subject to verification, it is probably possible to connect the power plant to the line that feeds the pumping
station set on the Waimanu river in Koroi road, or to find a suitable connecting point in the area. The length
of the transmission line would not exceed 10 to 12 km, and the tension would be preferably 33 kV, but 11
kV should be probably acceptable as well.
C. Taveuni Island
The existing grid in Taveuni Island is very small and limited to the Somosomo village area. Furthermore, its
appears to present deficiencies leading to operational problems.
A new grid is to be designed, with the view to connecting all major consumers. The length of the main trunk
line could be some 30 km, all placed along existing roads with easy access.
APPENDIX 1 - 6
4.
PRELIMINARY ECONOMIC EVALUATION
4.1.
UNIT RATES
The unit rates used for this very preliminary evaluation correspond
– for the civil engineering works, to recent global rates observed for the construction of small
hydroelectric schemes in Asia,
– for turbines and generators, to machine costs supplied by specialised manufacturers.
Usual mark-ups for P&G (Preliminary and General, 15%), contingencies and non measured items (20%),
have been included in the preliminary evaluation.
4.2.
PRELIMINARY COSTS
The preliminary costs indicated in the next sections contains P&G, contingencies, and 10% for engineering
and development.
They include as well the part of the transmission line directly related to the scheme, but, for the Namosi
schemes, not the 18 km main trunk to be built along the upper Namosi road.
For the Somosomo scheme, they include 30 km of 33 kV transmission line, but it may be possible, subject
to further studies, to reduce the tension and have a less costly transmission line.
5.
CONCLUSIONS AND RECOMMENDATIONS
There is no doubt that the more efficient schemes are Waisoi and Namado, in Namosi Province, and
Somosomo in Taveuni, subject for this last scheme to the proved existence of sufficient demand.
Waisoi and Namado show, at this stage, similar performance economic, and they both need the common
transmission line trunk along the upper Namosi road to evacuate the produced energy towards the south
coast and the main grid.
It is likely that none of these schemes will be able to support alone the cost of this 18 km long line. It is also
probable that there is some local development advantage to start a transmission line along the Waidina
river towards downstream to feed more villages, as well as to provide energy to the copper mine that may
develop in the upper reach of the Waisoi river.
It makes therefore good sense to include both Namado and Waisoi schemes, together with Somosomo in a
first priority development programme.
The cost of the kWh produced by these two schemes appear at this stage slightly above that of the energy
produced by the wind farm indicated in the FEA Annual Report of 2002. But it must be stressed that:
–
The cost indicated in the present report is very preliminary. It is based on international
contracted works, and includes large provisions for contingencies, development
engineering and other costs,
–
The energy produced by the hydro schemes is likely to be guaranteed at certain time of
the day, all along the year, which is not the case of wind energy,
–
The hypothesis for the determination of the runoff are thought to be conservative, and
there is still room for the optimisation of the schemes, the adjustment of the generating
equipment and dam gates etc..
APPENDIX 1 - 7
DESCRIPTION OF THE HYDROSCHEMES
A.
Namosi Province
Wairokodra
Waivaka
Waisoi
Waivutulevu
Namado
Wainikovu
B.
Naitasiri Province
Waimanu
C.
Taveuni
Somosomo
APPENDIX 1 - 8
WAIROKODRA
Wairokodra scheme is installed on the Wairokodra creek, a tributary of the Waidina river, which joins the
main river 500 m downstream of Narukunibua village.
The catchment basin is small, and covers an area of 5 25 km², that can be extended to 6.25 km² by adding
the catchment of the Wainitunikadua creek, which joins the Wairokodra creek slightly downstream of the
possible intake structure. With an average rainfall of 4 000 mm per year, the 6.25 km² catchment can
provide an average discharge estimated at 0.5 m3/s.
The scheme makes use of a 1 km long flat portion of the valley upstream of a steep gorge, where it is
possible to arrange a small reservoir, and of a 230 m drop over a 1.7 km long reach of the creek.
The sites provisionally selected to install the intake structure and dam is in the vicinity of the bridge on the
upper Namosi road that crosses the Wairokodra river, and the powerhouse is located at the outlet of the
gorge, at the beginning of the last 600 m reach of the river course, which is with a moderate slope until the
crossing of the lower Namosi road and the confluence with the river.
HYDROLOGICAL DATA
1.
RUNOFF
1.1.
Wairokodra Catchment Basin
Wairokodra Annual Rainfall
Rainfall
6.25
4000
km²
Mm
Runoff
January
February
March
April
May
June
July
August
September
October
November
December
Mm
436
403
502
509
324
225
185
185
258
271
350
350
Mm
281
268
367
397
229
140
95
76
140
136
201
192
M3/s
0.66
0.69
0.86
0.96
0.53
0.34
0.22
0.18
0.34
0.32
0.49
0.45
Mm3
1.759
1.677
2.297
2.482
1.431
0.874
0.595
0.476
0.874
0.850
1.259
1.203
Total
4000
2524
0.50
15.775
1.2.
FLOODS
Cyclonic conditions similar to those retained for the Monasavu dam would lead to a 114 m3/s peak flood on
the 5.25 km² catchment basin of the Wairokodra dam.
APPENDIX 1 - 9
GEOLOGICAL CONDITIONS
2.
The dam site and Wairokodra creek are located in the Namosi Andesite formation.
The volcanics are relatively fresh and unweathered with minor fracturing. Soil covers is 1 to 2 m thick with
jungle cover.
Weakly chlorite (propylitic) altered hornblende porphyries outcrops at the dam site in upper Wairokodra
creek.
The site is considered adequate for the construction of the dam and for the possible tunnelling works
anticipated west of the Wairokodra creek.
A porphyry copper resource occurs immediately upstream of the dam site at Wainikatam in flat laying
grasslands, and is the subject of the Namosi Special Prospecting License held by Nittetsu Mining Company
of Japan. The resource is however considered to be of marginal importance, and the decision to proceed
with its exploitation appears remote.
3.
PRINCIPLE AND SIZING OF THE SCHEME
Based on the characteristics of the site, the scheme will include a low dam, sized to create a reservoir
sufficient to catch the majority of the inflows, a waterway which shall consist preferably of a tunnel driven
through the mountain range on the west side of the creek gorge and of a surface penstock, and a power
plant installed on the left bank of the lower reach of the creek, which is gently sloping over the last 700 m
upstream of its confluence with the Waidina river.
In an endeavour to maintain the cost of the dam as low as possible, we shall limit the volume of the
reservoir to a reasonable minimum, with the aim of storing the peaks of usual micro-floods, without
attempting to provide any interseasonal regularisation.
In the absence of detailed discharge or runoff data, we have retained to size the active reservoir for the
discharge corresponding to one week of the wettest month, i.e around 0.6 Mm3.
To allow the reservoir to act as a flood damping structure, the power plant must be sized to drain the
reservoir with a discharge capacity higher than the average inflow of the wettest month, say 25 % more,
which gives a discharge capacity of 1.20 m3/s.
For a reservoir Full Supply Level around elevation 315, and a restitution around elevation 80,
corresponding to a maximum gross head of 235 m, the installed power will be some 2.4 MW, and will be
able to generate an average of 7.6 GWh per year.
3.1.
DAM
The location of the dam will be best if
–
It is in a narrow place, so as to limit the length of the dam,
–
It creates a significant reservoir with limited head, so has to limit the height of the dam.
The observation of the contour line on the 1:50 000 topo map indicates such a configuration just
downstream of the existing bridge on the Namosi road.
A cursory evaluation of the volume capacity of the reservoir upstream of the dam site leads to a provisional
setting of the reservoir at elevation 315, 5 to 7 m above the level of the Namosi road bridge deck, and a
maximum height of the dam above the foundation of say 12 to 14 m.
It is anticipated that the reservoir will be operated as well as a desanding basin, which avoids the
construction of a specific desanding/desilting basin in the waterway.
3.1.1.
SERVICES PROVIDED BY THE DAM
The dam must be designed so as to ensure the following services:
–
Retaining structure, to create the reservoir required for the proper operation of the
scheme,
–
Bottom outlet, to allow the flushing of the reservoir, that will be operated also as a
desanding basin,
–
Spillway to allow the routing of the extreme floods without submersion of the dam.
3.1.2.
DAM STRUCTURE
APPENDIX 1 - 10
The dam will include a central block fitted with the bottom outlet and spillway, and two lateral
embankments. These embankments are anticipated to be of rockfill type, with upstream concrete facing, for
which part of the rockfill may come from the excavation of he headrace tunnel.
The bottom outlet must be sized to allow the routing of the annual flood at low level. An opening slightly
smaller than that of the existing bridge will be sufficient, and a set of three 3 m² sector gates would be
adequate.
The spillway will consist in 15 m long crest section, able to route the extreme 114 m3/s flood with a
reservoir surelevation of 2.3 m.
A short stilling basin is to be provided, which supposes that the dam in founded on reasonably solid rock.
Alternatively, the dam can be built as a RCC (Roller Compacted Concrete) structure.
3.2.
WATERWAY
A pressure penstock installed between the dam and the power plant would have a diameter of
approximately 0.80 m to ensure a minimum stability to allow a reasonable participation of the plant to the
frequency control of the grid.
It seems not practical to consider the installation of such penstocks in the river valley, which is very deep,
shows steep sides, is obstructed by huge boulders, and where access appears very difficult to arrange.
A better option is to consider the driving of a pressure tunnel between the dam and the slope which
dominates the power plant site, and restrict the surface penstock to the last portion of the waterway, in the
slope which dominates the last 700 m long moderately sloping reach of the Wairokodra creek.
The tunnel, which will be 1300 m long, will be built with the minimum section allowing the execution of the
underground excavation, say 1.9 x 2.20 m, to allow for a section of 1.5 x 1.8 in the reaches requiring the
placing of a cast in situ concrete lining.
The penstock will be placed over the slope which dominates the power plant site, perpendicular to the
contour lines, so as not to be intersected by surface water. It will be 400 m long with a 600 mm diameter.
Calculations show that, with the selected dimensions, and provided that the closure time of the Pelton
turbine nozzles is not shorter than 20 seconds, there is no need for a surge chamber.
3.3.
POWER PLANT
The power plant will be located at the extremity of the last and moderately sloping reach of the
Wairokondra creek, 600 m upstream of the existing bridge on the Namosi Road, on the left side of the
creek.
3.3.1.
EQUIPMENT
The plant will be equipped with either one 2.4 MW or two 1.2 MW two jet horizontal Pelton turbines and
associated annex and control equipment.
The Pelton wheels will be placed well above (minimum 2 m) the flood level of the Wairokodra creek.
3.3.2.
STRUCTURE
The powerplant structure will include massive foundations for the installation of the Pelton turbine(s) and
generator(s), and standard superstructures holding a 6 tons gantry crane.
The surface of the power plant will be around 140 m², sufficient to house the two generating units, the
control panels and other services, as well as an erecting bay.
4.
ACCESS ROADS
Suitable access roads exist in the vicinity of the various structures of the scheme.
Beyond various site tracks, the only road to build will be
–
the 600 m long road to the powerplant, in flatish and easy terrain,
–
an access track from the powerplant to the downstream portal of the tunnel (say 1200
to 1500 m from el. 80 to 240, in steep grassed residual soil).
APPENDIX 1 - 11
5.
TRANSMISSION LINE
The transmission line will be a 33 kV line, from the extremity of the upper Namosi road to the Wairokodra
power plant, length 750 m, in easy terrain.
6.
PRELIMINARY EVALUATION
Maximum Gross Head
Maximum plant discharge
Installed capacity
Average Annual Energy Production
Preliminary cost evaluation
235 m
1.20 m3/s
2.4 MW
7.6 GWh
7.1 M US$
APPENDIX 1 - 12
WAIVAKA
Wavaka scheme is installed on the Waivaka creek, a tributary of the Waidina river, which joins the main
river a few hundred meters downstream of WaiNarukunibua village.
The catchment basin is rather small, and covers an area of 12.5 km², two times that of Wairokondra
scheme. With an average rainfall of 4 100 mm per year, the catchment can provide an average discharge
estimated at 1.04 m3/s.
The scheme makes use of a 1.5 km long flat portion of the valley upstream of a steep gorge, where it is
possible to arrange a small reservoir, and of a 200 m drop over a 2.5 km long reach of the creek.
The sites provisionally selected to install the intake structure and dam is the inlet of the gorge, in a bend of
the stream slightly downstream of the confluence of a small creek on the left bank, and the powerhouse is
located on the right bank of the Waidina river, in the vicinity of the Waivaka suspension bridge.
HYDROLOGICAL DATA
1.
RUNOFF
1.1.
Waivaka Catchment Basin
Waivaka Annual Rainfall
12.5
4100
Rainfall
km²
Mm
Runoff
January
February
March
April
May
June
July
August
September
October
November
December
Mm
447
413
515
522
332
230
190
190
264
278
359
359
Mm
292
278
380
410
237
145
100
81
146
143
210
201
m3/s
1.36
1.44
1.77
1.98
1.11
0.70
0.47
0.38
0.71
0.67
1.01
0.94
Mm3
3.653
3.480
4.751
5.123
2.963
1.818
1.247
1.009
1.829
1.786
2.627
2.515
Total
4100
2624
1.04
32.8
1.2.
FLOODS
the 12.5 km² catchment basin of the Waivaka dam.
APPENDIX 1 - 13
2.
East west trending hornblende porphyries and associated porphyry copper mineralisation occur in the
headwaters of Waivaka creek. Associated propylitic alteration envelopes the deposit. Further downstream
in the area outlined for hydro development Namosite andesite flows are cut by a major east west fault 2.2
kilometres south of Waivaka village. Competent fractured Wainimala basalts and agglomerates extend to
the junction.
Geological conditions are generally similar to those prevailing for the Wairokodra scheme. They are
considered adequate for the development of the hydraulic structures and underground works envisaged for
the Waivaka scheme.
As for Wainikova scheme, copper resource occurs immediately upstream of the dam site in flat laying
grasslands and above, and is the subject of the Namosi Special Prospecting License held by Nittetsu
Mining Company of Japan. As for Wairokodra area, the resource is considered to be of marginal
importance, and the decision to proceed with its exploitation appears remote.
3.
Rationales for the sizing of the scheme are similar to those developed for Wairokodra scheme.
through the mountain range on the west side of the creek gorge and of a surface penstock, and a power
plant installed on the right bank of the Waidina river slightly upstream of the Waivaka village.
Solutions with a shorter tunnel and a power plant installed more upstream in the last reach of the Waivaka
creek would have been possible, either with a power plant installed one km U/S of the Namosi road bridge,
with a saving of 600 m of tunnel length but at a cost of a loss of 50 m of hydraulic gross head and with a
difficult access to the plant, or with a power plant installed a few hundred meters upstream of the Namosi
road bridge, with a small saving on the tunnel length, but at a cost of a longer penstock and a loss of more
than 10 m on the gross hydraulic head. These alternatives do not appear to present definite advantages
and have not been considered further at this stage.
As for Wairokodra scheme, we shall limit the volume of the reservoir to a reasonable minimum, with the
aim of storing the peaks of usual micro-floods, without attempting to provide any interseasonal
regularisation. We have therefore have retained to size the active reservoir for the discharge corresponding
to one week of the wettest month, i.e around 1.2 Mm3.
Similarly, the power plant has been sized to drain the reservoir with a discharge capacity of 2.5 m3/s, 25%
larger than the average inflow of the wettest month.
3.1.
DAM
The observation of the contour line on the 1:50 000 topo map indicates a favourable configuration just
downstream of the confluence of a small creek on the left bank, around elevation 250. A visit of the area
confirmed the possibilities of the site.
setting of the reservoir at elevation 250, between 5 and 8 m above the level of the alluvial flat that can be
observed upstream of the entrance of the gorge.
3.1.1.
The dam must be designed in a similar manner and to ensure the same functions than the Wairokodra
dam, i.e.:
–
scheme,
–
desanding basin,
APPENDIX 1 - 14
–
3.1.2.
DAM STRUCTURE
embankments, all similar to the Wairokodra dam.
The bottom outlet must be sized to allow the routing of the annual flood at low level, so as to be able to
flush regularly the sediment that will settle in the reservoir. A set of three 5 m² sector gates would be
sufficient for this function.
The spillway will consist in a 20 m long crest section, able to route the extreme 220 m3/s flood with a 3 m
reservoir surelevation. A short stilling basin is placed downstream of the spillway, which supposes that the
river bed is made of competent rock.
3.2.
WATERWAY
The option retained at this stage considers the driving of a pressure tunnel between the dam and the slope
which dominates the power plant site, and the installation of a surface penstock in the slope on the right
bank of the Waidina river, just south of Waivaka village.
The tunnel will be 2 250 m long, and will be excavated, as for the Wairokodra tunnel, with the minimum 4.2
m² section, with concrete or shotcrete lining as required by the quality of the rock.
The penstock will be placed over the slope which dominates the Waidina river south of Waivaka village,
perpendicular to the contour lines, so as not to be intersected by surface water. It will be 300 m long with a
900 mm diameter.
The length of waterways together with the selection of reaction turbines require the presence of a surge
chamber to be installed close to the junction between the headrace tunnel and the penstock.
3.3.
POWER PLANT
The power plant will be located on the right bank of the Waidina river, in front of Waivaka village, in the
vicinity of the existing suspension bridge.
3.3.1.
EQUIPMENT
The plant will be equipped with two 2.1 MW horizontal Francis turbines and associated annex and control
equipment.
The turbines will be placed above the normal level of the Waidina river, to limit the importance of the
protection against flooding.
3.3.2.
STRUCTURE
The powerplant structure will include massive foundations for the installation of the two Francis turbines
and generators, and standard superstructures holding a 10 tons gantry crane.
4.
ACCESS ROAD
Access to the Power Plant is easy from the Namosi road, and requires no more than a few hundred meters
of new road in easy terrain.
Access to the tunnel D/S portal will be from the slopes dominating the left bank of the D/S reach of the
Waivaka creek (say 1000 to 1200 m from el. 80 to 200, in steep grassed residual soil).
Access to the dam and tunnel inlet portal is more difficult. Two possibilities can be considered and
investigated:
–
The use of the existing logging road starting from the upper Namosi road, upstream of
the dam site retained for the Wairokodra scheme, which is traced and opened down to
the south side of the Wainavuga creek, say 1 to 1.5 km from the retained dam side as
the crow flies,
APPENDIX 1 - 15
Another logging road, as shown on the 1/50 000 scale aerial photos of the area, which
arrives 2 km east of the site, coming from the Waisomo basin. There is also a trace of
an ancient logging track a few hundred meters upstream of the dam location, on the
right bank of the Waivaka creek. It is likely that these two tracks have been connected
at some time, and that there is a possibility to reopen the route with moderate works.
We shall retain, for the evaluation of the access road works, 3 km of heavy road rehabilitation works, and 3
km of new roads.
–
5.
TRANSMISSION LINE
The transmission line will be a 33 kV line, from the start of the Wairokodra branch to the Waivaka plant.
This 2.5 km long transmission line will be installed along an existing road and in flat plain.
6.
Maximum Gross Head
Installed capacity
200 m
2.5 m3/s
4.2 MW
13.5 GWh
11.6 M US$
APPENDIX 1 - 16
WAISOI
The Waisoi scheme is installed on the downstream reach of the Waisoi river, with an intake located 2.5 km
upstream of its confluence with the Waidina river. It exploits a 16.5 km² catchment that can provide an
average inflow estimated at 1.5 m3/s, and makes use of a 2 km long flat portion of the valley between the
intake site and the Waisoi Exploration Camp site, where it is possible to arrange a small reservoir, and of a
160 m drop over a 1.5 km long reach of the river.
The sites provisionally selected to install the intake structure and dam and the powerhouse are relatively
easily accessible from existing logging tracks.
HYDROLOGICAL DATA
1.
1.1.
INFLOW
Waisoi Catchment Basin
Waisoi Annual Rainfall
16.5
4400
Rainfall
Km²
Mm
Runoff
January
February
March
April
May
June
July
August
September
October
November
December
Mm
480
444
553
560
356
247
204
204
284
298
385
385
Mm
325
309
418
448
261
162
114
95
166
163
236
227
m3/s
2.00
2.11
2.57
2.85
1.61
1.03
0.70
0.58
1.05
1.01
1.51
1.40
Mm3
5.363
5.093
6.893
7.392
4.313
2.678
1.875
1.562
2.733
2.693
3.902
3.753
Total
4400
2924
1.53
48.246
1.2.
FLOODS
the 16.5 km² catchment basin of the Waisoi dam.
2.
Waisoi creek is located near the centre of the stratavolcano and flows east through the exploration camp to
its junction with the Waidina river. The proposed scheme occurs immediately east of the main copper
deposit at Waisoi, predominantly within basalt and basaltic agglomerates of the basement Wainimala
Group. Narrow quartz porphyry diorite dykes cut the creek along with andesite dykes near the junction.
Prominent clay alteration occurs at the base of the hill where the road is closest to the Waisoi creek. The
APPENDIX 1 - 17
Wainimala rocks are fractured but competent with a number of waterfalls and boulder chokes between the
camp and junction.
The copper resource which occurs immediately upstream of the dam site in the Waisoi catchment, is also
the subject of the Namosi Special Prospecting License held by Nittetsu Mining Company of Japan. The
resource is considered to be more economically attractive than those investigated in the Wairokodra and
Waivaka catchment. The decision to proceed with its exploitation is still pending, but, subject to further
verifications, the location of the deposits might not interfere with the scheme.
Geological conditions are considered adequate at this stage for the development of the hydraulic structures
and underground works envisaged for the Waisoi.
3.
Rationales for the sizing of the scheme are similar to those developed for Wairokodra and Waivaka
schemes.
through the mountain range on the northern side of the creek and of a surface penstock, and a power plant
installed on the left bank of the Waisoi river 800 m upstream of its confluence with the Waidina river, 3 km
downstream of Naivaka village.
As for Wairokodra and Waivaka schemes, we shall limit the volume of the reservoir to store the discharge
corresponding to one week of the wettest month, i.e around 1.7 Mm3.
Similarly, the power plant has been sized to drain the reservoir with a discharge capacity of 3.5 m3/s, 25%
larger than the average inflow of the wettest month.
3.1.
DAM
The observation of the contour line on the 1:50 000 topo map indicates a favourable configuration where
the track to the Waisoi Exploration Camp Site gets close to the river, around elevation 220.
setting of the reservoir at elevation 230, between 10 and 12 m above the level of the alluvial flat that can be
observed upstream of this site.
3.1.1.
The dam must be designed in a similar manner and to ensure the same functions than the Wairokodra and
Waivaka dams, i.e.:
–
scheme,
–
desanding basin,
–
3.1.2.
DAM STRUCTURE
embankments, similar to Wairokodra and Waivaka dams.
The bottom outlet must be sized to allow the routing of the annual flood at low level. A set of three 6 m²
gates would be sufficient for this function.
The spillway will consist in a 25 m long crest section, able to route the extreme 270 m3/s flood with a 3 m
reservoir surelevation. A short stilling basin is placed downstream of the spillway, which supposes that the
river bed is made of competent rock.
APPENDIX 1 - 18
3.2.
WATERWAY
The option retained at this stage considers the driving of a pressure tunnel in the hill range running
alongside the left bank of the river, and the installation of a surface penstock in the slope that dominates
the flat grounds that border the left bank of the downstream reach of the river before its confluence with the
Waidina river..
The tunnel will be 1 400 m long, and will be excavated, as for the Wairokodra and Waivaka tunnels, with
the minimum 4.2 m² section, with concrete or shotcrete lining as required by the quality of the rock.
The penstock will be placed over the slope which dominates the Waidina river south of Waivaka village,
perpendicular to the contour lines, so as not to be intersected by surface water. It will be 300 m long with a
900 mm diameter.
As for Waivaka scheme, the length of waterways together with the selection of reaction turbines require the
presence of a surge chamber to be installed close to the junction between the headrace tunnel and the
penstock.
3.3.
POWER PLANT
The power plant will be located on the left bank of the Waisoi river, in front of Waivaka village, 900 m
upstream of its confluence with the Waidina river.
3.3.1.
EQUIPMENT
The plant will be equipped in principle with two 2.45 MW horizontal Francis turbines and associated annex
and control equipment.
The Francis turbines be placed well above the level of the Waisoi river, so as to limit the importance of the
protection against the floods.
3.3.2.
STRUCTURE
The powerplant structure will include massive foundations for the installation of the two turbines and
generators, and standard superstructures holding a 20 tons gantry crane.
4.
ACCESS ROAD
Access to the Scheme is easy from the track built to give access to the Waisai Exploration Camp Site.
The track lays close to the river in the vicinity of the dam site, but is to be shifted to stay higher than the
reservoir created by the dam.
Access to power house requires the construction of a one km long road in relatively easy terrain, but
requires the construction of a bridge over the Waisoi river.
Access to the downstream portal of the tunnel requires the construction of track from power house access
track in the left bank of the Waisoi river, say 1000 to 1200 m from el. 50 to 180, in moderately sloping
terrain.
5.
TRANSMISSION LINE
The transmission line will be a 33 kV line, from the Waivaka switchyard to the Waisoi plant. This 3.5 km
long transmission line will be installed for a part along an existing road in flat plain and across a small in
more sloppy ground.
6.
Maximum Gross Head
165 m
3.5 m3/s
APPENDIX 1 - 19
Installed capacity
4.9 MW
16.3 GWh
11.0 M US$
APPENDIX 1 - 20
WAILUTULEVU
The Wailutulevu scheme is located on the Wailutulevu creek, the main tributary of the upper reach of the
Waidina River.
The 10 km² catchment basin, slightly smaller than the Waivaka catchment, provides an average discharge
of 0.77 m3/s.
The Waivutulevu gorge is very deep, with difficult access, and no easy access from the plateau to the
possible location of a water intake appears to be available.
The head between the entrance of the gorge and the Waidina valley does not exceed 80 to 100 m.
HYDROLOGICAL DATA
1.
RUNOFF
1.1.
Waivutulevu Catchment Basin
Waivutulevu Annual Rainfall
10
3900
Rainfall
Runoff
km²
mm
January
February
March
April
May
June
July
August
September
October
November
December
Mm
425
393
490
496
316
219
180
180
251
264
342
342
Mm
270
258
355
384
221
134
90
71
133
129
193
184
m3/s
1.01
1.07
1.33
1.48
0.82
0.52
0.34
0.27
0.51
0.48
0.74
0.69
Mm3
2.705
2.582
3.549
3.844
2.209
1.342
0.905
0.715
1.334
1.293
1.927
1.837
Total
3900
2424
0.77
24.24
1.2.
FLOODS
the 10 km² catchment basin of the Waivutulevu scheme.
2.
Wailutulevu creek flows south and is located 1.3 kilometres west of Namosi village. It occurrs near the rim
of the stratavolcano and cuts the outer Korobasabasaga tephra layers. The creek is extremely rugged and
full of very large pyroclastic boulders making traversing difficult. Three major east west trending faults cut
the creek forming the boundary between Namosi andesite flows downstream and hornblende porphyries
APPENDIX 1 - 21
upstream. The hornblende porphyry trends east west and is the western extension of the Waivaka copper
deposit. Propylite alteration surrounds the porphyry while argillic alteration occurrs within the intrusive.
3.
POSSIBLE SCHEME PRINCIPLE
The observation of the 1/50 000 scale topographical map does not reveal the presence of a proper dam
site able to store significant amount of water with reasonable height. This means that it will be difficult to
create a reservoir allowing the dampening of the river inflow, leading to poor flow recovery, unless the
capacity of the plant is widely increased.
The scheme suffers also other drawbacks:
–
The available head between the entrance of the gorge and the Waidina river valley does
not exceed 80 to 100 m,
–
The access to the possible intake site is very awkward, no reasonable access being
available in the headwater of the Wailutulevu creek,
–
The development of the scheme requires a 600 m long headrace tunnel, unless a
penstock is placed in the creek itself, which would not be easy.
All these difficulties will lead to an expensive set up of the scheme for small installed power and uncertain
production.
It is recommended not to include this scheme is the priority development programme, and to review its
feasibility in the light of
–
better hydrological information (in particular the sustained low flow during the dry
season),
–
the possibility to place a small penstock in the banks of the gorge. For this, field
investigations could be undertaken by a geologist or a civil engineer, with the view to
recognising a layout reasonably accessible, where a narrow track can be traced with
moderate transverse slope.
If it is possible to find such a route and if a sustainable discharge of 200 l/s can be guaranteed, the 80 m
gross head can allow to install a 120 kW generating set with a small action turbine.
APPENDIX 1 - 22
NAMADO
The Namado hydroscheme scheme is located on the Wainikoroiluva river, in the Mado gorge 1.5 km east
of the village of Nakavika. It exploits the 25 m drop between the upstream part of the gorge and the large
oxbow of the river which stands directly south of Nakavika.
The catchment basin is relatively extensive, and covers an area of 123 km² where the average rainfall is
slightly more than 3700 mm. This catchment provides an average discharge of 8.8 m3/s
HYDROLOGICAL DATA
1.
RUNOFF
1.1.
Namado Catchment Basin
Namado Average Annual Rainfall
Rainfall
123
3736
km²
Mm
Runoff
January
February
March
April
May
June
July
August
September
October
November
December
Mm
408
377
469
475
303
210
173
173
241
253
327
327
Mm
253
242
334
363
208
125
83
64
123
118
178
169
m3/s
11.60
12.29
15.35
17.25
9.53
5.93
3.81
2.93
5.83
5.43
8.46
7.77
Mm3
31.065
29.728
41.121
44.709
25.533
15.370
10.197
7.860
15.108
14.537
21.929
20.822
Total
3736
2260
8.81
277.98
1.2.
FLOODS
Cyclonic conditions similar to those retained for the Monasavu dam would lead to a 1250 m3/s peak flood
on the 123 km² catchment basin of the Namado dam.
2.
The Mado deep gorge is formed along a major fault trending south east, where Navua mudstones abut
Namosi andesites. The fault is however not active and shows no clay alteration or fracturing.
The andesites are competent and weakly weathered.
Further to the east, another gorge occurs, where quartz eye porphyries outcrop. These porphyries are
more weathered and less competent than the andesites of the Mado gorge, but still widely sufficient to
provide excellent foundation conditions for a concrete dam.
APPENDIX 1 - 23
PRINCIPLE OF THE SCHEME
3.
The Wainikoroiluva river shows a drop of 25 meters between the upstream gorge and the pools which form
downstream of the Mado deep gorge outlet.
This scheme includes a 2 km long reservoir, where it is possible to accommodate an active storage volume
of 2.5 Mm3 between elevation 75 and 85, which represents 2 days of storage of the average inflow of the
wettest month.
To allow the reservoir to act as a flood damping structure, the power plant must be sized to drain the
reservoir with a discharge capacity higher than the average inflow of the wettest month, say 25 % more,
which gives a discharge capacity of 21.5 m3/s.
For a reservoir Full Supply Level around elevation 85, and a restitution around elevation 42, corresponding
to an average gross head of 43 m, the installed power will be some 7.7 MW, with an energy production of
24 GWh for 90% of the inflow.
3.1.
DAM
Two options can be envisaged for the location of the dam,
–
The Mado Deep Gorge itself (D/S site),
–
The longer gorge which lays 500 m upstream of the Mado Deep Gorge (U/S site).
The topographical survey shows a difference of 15 m between the possible dam foundation levels of the
upstream and the downstream sites, but the upstream site requires a 500 m longer power tunnel. Pending
further evaluation and comparison of both options, we retain at this stage the upstream gorge, where the
installation of the dam appears easier.
At this site, the width of the dam will be around 20 m at foundation level, and 120 m 25 m above the
foundation.
As the foundation quality is good for a concrete dam, we retain this type of structure with high capacity
bottom outlets to flush the sediments that will settle in the reservoir, and an overflow spillway sized to route
the hurricane discharge.
For the 30 m wide crest spillway that the site can accommodate, the routing of the flood discharge requires
a head of 8 m. In order not to increase the height of the dam excessively, we have considered to include in
the spillway arrangement a 3 m high flap gate that may be designed in such a way as to regulate
automatically the reservoir level during the routing of the floods until the flap gate is completely lowered
down.
3.2.
WATERWAY
The waterways comprise a water intake structure located on the right bank of the river just upstream of the
dam, a 950 m long tunnel with a minimum section of 6.5 m² where lined, daylighting at the location of the
power plant, 500 m downstream of the outlet of the Mado gorge.
Alternatively, the tunnel can be made of two small reaches with a surface pressure conduit arranged in the
right bank of the amphitheatre which exists just upstream of the Mado gorge.
3.3.
POWER PLANT
The power plant is installed in the right bank of the Wainikoroiluva river, 500 m downstream of the outlet of
the Mado gorge, where it appears more gentle to accommodate the 400 m² power station.
The plant is sized to house two Francis generating units, that are set 2 to 3 m above the normal level of the
river, above the level expected to be reached by the floods.
The road to the village of Nakavika dominates the river bank, providing an easy access to the site of the
plant.
4.
TRANSMISSION LINE
The transmission line will be a 33 kV line, from the extremity of the upper Namosi road the Namado plant
switchyard. This 10 km long transmission line will be installed along an existing road in easy terrain.
APPENDIX 1 - 24
5.
Maximum Gross Head
Installed capacity
44 m
21.5 m3/s
7.7 MW
24 GWh
17.5 M US$
APPENDIX 1 - 25
WAINIKOVU
Wainikovu scheme is to be developed on the Wainikovu river, in the narrow gorge which stands 2.5 km
upstream of its confluence with the Navua River.
The site lies 3 km east of Nukusere Village, but its access is awkward, and requires the construction of 3
km long access road is bush and hilly terrain to the north bank of the gorge, and a few more km to have
access to the left bank of the river.
HYDROLOGICAL DATA
1.
RUNOFF
1.1.
Wainikovu Catchment Basin
Wainikovu Annual Rainfall
Rainfall
70
3580
km²
Mm
Runoff
January
February
March
April
May
June
July
August
September
October
November
December
mm
391
361
450
456
290
201
166
166
231
243
314
314
Mm
236
226
315
344
195
116
76
57
113
108
165
156
m3/s
6.16
6.54
8.23
9.28
5.10
3.14
1.98
1.48
3.05
2.81
4.45
4.07
Mm3
16.488
15.817
22.030
24.055
13.647
8.133
5.298
3.968
7.894
7.533
11.523
10.893
Total
3580
2104
4.67
147.28
1.2.
FLOODS
the 70 km² catchment basin of the Wainikovu dam.
Construction flood are to be properly evaluated, but could be in the range of 200 to 300 m3/s.
2.
The dam site stands in the Wainikovu sandstone and conglomerate units. These formations are relatively
fresh and stand up as competent cliffs.
The conglomerates contain basalt clasts to 5 cm in diameter with interbedded grits. The bedding planes are
flat lying and the units average 30 to 40 cm thick.
APPENDIX 1 - 26
3.
At the dam site, the sandstone and conglomerate formations form 50 m high cliffs on both sides of the
creek, leaving a 50 m high 10 to 15 m wide gorge.
This gorge could appear as an ideal site to build a dam with a significant height and small concrete volume.
In reality, various aspects of dam construction realities are to be taken into account:
•
The banks and the foundation of the dam structure must be the subject of proper treatment
to provide stiff, stable and watertight support to the dam:
–
The dam will be probably of the cylindrical arch type, and keys of suitable shape are to
be excavated in the cliffs,
–
The foundation needs to be cleaned of all sediments and debris, and will have
probably to be shaped to provide adequate support to the structure,
•
The river must be diverted so as to allow the execution of the works in the river bed:
–
In the present instance, the only feasible way is to drive a tunnel in the left bank. 5 to
10 year recurrence floods of possibly 200 to 300 m3/s would require the construction
of a 5 m diameter tunnel. The difficult access conditions to the gorge itself lead to the
necessity to arrange a 600 m long tunnel that by-passes the gorge.
–
The diversion of the river and the emptying of the dam site require the construction of
a 10 to 12 m high upstream cofferdam, and of a few meters high downstream
cofferdam, together with the drainage by pumping of the space between both
cofferdams,
•
Access must be provided to both banks of the river, and access to the gorge and banks at
the dam site proper will probably require the installation of a cableway,
The 800 m3/s flood discharge must be routed over the dam. This will produce a
surelevation of the reservoir above the level of the spillay by more than 10 m, which is no
problem, but the dissipation of the energy of the falling jet will require.....
Assuming a 40 m high dam, to allow for the surelevation of the reservoir during the routing of the floods,
and with the sizing of the plant at 1.25 times the wettest month average discharge, the installed power will
be around 4 MW.
•
Conclusion/Recommendation :
It is clear that the site deserves attention and that all the works required to develop the Wainikovu scheme
need to be carefully studied. However, given the complexity of the construction of this scheme, the studies
require comprehensive field investigations that have to be carried out in difficult conditions and the
relatively modest production of energy expected, we suggest not to place the Wainkovu scheme in the
priority development programme.
APPENDIX 1 - 27
WAIMANU
The Waimanu scheme is installed on the downstream reach of the Waimanu river, with a dam built
somewhere in the large oxbow located 10 km upstream of the confluence of the river with the Rewa river. It
takes advantage of a 1121 km² catchment that can provide an average inflow estimated at 11.6 m3/s.
The river profile is rather flat in the area, and the whole head of the scheme is to be created by the dam. A
solution with a power plan placed at the extremity of a short tunnel cutting the opening of the oxbow can be
envisaged, and would bring a moderate additional fall of possibly 1 to 2 meters.
HYDROLOGICAL DATA
1.
RUNOFF
1.1.
Waimanu Catchment Basin
Waimanu Average Annual Rainfall
121
4509
km²
mm
Waimanu
Runoff
Rainfall
January
February
March
April
May
June
July
August
September
October
November
December
Mm
492
455
566
574
365
253
209
209
291
306
395
395
mm
337
320
431
462
270
168
119
100
173
171
246
237
m3/s
15.22
15.99
19.49
21.56
12.21
7.86
5.36
4.50
8.06
7.71
11.48
10.71
Mm3
40.764
38.675
52.202
55.887
32.693
20.376
14.360
12.061
20.892
20.639
29.766
28.677
Total
4509
3033
11.64
366.993
1.2.
FLOODS
Cyclonic conditions similar to those retained for the Monasavu dam would lead to a 1 200 m3/s peak flood
on the 121 km² catchment basin of the Waimanu dam.
2.
At the dam site, on the west part of a large oxbow, the Waimanu river trends north up to a major bend
where the road meets the river. Further west, the river trends south west. Quartz eye rhyolites, generally
APPENDIX 1 - 28
weakly fractured, outcrops on both sides of the river at the dam site, with basalts outcropping to the north
and forming cap on the ridges. The basalts represent outlier of the Ba basalt plateau to the east.
A major fault trends east north east along the Waimanu river and cuts the ridge south of the dam site.
Further east, the fault trends along the eastern side of the ridge.
Major landslides are associated with the basalts. The slips occur at conjugate faults on the east and west
slopes of the river and are unstable.
Geological conditions of the foundation in the river remain to be assessed, but the depth of sediments is
not considered to be excessive.
3.
The flat profile of the river involves that the majority of the head of the scheme is to be created by the dam.
However, the route of the river with a large oxbow open towards south allows the consideration of two
types of schemes as follows:
–
a solution with a power plant placed alongside of the dam or at the foot of the dam if the
dam is high enough,
–
a solution with a power plant placed at the extremity of a short tunnel cutting the opening
of the oxbow.
The second solution brings a moderate additional fall of possibly 1 to 2 meters, but requires the
construction of a short tunnel. Since this additional head is very small, the advantage of this solution may
appear modest at first glance, but it allows the construction of a simpler dam structure since the power
plant will not be in the river bed.
The final height of the dam is to be determined after an optimisation process. This process cannot be
undertaken at this stage, but, as a result of the very large increase of the cost of the dam when the height
increases, it is likely that it will lead to a dam of relatively modest height.
Likewise, it is not possible to envisage and compare at this stage the various scheme arrangements that
the site allows, and we shall limit this first approach to a reasonable scheme lay out, with low dam and
power plant installed in one side of the dam.
We shall consider also the construction of the power plant and of the overflow section of the dam in two
phases during two successive dry seasons to allow for construction works in half of the river width at a
time.
3.1.
DAM
The location of the dam is to be selected in the upstream branch of the oxbow. A position between the road
and the Wailosilosi creek offers relatively small dam length, but must be chosen so as to avoid the
landslide that can be observed on the right bank.
The river valley is subject to numerous landslides, leading to a high level of sediment transport in the river.
It is therefore necessary to include in the dam a high capacity bottom outlet able to flush the sediments that
will settle in the reservoir.
The interannual regularisation of the flow would require a live reservoir capacity of 68 Mm3, whereas the
capacity corresponding to 25% of the wettest month to dampen the usual flood is only 14 Mm3.
The contour lines of the existing 1/50 000 scale topographic map are not precise enough to give an idea of
the slope of the stretch of river where the dam lays, but local measurements indicate a possible slope of 1
to 1.5 m/km. For an average width of the valley of 150 m at elevation 30, the storage would be 3 to 4 Mm3
per m of storage, and to provide the live volume necessary for the annual regularisation would lead to an
uneconomically high dam. There again, the site conditions call for a run-of-river type of scheme with a few
days live storage.
Because of the requirements to ensure the necessary hydraulic functions, the dam will be almost certainly
a concrete structure including:
–
high capacity bottom outlets sized to route the annual flood at low reservoir level, to allow
for regular flushing so as to permit the use of the reservoir as desanding basin.
–
a free flow spillway, able to route the cyclonic flood over the dam.
Depending of the quality of the river bed, the addition of a proper stilling basin may be necessary to ensure
the stability of the river bed downstream of the dam.
APPENDIX 1 - 29
3.2.
POWER PLANT
The power plant will be placed alongside or just downstream of the dam body, and sized to house two axial
flow turbines, bulb type or S type.
TRANSMISSION LINE
4.
Subject to verification, it is probably possible to connect the power plant to the line that feeds the pumping
station set on the Waimanu river in Koroi road, or to find a suitable connecting point in the area. The length
of the transmission line would not exceed 10 to 12 km, and the tension would be preferably 33 kV, but 11
kV should be probably acceptable as well.
5.
ACCESS
The Waibau road gives access to the north bend of the oxbow, 300 to 500 m north of the dam site. A short
length of road will have to be built in hilly terrain.
6.
Maximum Gross Head
Installed capacity
16 m
27 m3/s
3.2 MW
10.5 GWh
12.3 M US$
APPENDIX 1 - 30
SOMOSOMO
The Somosomo Minihydro Project, which is located on Naibili Creek on the west coast of Taveuni, has
been the subject of successive studies since the sixties, including
–
a Design Study by Beca Worley International in 1986, followed by the preparation of
Tender Documents in 1987 for a scheme including a 350 kW hydraulic generating unit
and back up diesel generating units,
–
a financial, economic and socio-economic study of the project by Gibb-Sinclair Knight in
1994.
The project considered in these studies includes a 350 kW run-of-river high head hydroelectic plant and
two 225 kVA diesel engines that will supplement the hydro generation during the period of low stream flow
and peak demand, as well as during maintenance or forced outage of the hydro plant.
The project was shown to be viable in economical term, with an Economical Internal Rate of Return of
15%, but not financially viable with all the charges considered in the study.
At the time of the study, the annual electicity usage in the area covered by the project was estimated to be
1.02 GWh, for a 24 hour grid supply, with a peak power demand of 480 kW, coresponding to a load factor
of 0.24.
With the installation of new hotel resorts, the level of the electricity demand is considered to be at present
much more than that resultig from the growth rate retained in the economic study of Gibb-Sinclair Knight,
and will continue to grow. This demand could be as high as 1.5 MW, but this figure remains to be confirmed
by proper investigations and study.
The economical conditions for the installation of larger generating facilities appear therefore more favorable
now than anticipated by the previous studies.
1.
PROJECT PRINCIPLE
Considerable information on the project to be developped is available in the existing study reports, that can
be used for the present study.
The project, as presently developped, taps the water from the Naibili Creek at elevation 633. The location
of the water intake appears to be judiciously chosen, where creek turns west towards the west coast of the
Island, and where its slope increases.
The catchment of the creek is small, but the rainfall is extremely high in the area, from 10 m/year over the
Lake Tagimaucia catchment, to 14 m at Des Voeux Peak, south of the lake.
The Lake Tagimaucia and surrounding marshlands occupy the centre of an old volcano crater. The
marshlands and lake drain through a small river which spills over a natural rocky weir located in the south
part of the rocky range that closes the east side of the crater. The spilled flow joins ultimately the Wainisairi
creek which flows towards the east coast of the island. The surface of the crater is around 2 km², but its
catchment covers an area of 4.9 km².
The catchment of the Naibili creek is to the north of the crater and covers an area of 2.5 km².
Measurements of the flow in the Naibili creek and over the Lake Tagimaucia rocky weir are reported in the
table below :
%
100
95
90
80
Daily flow duration
Naibili
Lake
Creek l/s
Tagimaucia
spillage l/s
55
25
84
80
97
130
123
250
Total
l/s
80
164
227
373+
APPENDIX 1 - 31
70
60
50
40
152
183
215
264
250+
250+
250+
250+
402+
433+
465+
514+
The minimum flow of the Naibili Creek is relatively small, with 84 l/s for a 95% guarantee, compared to the
200 l/s that is necessary to produce the objective of 1.5 MW.
It is however relatively easy to increase the hydraulic resource by diverting towards the Naibili Creek part of
the crater catchment. The observation of the discharge spilled over the rocky weir towards the Wainisairi
creek, shows that the instantaneous demand may exceed the total discharge of the system during small
periods. The deficit of flow corresponds to a very small volume of water, that can be easily extracted from
the marshland, either by digging a short canal through the north bank of the crater, towards the
Ndranomath Lake, or by pumping in a well to be dug in the marshland.
This Ndranomath lake, which spills into the major tributary of the Naibili Creek, may constitute an ideal
reserve of water to provide the missing water during peak energy consumption. This will allow a
considerable reduction of the pumping capacity, ad the cost of a small structure to raise slightly the level of
the dam.
Alternatively, the level of the Tagimaucia lake can be raised by adjusting the control level of the rocky weir
with small volume of concrete fill. It is likely that a very modest of the level of the lake will provide the
necessary buffer volume.
2.
COMPONENTS OF THE SCHEME
2.1.
WATER INTAKE
The water intake is located on the Naibili Creek at elevation 633, which provides a gross head of 590 m.
The intake includes a desanding basin. The design is ready for a discharge of 80 l/s, and can be easily
adjusted for the 300 l/s discharge required for a 1.5 MW installed power.
2.2.
PENSTOCK
The conveyance of the water from the water intake to the power plant is made through a 300 mm dia 4200
m long welded steel pipe, with cement mortar or epoxy coating.
By using 360 MPa yield strength pipe for pipes with more than 200 m pressure, the total weight of the
supply is around 300 t.
The penstock will be placed over a sand bed in a trench, which will be eventually backfilled with compacted
soil. The bends will be fixed by concrete anchor blocks.
2.3.
POWER PLANT
The power plant will be installed on the side of the Somosomo creek, probably just above the Somosomo
village. It will be probably developed in stage, to follow the progress of the energy demand.
Several options of equipment are possible. They depend on the predictable growth of the demand, and
must be selected so as to provide the lowest present cost of the project. They must also take into account
the fact that, to convince future customers of the reliability of the supply and assure the viability of the
operation, the availability of the energy must be guaranteed, which implies to have back-up equipment
ready to be put on line in case of programmed maintenance or forced outage of the main units. The most
convenient back-up equipment consists in diesel engine(s) to be installed in close proximity of the
hydroelectric plant.
Options that can be considered and compared may be:
–
The installation in a first phase development of a 500 kW hydro-generating unit, together
with a 500 kW diesel unit, and complete the equipment by a 1 MW hydro-generating unit
when the demand and the distribution network allow it, together with a second 500 kW
back-up diesel generating unit,
APPENDIX 1 - 32
The installation in a first phase development of a 750 kW hydro-generating unit, with a
750 kW back-up diesel unit, and complete the equipment by a second 750 kW hydrogenerating unit when the demand and the distribution network allow it.
For both previous options, the choice between the installation in the first phase of a penstock sized for the
total installed power of the ultimate phase of development or the delayed installation of a second penstock
needs to be analysed.
The final choice is, of course, very dependant of the anticipated energy demand growth rate.
–
With the arrangement envisaged, the hydraulic power plant will be able to produce the energy
corresponding to the installed power 95% of the time. The actual energy produced with be therefore
controlled by the demand.
3.
STUDIES TO BE CARRIED OUT
3.1.
DEMAND STUDY
The study of the demand is to be carried out in a manner similar to that adopted for the Gibb-Sinclair Knight
study, with detailed investigations concerning the potential large consumers.
3.2.
ENVIRONMENT STUDY
The Lake Tagimaucia is ecologically sensitive. It is customary land of Bouma community, living in the
South East of the Island, and not to be beneficiary of the proposed project.
A full Environment Impact Assessment appears to be necessary prior to undertake the development of the
project, to verify that the (small) drainage of the marshland during a limited period of the year, or the small
raising of the Tagimaucia Lake is ecologically and sociologically acceptable.
4.
Maximum Gross Head
590 m
0.305 m3/s
Installed capacity
1.5 MW
According to the demand
6.8 M US$
A large proportion of the cost is for the transmission line.
APPENDIX 1 - 33
DATA TO BE ACQUIRED DURING THE COMING WET AND DRY
SEASONS
1.
1.1.
HYDROLOGICAL DATA
DATA TO BE ACQUIRED FROM THE HYDROLOGICAL DEPARTMENT OF THE MINISTRY OF PUBLIC
WORKS
The following records have been indicated to be available, most of them on an hourly basis (Chief
Hydrologist Richi Raj, meeting on Feb 23)
3) Discharge records:
–
Waynicacau
–
Namosi
–
Waimanu
–
Somosomo creek - Taveuni
4) Rainfall
–
Nasevu
–
Wainicavu
–
Waimanu
–
Wainaboro
–
Nabukaluka
–
Wainivra
–
Des Voeux Peak - Taveuni
Partial records are available only for the Namosi gauging station.
As long as possible records should be obtained, with a minimum of 20 years when they are available.
1.2.
DISCHARGE MEASUREMENTS
It is necessary to proceed with regular and comprehensive measurements of the discharge of some of the
rivers where the development of hydroelectric schemes envisaged, with the view to getting a better
understanding of the hydraulic regime of theses rivers, and particularly
–
the short term variation of discharge, in relation with rain episodes,
–
the base flow during the dry season.
We have selected rivers and location where the measurement was possible without the necessity to build
particular structures, and the measurements will have to cover the next rainy and wet seasons.
1.2.1.
WAIROKODRA, WAIVAKA AND WAILUTULEVU SCHEMES
The measurement of river discharge is relatively easy for these three schemes, where bridges with
characteristics suitable to install accurate flow measurement devices are available.
APPENDIX 1 - 34
Indeed these bridges are of common design, and consist of adjacent concreted arches with flat concrete
apron. It is possible to force the flow into the central arch of the bridges by placing 40 cm high flashboards
across lateral bays and create critical flow conditions in the central bay that allow an accurate
determination of the discharge by measuring the head1 over the concrete base.
The resulting head discharge relationship is indicated in the graph below for 40 cm high flashboards
installed in all except one bays of the bridges.
Such bridges are available at the place of the dam and upstream of its confluence with the Waidina river for
the Wairokodra creek, and upstream of its confluence with the Waidina river only for the Waivaka and
Wailutulevu scheme.
Description of the flashboards
–
The flashboards will be made of 80 mm thick wood boards, placed vertically against
the offset between the discharge bays and the upstream guide walls,
–
The width of the flashboard is around 2.65 m,
–
The top level of the flashboards will be adjusted to be 40 cm above the bridge
concrete apron,
–
The flashboards will be rigidly tied to the concrete so as not to move, vibrate or float
when loaded by water.
Discharge through Bridge
Q m3/s
14.000
12.000
10.000
8.000
5 bay bridge
6.000
4 bay bridge
6 bay bridge
4.000
2.000
0.000
0
0.2
0.4
0.6
0.8
1
Water level above apron (m)
1
The head is the difference between the elevation of the water upstream of the measuring section, or the still water
upstream of the closed sections, and the elevation of the sill of the central section.
APPENDIX 1 - 35
Discharge through Bridge
Small discharges
Q m3/s
2.000
1.800
1.600
1.400
1.200
5 bay bridge
1.000
4 bay bridge
0.800
6 bay bridge
0.600
0.400
0.200
0.000
0
0.1
0.2
0.3
0.4
0.5
0.6
Water level above apron (m)
1.2.2.
NAMADO SCHEME
It is possible to proceed with water level measurement on the Wainikoroiluva river near the village of
Navunikabi.
A river section has been selected to this effect at the downstream limit of Navunikabi village, where a staff
gauge can be sealed in the low rock cliff that exists on the right bank just upstream of the Wainatava Set.
This section has been selected because of its commodity to install a staff gauge in an accessible place, but
it is probably not very stable, and needs to be calibrated from time to time.
Flow velocities are therefore to be measured from time to time at various river discharge conditions.
1.2.3.
MEASUREMENTS PROCEDURES
Taking into account the rapid variations of the discharges to be measured, it is recommended to proceed
with 4 measures per day.
These measures will be made at defined hours, and reported on dedicated log books. The precision of the
measurement will be lower than 1 cm.
For the measurements to be made at the bridges over the Wairokodra, Waivaka and Wailutulevu rivers, the
level will be measured upstream of the bridge, where still water (moderate flow velocity) prevails.
–
1.3.
RAINFALL DATA
Rainfall gage are to be installed and read on a regular basis at:
–
Wairokodra dam site,
–
Wairokodra power plant site
Namado scheme, at the gauging section on the Wainikoroiluva river near the village of
Navunikabi.
1.4.
STAGE DISCHARGE RELATIONSHIP
Obtain the rating curve (stage-discharge relationship) of the Waimanu river at gauging station.
APPENDIX 1 - 36
2.
•
•
TOPOGRAPHICAL DATA TO BE ACQUIRED
Cross section of the Waimanu valley at provisional dam site axis, up to 30 meters
above the river level,
If possible, cross section of the Waikava river at provisional dam site axis, up to 25 m
above the river level.
3.
GEOTECHNICAL DATA
Proceed with the verification of the level of the bedrock in the Waimanu river at retained dam site by jetting
technique as already considered.
The execution of geophysical profiles can be delayed to the next phase of study.
Appendix 2 - i
APPENDIX 2
PREFEASIBILITY STUDY FOR THE ELECTRIFICATION OF ROTUMA
BASED ON LOCALLY PRODUCED COCONUT OIL
December 2005
Prepared by Peter Johnston, REEP Consultant
Appendix 2 - ii
TABLE OF CONTENTS
I.
Project summary.........................................................................................................1
II.
Physical, Demographic and Economic Background .................................................2
III.
The Government Electricity Supply System.............................................................3
A.
Fuel requirements for electricity supply ............................................. 5
B.
‘Urban’ household consumption ....................................................... 5
C.
Government corporation consumption................................................ 5
D. Cost of supply from Ahau government station....................................... 5
IV. Existing Village Electrification ..................................................................................6
V.
Diesel Fuel Supply and Cost.....................................................................................9
VI.
Annual Patterns of Power Use and Growth in Demand ..........................................10
VII.
Rotuma’s Coconut Resource and Coconut Oil Potential........................................11
VIII.
Comments on Economics of Coconut Oil Production in Rotuma..........................12
IX.
Scope of the Project .................................................................................................14
A.
11 kV centralised grid and central power station................................... 14
B.
Biofuel production ....................................................................... 15
C. Managing the enterprise ................................................................ 15
X. Further Project Concept Development......................................................................16
XI.
Supplementary Rotuma Photographs......................................................................17
Appendix 2 - 1
Rotuma Electrification Using Locally Produced Biofuel
I.
Project summary
1. In October 2004, the Coconut
Figure 2 – Rotuma Location Map
Industry Development Authority (CIDA)
recommended Rotuma to the REEP
team as a site for renewable energy
development using coconut oil as a
replacement for diesel fuel for power
generation. However, the Department
of Energy (DoE) did not initially support
the concept, preferring to develop
100% electrification of the island of
Moala by renewable energy through
the REEP. Further investigation in late
2004 indicated that renewable energy
on Moala probably could not be
economically developed to the extent
desired by the DoE. In February 2005,
DoE shifted its support to the CIDAproposed Rotuma biofuel electrification
project. The Steering Committee
approved the concept in February
2005. This late acceptance of the
project, limited availability of fuel use
and electrification data for Rotuma and
the difficulty of accessing the Island all
delayed development of the project
proposal. A site survey by the REEP
Fiji local consultant was carried out in
October 2005 and further data were
gathered between then and December 2005.
Figure 3 – Rotuma from the Air
Photo: Peter Johnston, October 2005
2. The remote island of Rotuma has a small diesel system supplying the
government administrative centre at Ahau and nearby households. There are also
numerous stand-alone generators in villages in seven districts spread fairly evenly
around the island. This project is for the development of a centralised electricity
system that would replace expensive imported diesel fuel, supplied irregularly and
sometimes unreliably, with fuel based on locally produced coconut oil. The project
would include a coconut oil mill and related facilities, a new central diesel plant on the
Appendix 2 - 2
order of 300 kW, and reticulation of supply, probably at 11 kV, around the perimeter
of the island. The transmission line would extend about 32 km in total.1 The project
has been endorsed in principle by the government-owned CIDA, the Office of the
Prime Minister and the Ministry of Finance and Planning (MOFP). It also has the
support of the DoE.
II.
Physical, Demographic and Economic Background
3. Rotuma is Fiji’s most remote island (see Figure 2), 465 km north of the main Fiji
Islands group. It is volcanic, 44 km2 in land area (14 km long by 4.3 km at its widest)
carpeted with lush vegetation, with hills (see Figure 3) reaching 262 metres in height
and abundant coconut trees. Although politically part of Fiji, Rotumans are ethnically
Polynesian. The Rotuman language is unique although Polynesian based. After class
3 (the third grade), students are taught in English, and nearly all Rotumans are at
least bilingual with many also speaking Fijian and Hindi. The population of about
2,400, increasing to 2,600 over the Christmas/New Year’s holiday period, is spread
along the coastline with the hilly interior largely uninhabited. An unpaved road circles
the island (See Figure 4 and supplementary photos2) linking all villages. There are
twice-weekly 2½ hour flights from Fiji’s capital Suva by small turboprop aircraft that
are typically fully booked for freight and passengers. Irregular ocean transport sails
every 4-6 weeks with a 36 hour transit time from Suva to Rotuma.
Figure 4 – Map of Rotuma
1
The transmission line would extend 25 km around the larger eastern part of the island, plus
3 km to reach the main villages on the smaller western bulge (1.6 km to Maftoa and a 1.4 km
branch to Losa) and another 3½-4 km for branches to the three water pumping stations (1.5
km to Motusa, 1 km to Sumi and 1 km to Lepjea). Distances were measured along the roads
and into the interior on a map of scale 1:7920 or 8 inches = 1 mile = 80 chains.
2
Supplementary photographs are annexed as Attachment 1. These illustrate the quality of
roads, village generating systems, typical house wiring, copra drying, fuel storage,
topography, etc. Attachment 2 lists people and organisations contacted.
Appendix 2 - 3
4. In principle, nearly 90% of the island’s population is electrified using numerous
independent diesel generators feeding small underground village grids but often
many of these are not operational, sometimes for long periods. In October 2005,
73% of village households had a functioning electricity system. Service is typically
provided for 4-6 hours each day with periods without service due to lack of fuel or
mechanical problems. In 2004, the island was reportedly without fuel for two months
due to shipping problems and during 2005 there were numerous periods where
power was restricted for both the government system and communities, sometimes
due to lack of funds to purchase fuel. During the October 2005 REEP visit to the
island, it was observed that residents had difficulty in purchasing diesel fuel from
retailers for use in private vehicles.
5. Relative to Fiji’s other outer islands, Rotuma is relatively affluent, with a semiskilled workforce. Rotumans by and large enjoy a comfortable standard of living with
ample food, adequate housing, and an increasing number of household appliances.
There are probably fewer than twenty motorised vehicles on the island, however, and
their number is increasing only slowly. Because of high outward migration to
mainland Fiji for employment, the island’s population has a higher percentage of
children and retired people than that of Fiji overall. There are currently no
restaurants, hotels, cafes, tourist facilities or Internet service on the island. The onceactive cooperative system failed some years ago. There is one commercial piggery
and considerable subsistence fishing. In the past, Rotuma exported oranges to
mainland Fiji but this has long ceased. Copra is the only export commodity of any
significance but this brought less than US$0.2m to the island in 2004.3
6. The lifestyle is supported by a combination of local production, formal
employment (primarily with government agencies) and remittances from family
members who live elsewhere in Fiji or overseas. Although remittances from within Fiji
are not well documented, authorities in Rotuma suggest that at least FJ$430,000
(over US$250,000) was remitted to the island in November and December 2004
alone. In 2004, remittances for the full year exceeded FJ$1.4 million (US$0.8m) or
about US$350 per capita.4
7. There is a government station (postal service, satellite telecommunications,
hospital, administrative centre, school, etc.). Affairs are managed by an elected
council of traditional chiefs, the Rotuma (RIC), with a three year mandate. The RIC
has about 22 members: chiefs and sub-chiefs from all districts plus several Fiji
government officials (the District Officer (DO), agricultural officer, doctor, etc.). The
DO is accountable to the Ministry of Regional Development in Suva. A highly
subsidised Government power system serves the government station and nearby
households, reaching about 10% of the island’s population.
III. The Government Electricity Supply System
8. A small diesel generator and underground distribution system serves the
government complex at Ahau and nearby housing that includes eleven civil servants’
3
In 2004, Rotuma exported 801 tonnes of copra (source: Rotuma agricultural office), at an
average value of FJ$485 per tonne (assuming, as reported by the agents “Three Sisters”,
70% grade F1 at FJ$500 and 30% grade F2 at FJ$450) minus shipping costs of FJ$84/tonne.
As discussed later, the growers earned less.
4
There are no banking facilities on Rotuma. According to sources on the island, FJ$1.4
million is the amount remitted to the island through Western Union during 2004. As Rotumans
bring cash (and food and gifts) when they visit, particularly during Christmas, the actual
amount remitted is considerably higher.
Appendix 2 - 4
quarters, seven private homes and a church at Tieri village 1 km south and another
nine private houses between 0.2-0.8 km to the north. Some government offices have
their own gensets, solar PV power or standby diesel facilities. The government
system normally operates for eight hours daily from 08:00-12:00 and 18:00-22:00.
When there is ample fuel, it also runs from 05:00-08:00. Government generation
facilities are summarised in Table 8. Except where noted, these are diesel based. All
generation except that used for water pumping is at or near the government station
at Ahau. There are three electric water-pumping stations, with the approximate
locations shown in Figure 6. 5
9. Although there is no record of the average or peak load on the government
system, demand is normally the highest in mid-morning when PWD welding
equipment and compressors tend to be used. The RIC garage is used as a general
maintenance facility for the island, with extensive use of power tools, a welder and
compressors. The hospital includes a dental clinic with a small compressor, several
refrigerators and a small (7.5 kW) back-up genset. Although the Post Office shop
serves as a general wholesale / retail outlet and has several big freezers, they are
really only used for several days per month, as frozen goods sell out within 2 or 3
days and ships deliver food only every 4-6 weeks.
Table 8– Government Facilities Electricity Supply Summary
Generating
plant
Comments
Main loads
Government station 1
44 KVA (35.2 kW)
No backup 2
1996 Wilson F6 model P44E 415/240v 3 phase, 1500
rpm.
Govt offices, shops & homes. 3
Mid-morning peak; little or no A/C.
Water Supply Office
pumping stations
4 x 27 KVA Perkins
Three gensets and pumps are used daily to meet
demand & one is used for peak demand. Diesel
consumption is slightly less than 4,000 litres (20 x 200
litre drums) per month. Demand has not increased
noticeably in recent years.
Electric pumps for reticulated
water supply and to water tanks in
rural areas
Hospital
5 KVA backup
Powermate APY5 single phase; currently not
functioning
2 small compressors (1-2.2 kW;
1-3.2 a), several refrigerators
(3.5+a).sterilisation equipment, xray, computers, lights
Rotuma
Island Council
4.8 KW
Robin RGD5000 240 VAC 17.9 a diesel; portable;
purchased 2005 & used for garage, workshop and
main office during afternoons
Power tools, welder (Tranarc
Tradesman 180 a; 240 v),
compressor (1.7 kW, 9a)
District Officer
< 1 kW (?)
Small wind electric generator for battery charging
VHF communications
Telecom
PV charged
batteries
18 KVA backup
Specifications unknown.
1994 Onan 46DGRE, 1 operates ‘few hours’ monthly
Satellite communications;
battery charging
Location
1
2
3
5
Centrally located in government complex in dedicated building on concrete slab. Water cooled. The radiator has been replaced three times
in past 9 years due to vibration, metal fracture and corrosion.
A used 110 KVA Perkins 3 backup system never operated and was shipped to Suva.
These homes typically have electric lighting, electric iron, refrigerator, radio, kitchen appliances, and small home workshop.
Some have television/video and stereo systems.
The three boreholes were drilled in the early 1980s. Mono lift pumps are operated from
diesel engines as follows: Lepjea 44.5m depth (10-12 hours daily; 3 litres per second or 11
m3/hr), Motusa 60m (18 hours daily; 11 m3/hr) & Sumi 72m (volume unknown, should be used
for standby production). Source: “The Status of the Groundwater Production Boreholes on
Rotuma” (Prem Kumar; Govt of Fiji Mineral Resources Dept. Note BP 44/25; July 1997).
Appendix 2 - 5
A. FUEL REQUIREMENTS FOR ELECTRICITY SUPPLY
10. There is no logbook at the Rotuma
Figure 5 – 44 kVA PWD Genset, Aahau
power house recording kWh of energy
produced, or maintenance, only the fuel
consumption, which averages 350 litres of
diesel per week or about 18,000 litres per
year. This appears to represent an
extraordinarily low efficiency of operation
and actual system logging of generation
needs to be carried out. According to the
Public Works Department (PWD) Water
Supply Office, an additional 48,000 litres
per year are used for three gensets for
electric water pumping, for a government
total of 66,000 litres per year for power
generation. An additional 50,000 litres per
year is estimated (see Table 11) for
Photo: John Bennett, May 2005
village electrification, a total of 116,000
litres (116 KL) of diesel fuel per year used on Rotuma for power generation. This
volume is approximate and should be confirmed.6
B. ‘URBAN’ HOUSEHOLD CONSUMPTION
11. For the 27 households connected to the government grid, consumption from
Feb.-April 2005 (when records were available) averaged 51.3 kWh per month per
household (from 5-268 kWh). According to tenants, the charge to households is
FJ$0.1575 per kWh plus 12.5% value added tax (VAT) or FJ$0.1772/kWh (about
US$0.103) compared to the VAT-inclusive FEA price of FJ$0.2316/kWh.7
C. GOVERNMENT CORPORATION CONSUMPTION
12. For February-April 2005, consumption for the Rotuma facilities of Post Fiji Ltd
and Telecom Fiji Ltd. averaged 535 kWh/m and 404 kWh/m respectively. The charge
to government entities is the same as for households. There are apparently no
records of government’s own consumption although some facilities are metered.
D. COST OF SUPPLY FROM AHAU GOVERNMENT STATION
13. There is no reliable information on the cost of electricity produced by the
government power system. An estimate of costs from the other four remote
government stations in 2002 by a Fiji DoE consultant8 indicated a range of FJ$0.81.5 per kWh. That study did not include site visits and was based on logbook entries
6
Discussions with a former executive of Shell, which has a contract to supply fuel used by
PWD Rotuma, suggests that the volume might be considerably higher. Fuel is provided by
drum to PWD Suva as part of a larger government contract and Shell does not distinguish
Rotuma volumes from the total. PWD has been unable to provide information on its
shipments from Suva to Rotuma. The main supplier of fuel for private and village use, Three
Sisters, did not respond to requests for information on volumes. See Attachment 3.
7
According to PWD Suva, consumers are supposed to be charged at the FEA rate. In
October 2005, one tenant in a government house claimed to pay a flat charge of FJ$10/m.
8
“Cost of Electricity Production: Diesel Schemes for Remote Villages, Government Stations
and Fiji Electricity Authority Un-Electrified Villages” by Luis Vega, for Office for the Promotion
of Renewable Energy Technologies (OPRET), Fiji Department of Energy, 2003.
Appendix 2 - 6
at the power plants, which are unlikely to be accurate. The costs were probably
understated. Rotuma was excluded because sufficient data were not available.
However, in 2002 it was probably in the upper range of these estimates. From 2002
to late 2005, the cost of diesel fuel (duty-free Singapore price) has increased from
US$27 to about US$60 per barrel and the wholesale price of diesel fuel in Suva
increased by 71%. The current cost of electricity at the Ahau power station is
probably well over FJ$2 (US$1.2) per kWh. There is clearly a massive subsidy
provided to those consumers connected to the Government system.
IV. Existing Village Electrification
14. Table 9 shows Rotuma’s population by district, with the largest concentration in
Itu’ti’u in the general vicinity of the government centre. Away from Ahau, electricity is
generated by many small diesel gensets operated by users or a local committee.
There are several privately-owned solar PV electricity systems at homes and shops.
Table 9 – Rotuma Population by District (2003)
District
Noa’atau
Oinafa
Malhaha
Itu’ti’u
Itu’mutu
Pepjei
Juju
Total
Population
%
Households
%
311
287
277
887
165
167
296
2,387
13
12
12
37
7
7
12
100
79
74
58
192
33
30
59
525
15
14
11
37
6
6
11
100
Source: Rotuma Island Council, 2005. Percentages are rounded to nearest whole number
15. Figure 6 shows the seven districts of Rotuma and the distribution of villages.
There are 15 main villages, some of which are contiguous, and several sub-villages.
Some villages have more than one generator and some villages share a generator
so there is not a one-to-one correspondence between villages and gensets but
generally there is one communal genset per community.
Figure 6 – Village and Pumping Station Locations on Rotuma
Modified by REEP from map at http://www2.hawaii.edu/oceanic/rotuma/os/hanua.html.
16. In early 2005, DoE staff provided training in Rotuma in diesel operation and
maintenance (O&M) and found the existing systems to be widely variable in terms of
quality of maintenance and general condition. The systems are usually operated only
at times of peak need, the quality of power is typically poor and system reliability is
low. Long periods without power are common due to delays in ordering and receiving
Appendix 2 - 7
repair parts, lack of village funds for purchasing replacement parts or fuel and at
times delayed fuel deliveries.
17. No
comprehensive
inventory
of
generators in use has yet been officially
prepared but PWD/DoE rural electrification
records show the installations listed in
Table 10.
Table 10 – Diesel Generators known to have been
installed on Rotuma (DoE Records)
Village
Oniafa Village *
Year
Install
ed
Generator
1981
LISTER (ST3)
18. During the March 2005 diesel system Paptea Village *
1982
LISTER (ST2)
O&M training, DoE staff visited villages in Malhaha
1983
LISTER (ST3) 20 KVA
each district and interviewed diesel system Juju District
1985
LISTER (ST2)
1985
LISTER (ST2)
operators. This was supplemented in Pepjei Diatrict
Lau/Feavai
1991
LISTER
13.5 KVA
October 2005 by a detailed follow-up
Maftoa
2002
LISTER 8.5 KVA
survey of electricity use in three villages,
Savalei
2002
LISTER 10.5 KVA
visits to all electrified villages, and Pala
2002
LISTER 15 KVA
interviews with operators. The initial survey Tuakoi Ext
2003
DEUTZ 15 KVA
2003
DEUTZ 8.5 KVA
indicated 18 electrified communities Sumi Catholic School
2003
DEUTZ 15 KVA
providing a part-time electricity service to Losa
Kalavaka
/
Ituitu
2003
DEUTZ
20.0 KVA
471 households or nearly 90% of the
Noatau District School
2003
DEUTZ 20.0 KVA
island’s population. However, there were Haga
2004
HATZ 15 KVA
some discrepancies, including apparent Motusa
2004
DEUTZ 40 KVA
double counting of some households. * Not operational in 2005; ‘Year Installed’ refers to most
Some systems reported by PWD/DoE to recently installed system.
be operational have reportedly broken
down, some several years ago. Table 11 summarises the revised findings.
19. Table 11 suggests that 88% of
the village households (470 of 535)
are electrified but in Late 2005 only
about 73% (389 of 535) actually
had a functioning electricity
service. The systems operate 3-6
hours per day (4 hours unless
noted), often for an hour early in
the morning to keep refrigerated
food cool, and several hours in the
evening.
Figure 7 – Mea Hampak village generator installed in 1998
20. There is some ambiguity in the
survey data as different responses
were received from the same
informants at different times. In
general, operators could not Peter Johnston October 2005
produce records so fuel consumption data were based on their estimates only. There
appear to be 18 village generating systems with a total capacity under 300 kVA,
which is consistent with the information in Table 10 from DoE rural electrification
records. The reported fuel consumption, which is unlikely to be very accurate,
suggests that village power systems consume about 4,200 litres per month of diesel
fuel.
21. The monthly payments per household, and the formulas for setting tariffs, vary
considerably ranging from nothing to as much as FJ$30 per month. In several
villages, there is no monthly payment but households take turns buying fuel for the
generator. In most, if not all, villages, households can arrange additional hours of
service at cost for special functions. The operators are usually paid no wages but
may receive free electricity. There is village fund raising to meet expenses for
Appendix 2 - 8
repairs. The cost of generation and distribution cannot be calculated from the data
available. The data should be considered indicative.
Table 11 – Rotuma Village Electrification Survey Results (October 2005; Costs in FJ$)
District
Itu’ti’u
Village
Households:
with
no
Elec
Elec
67
?
15
Saulei
Fee
($/hh/m)
Other comments
$9.4
$12
Operates 5 hrs/day
0
?
0
Late ‘04
?
2004
18
?
5
?
$100/yr
?
$12
?
$10
30
0
25 kVA Lister
2002
>7
$10
Tuakoi
Elsio 2
Pephaua
23
20
11
1
0
1
16 kVA Duetz
Small Lister
10 kVA Lister
2004
2005
~ 1995
5-7
10
5-8
Else’e
20
1
Lopta
32
0
~19801985
2002/3
10
Oinafa
13 (or 17.5?)
kVA Lister
16 kW Lister
10
Yes; $
unknown
?
$ 100/yr
$600
(once)
$100 /
year
?
Noa’tau
Oinafa
Maragtteu
0
46
40 ?
7
27 kVA Duetz
2004
16
$10/hr
$15
Kalvaka 3
Ujia
Uanheta
& Avave 4
Tuai
Haga5
mission
Juju &
Saukana
Maftoa
22
15
21
0
1
0
15 kVA Duetz
2004
9
$1.5
$10
Shared
10 kVA Lister
1985
>4
See
note
$8
4 hrs/day (previously 6 hrs)
Out of order Aug-Oct. 2005
Flat fee; 3hrs: 6-9 pm
Not operating in 2005
+ $1/m per power point &
$1/m per tube light; 4 hr/day
One breakdown (?)
4 hrs: 6-10 pm
4 hrs: 6-10 pm
5 breakdowns/yr
Also provide 16 l fuel/hh/m.
6-9 pm; 4 breakdowns/year
1 breakdown; 6-10 p.m; Fuel
provided in turn by families
No genset for past 10 years
+ $4 per appliance per
month; Operates 6 hrs/day
Operates 5-6 hrs/day
~100 breakdowns/year!
Normally used 6-9 p.m.;
down past 10 months
0
15
4
30
31
0
1
10
~ 1985
2005
Aug ‘04
1984
n/a
5.6
3.4
6
30
3
7 kVA Lister
16 kVA Hatz
6.7 KW
6 (or 7.3?)
kVA Lister
13 and
10 kVA Listers
2003
12
Total: All Gensets
470
65
~ 140 6
All gensets listed above
Total: Now Operating
389
146
~ 125
Gensets operating in Oct. ‘05
Itu’muta
Motusa
Lau
Losa
Other
cost
($/m)
7.5
Juju
0
Fuel
(l/day)
~ 1998
Pepjei
38
Date
installed
17.5 kVA
Lister
40 kVA Duetz
?
15 kVA Duetz
Malhaha
Mea 1
Genset
n/a
?
?
$100 /
year
?
$17-20
$30 (?)
$10
See
comments
n/a
?
none
?
$15
Broke down about 2001
5-6 am & 6-10 pm: 5 hrs/day
Costs paid by church
Operates 4 hours: 6-10 pm;
~ 2 breakdowns/year
Operates 6 hrs/day;
1 breakdown
1)
2)
3)
4)
5)
Mea (Hapmar subdistrict) genset also serves Melsa’a, Salvaka and Ropure.
> = more than; n/a = not applicable ~ = approximately.
Elsio has an old generator (age ?) borrowed from Oinafa to replace a 1985 genset in 2005. Fuel is provided daily by households in rotation.
Kalvaka operator claims fuel use of 200 litres in 23 days or 260 l/m. Extra usage is charged at $15 per hour. The genset also serves Ut’utu.
Informants say several hundred dollars was collected months ago (very early 2004) for repairs but parts & service still awaited.
After joint Haga-Tuai system broke down, 16 kVA replacement plant was ordered but Tuai dropped out and is now unelectrified.
The oversized genset is used for Haga alone. Previously (pre-2001) chare was $10 per hh per month plus fund-raising.
6) Assuming 365 days per year, the current fuel use would be about 46 KL/year. If all gensets are operating about 51 KL.
22. The March DoE survey provided very limited information on village appliance
ownership. In October 2005, REEP arranged a more detailed household survey of
appliance use, electricity use and attitudes in 51 households in three communities
(Juju in the south of the island and the contiguous villages of Pephaua and Else’e on
the north coast),9 all of which had been electrified for at least five years and
presumably had reached some stability in electricity use patterns. Although the DoE
has not yet completed an analysis of results, there was little to suggest that villagers
expect a significant increase in electricity use through the purchase of new
9
Rotuma has a long history of interdistrict rivalry compounded by divisions along religious
lines between the Methodist north and Catholic south. Thus the survey covered both areas.
Appendix 2 - 9
appliances or the establishment of new businesses that would require a reliable 24hour per day power supply.
V.
Diesel Fuel Supply and Cost
23. A Mobil Oil fuel storage facility (Figure 8) is located on the road to the village of
Fapufa near Motusa. It was built at a cost of about FJ$375,000 and opened in
February 1997 but is no longer used. The capacity is about 200 tonnes of all
products, sufficient for many months of consumption. Fuel supplies were pumped
ashore from small coastal tankers anchored offshore via a pipeline that extended
beyond the reef. Serious damage to the pipeline from a tropical cyclone caused the
facility to be unusable. Repairs were not considered by Mobil to be financially
reasonable since high shipping costs, an unreliable shipping service, maximum
prices set by the government and other factors resulted in Mobil claiming losses on
fuel delivered to Rotuma. Mobil withdrew from the market about mid 2004. For a time
Shell provided fuel to Rotuma in 200 litre drums but withdrew in early 2005 (except
for the government contract for fuel delivered to Suva). Fuel continues to be shipped
and stored in 200 litre drums (Figure 9).
Figure 8 – Rotuma’s Deteriorating Fuel Depot
Figure 9 – Ahau Fuel Storage in 2005
Photo: P Johnston, October 2005
Photo: J Bennett, May 2005
24. In March 2005, communities reported that diesel fuel for power generation cost
FJ$1.42-1.66 per litre and lube oil FJ$2-5/litre. In October 2005, villages reported
paying FJ$1.70-1.83 per litre of diesel fuel, which is higher than the maximum
allowable price established by the Prices and Incomes Board (PIB) shown in Table
12.10 Several communities reported paying FJ$1.80 per litre even when purchasing a
full 200 litre drum. In addition to the PIB cost, Rotuma is subject to charges from the
supplier for damaged drums. Each drum carries a deposit of FJ$50, returnable if the
drum is undamaged. Damage is reportedly common.
Table 12 – PIB Maximum Fuel Prices in Rotuma in Fiji cents per litre (November 2005)
Location
Diesel
Kerosene
Motor Spirit
wholesale
retail
wholesale
retail
wholesale
retail
Within 3 km of Oinafa jetty
143.11
165.0
131.15
170.0
174.63
201.0
Beyond 3 km from Oinafa jetty
146.11
168.0
134.15
174.0
177.63
204.0
Source: PIB, 7 December 2005
10
In October 2005, the maximum wholesale and retail prices of diesel fuel within 3 km of the
Rotuma jetty were FJ$1.361 and FJ$1.57 respectively (3 FJ ¢/l higher elsewhere in Rotuma).
See Attachment 4 for PIB fuel price changes during 2005.
Appendix 2 - 10
25. The cost of diesel fuel in Rotuma is the highest in Fiji and the timing and
frequency of deliveries can be uncertain. The supplier to PWD (roughly 60% of
consumption) is Shell but PWD must arrangement shipping from Suva to Rotuma.
The main supplier for private use including village electrification is ‘Three Sisters’ with
several distribution outlets on the island. The RIC also arranges occasional
shipments on the government ship, mainly for school buses and other transport, and
private individuals sometimes purchase small volumes in Suva and ship it to Rotuma.
VI. Annual Patterns of Power Use and Growth in Demand
26. Fuel consumption and power demand increases each year typically in May and
November, corresponding to 2-4 week visits of government officials to the island. The
extent of the increase has not been documented. There is an increase in population
of several hundred or more people over Christmas as Rotumans living away from the
island return for the holidays. Although it can be inferred that household electricity
use increases over the holidays, anecdotal evidence suggests that Government use
does not increase, as there is less activity by government during the holiday season.
27. There are no historical data available from which to estimate the future growth in
demand. There has been no population census since 1996 but population is said to
be stable. There are plans to construct a new air-conditioned hospital in 2006 but the
plans have not been made available, so it is difficult to estimate the impact on
demand, though it will increase considerably.11 There are tentative plans for a new
air-conditioned complex for the RIC and government offices but this is presently on
hold, in part because the Fiji government has not committed itself to renting space in
the proposed facility. Without the government as an assured tenant, the complex is
not a financially viable investment for the council. At one stage there was reportedly
interest in upmarket tourist hotel development in Rotuma. However, in part due to the
unwillingness of 100% of landowners to allow the development of their land, this did
not eventuate and is not now under active consideration.
28. There is almost no air household air conditioning in Rotuma and no indication
that it is likely to increase in the near future. Overall, demand (both kW and kWh) is
expected to grow slowly due mainly to increasing appliance ownership by
households (washing machines, irons, TVs) and the development of new
government facilities. A change from several hours per day of unreliable village
power to a 24-hour service will also increase demand, especially as a satellite
television service has recently been introduced by Fiji TV to Rotuma, but the
magnitude cannot be accurately predicted, especially in the absence of any baseline
data on current electricity use.
29. A centralised system would require about 100 kVA for the current government
load (power distribution and electric water pumping) and a similar capacity for rural
electrification, excluding back-up requirements. Present indications are that Rotuma
will need roughly 250 kVA to cover the existing customers. Additional capacity will be
needed for back-up and the internal consumption of the proposed coconut oil mill.
11
According to the doctor in charge, the old 12-bed single-storey, non air-conditioned
hospital (see Attachment 1 for photograph) will continue to be used. The new two-storey, fully
air-conditioned building will have administrative rooms, surgery facilities, a laboratory and a
pharmacy downstairs and 9 beds for patients upstairs.
Appendix 2 - 11
VII. Rotuma’s Coconut Resource and Coconut Oil Potential
30. Most coconut trees in Rotuma are of the
Figure 10 – Husked Coconuts
Rotuma Tall variety, with smaller numbers of
Malayan dwarf and Samoan but very few Fiji Talls.
Most trees were planted during the 1970s.
Although replanting on a small scale continues,
relatively few trees have been planted since the
demise of the cooperative system in 1993/94. The
nuts in Rotuma are considerably larger than those
in Fiji’s other islands, apparently due to the variety
grown and soil and weather conditions, with claims
of flesh and copra yields per nut being about 75%
higher than elsewhere in Fiji. In Figure 10, the
Photo: P Johnston, October 2005
larger husked nut is a Rotuma Tall and the smaller
a Fiji Tall (which are said to be bigger in Rotuma than those grown in Fiji proper. The
difference in the amount of flesh is more obvious with shelled nuts.
31. There has been no recent survey of the coconut resource in Fiji overall or
Rotuma in particular. In 2005, the RIC requested SOPAC to arrange high-resolution
satellite imagery to provide an accurate current assessment of the resource.
However, as of 16 December 2005, this still awaited formal endorsement by the Fiji
Government’s SOPAC representative.12 According to the Agriculture Office in
Rotuma, perhaps 65-70% of the total land area of 4400 hectares is under coconut. A
2004 report prepared for CIDA13 indicated that in December 1999 Rotuma had
somewhat less than this: 2,615 hectares or 59% of land area under coconuts, 100%
of which were of a productive age. The report indicated a potential production of
15,843 tons (14,400 tonnes) from this area although CIDA questions the accuracy of
this estimate. Sources in Rotuma suggest an output of between 11,610 and 12,550
tonnes of copra (10% moisture content)14 from 2615 ha, an average of 12,080
tonnes, somewhat less than the CIDA report. It is assumed that the maximum yield
of copra with the current resource is on the order of 12,000 tonnes per year but this
should be confirmed.
32. In the photo below (Figure 11), most of the lower parts of the island is covered in
coconut trees. Although Rotuma is hilly, most coconut trees are near the coast and
nearly all of the area planted in coconuts is said to be accessible. In 2005 CIDA
reported15 that the island has the capacity now to produce 1,500 tonnes (metric
tonnes or mt) of copra per year, equivalent to 900 mt of coconut oil, with the potential
to double output to 1,800 mt of oil without new planting.
12
In 2005, SOPAC provided similar satellite imagery to assess the resource for the proposed
Samoa coconut-oil based biofuel project under REEP.
13
The report is “Feasibility Study on the Setting Up of a Coconut Wood Mill in Savusavu,
Vanua Levu, Fiji”
14
The low estimate is based on 4000 nuts/tonne of copra, 60 nuts/year/tree, and 296
trees/ha. The higher estimate assumes 16 kg of copra/tree (at 60 nuts/year/mature tree) and
300 trees per hectare. Observers note that in some areas, there can be up to 100 trees per
hectare.
15
“Use of Coconut Oil Based Biofuels in Rotuma” prepared for REEP Steering Committee
Appendix 2 - 12
Figure 11 – Ahau and Northwest Rotuma from Maka Bay
Photo: P Johnston October 2005
33. From 1970 through 1980, copra production averaged 1,300 tonnes per year.16 In
the past five years, copra production (Table 13) has never exceeded 1,500 tonnes
per year, and has generally been declining.
Table 13 – Rotuma Copra Production, 1999 – 2004 (tonnes)
Year
1999
2000
2001
2002
2003
2004
Copra
1425
960
897
703
694
801
Source: Technical Officer, Agriculture Department, Rotuma (2005)
34. As noted, CIDA estimates a current capacity to produce 1500 tonnes of copra or
900 mt of coconut oil, which is equivalent to 99 KL of oil, or somewhat less in terms
of diesel fuel equivalent.17 Assuming 5% lower fuel efficiency (l/kWh) for coconut oil
compared to diesel, 99 KL of coconut oil would displace about 94 KL of diesel fuel.
Rotuma’s current estimated consumption of diesel fuel for power production is 116
KL. In principle, based on the CIDA data, a very preliminary estimate suggests that
Rotuma-produced coconut oil should be able to displace 81% (94 KL / 116 KL) of the
diesel fuel now used to produce electricity. Without new planting, but with a much
higher (doubled) collection of available unused nuts, Rotuma should be able to
produce about 162% of current diesel fuel demand. To displace all 116 KL of diesel
fuel, Rotuma would need to produce about 122 KL of coconut oil. If this were made
from copra, it would require about 1846 tonnes or less than 16% of the estimated
maximum copra production of 12,000 tonnes from all of the 2615 ha of land currently
under coconut trees.
VIII. Comments on Economics of Coconut Oil Production in Rotuma
35. It is not possible to accurately estimate the cost of the production of coconut oil or
its derivatives for fuel use in Rotuma at this time. It may be that a refined cocomethyl
ester (CME), produced from the transesterification of coconut oil might be preferred
as the appropriate fuel alone or for blending with diesel fuel, in part to reduce issues
related to engine warrantees. However, this would be expensive, would require the
use of methanol and a catalyst such as caustic soda, could raise environmental
issues, and is unlikely to be economic at the small scale of production proposed. For
engines of the size proposed, it is understood that warranties are available for
16
From “One Hundred Years: Rotuma 1881-1981”, Rotuma Island Council (undated). An
unknown, but significant amount of coconuts are used for animal feed and drinking but a large
amount is unutilised.
17
Coconut oil contains about 38.4 MJ/litre compared to 46 MJ/l for automotive diesel oil but
this difference is apparently not reflected in significantly less fuel efficiency per litre.
Appendix 2 - 13
coconut oil itself as a fuel. For Rotuma, coconut oil produced from the kernel (fresh
flesh) or possibly copra (dried flesh) would be preferable, filtered and possibly
centrifuged as required.
36. The current world price of coconut oil exported from Fiji is US$620 per mt (about
FJ$1,000/mt) or FJ$0.91/litre. This has been fairly static for some months but is
higher than the medium to long-term projections of US$400-600/mt. The value of oil
to Fiji as an export commodity is somewhat lower as freight, insurance and other
charges to transport the oil to market must be paid. The value of the oil is still lower
in Rotuma due to the high cost of shipping copra to Suva (FJ$84/tonne), and then to
Savusavu (on Vanua Levu) for processing into oil. The combination of Rotuma
having the highest diesel fuel cost and the lowest effective copra price in Fiji makes it
the most likely site in Fiji to find the use of coconut oil for power generation an
economically sustainable endeavour.
37. Coconut oil is not produced commercially in Rotuma. A small amount is
occasionally made by one person (John Bennett) for use as fuel or for blending with
diesel fuel in a 2.5 kVA Yanmar genset. He uses a small hand press (about 2 kg or
2.2 litres of oil per hour capacity) or a ‘Hander’ screw press (30 kg or 33 l/hr).
38. Approximately 14 conventional wood-fuelled copra driers (see Attachment 1)
produce small quantities of copra, often at low quality, for sale to Three Sisters.
There are also two solar driers, a large one (5 tonne capacity) at Kalvaka, Noa’tau
District built around 1994 which is used intermittently (Figure 12) to produce a highergrade of copra and a small one (0.5 tonne capacity) at Maf’toa, Itu’muta, which is
used regularly. Although the large drier appears to be dilapidated, the
designer/builder (J Bennett) said it should be relatively inexpensive to renovate it.
Some coconut flesh is also air-dried (Figure 13) to produce copra. Most copra is
produced by Three Sisters itself using a wood-fuelled drier. Coconut flesh is prepared
by villagers and left in baskets (see Attachment 1) for collection for later processing
by Three Sisters. Although the flesh is sometimes left for several days before
collection, and the surface can become rancid, this is reportedly adequate for
producing fuel-grade raw coconut oil.
Figure 12 –
Large Solar Copra Drier, Kalvaka, Noa’tau District
Figure 13 –
Village Air Drying of Copra
Photos: J Bennett, May 2005
39. Displacing 116 KL of diesel fuel per year would require about 122 KL of coconut
oil, which would in turn require about 1846 tonnes of copra. There are various
technologies available to produce this volume of fuel. A simple system using a copra
cutter and expeller is illustrated in Figure 14. About 15 units have been sold in the
Pacific Islands. The basic equipment to produce the required volume would cost
about US$20,000 delivered to Fiji excluding civil works, filters and motors. The
coconut oil is ‘food quality’ but is yellowish with a slight odour.
40. Other systems produce a finer high-quality ‘virgin coconut oil’ (VCO), which is
clearer and odourless, from the cream produced by squeezing finely grated coconut
flesh. These often use a fermentation and filtering system or the cream can be
Appendix 2 - 14
centrifuged (Appendix 7), in some cases without further filtering.18 One Fiji company
which uses VCO for body oils, pays US$5/litre, far above its value as a fuel and
export prices for high quality VCO can be considerably higher. Another Fiji company
which produces VCO (using the basic system described in Appendix 6 but freezing
the cream rather than fermentation) estimates a production cost of F$2 per litre
(about US$1.10) from a small system producing about 100 l/day. For this size, a
turnkey container-mounted system would cost about F$50,000 (US$29,000). For the
volume required for Rotuma, and a centrifuge system, he estimates a considerably
lower production cost.
41. In November 2005, Three Sisters (the sole
Figure 14 –
coconut flesh or ‘kernel’ and copra buyer on
Old Tinytech Coconut Oil Expeller
Rotuma) reportedly paid growers FJ8¢/kg of
kernel, equivalent to FJ$40 per tonne of copra
produced, i.e. the growers received about 10% of
the net value of copra exported from Rotuma, or
only FJ$32,000 (under US$20,000).19 FJ 8¢/kg
of kernel is equivalent to about FJ4¢ per
(Rotuma sized) coconut. The number of
coconuts necessary to produce 122 KL of oil is
roughly 2.3 times the number used for copra
production in 2004. Some Rotumans feel that
the price paid per kg of kernel would have to Photo: Peter Johnston 2004 (Solomon Islands)
increase to FJ 15¢ per kg of kernel, about FJ 8¢/nut to provide sufficient incentive to
produce that much kernel. However, a less labour-intensive system based on the
delivery of whole nuts to the roadside rather than kernel flesh, should be less costly.
The cost per coconut could have a significant impact on fuel price. At FJ4¢ and FJ8¢
per nut, and about 6 nuts per litre of oil, the raw material cost is FJ 24¢/litre and FJ
48¢l respectively.
IX. Scope of the Project
42. The project has two parts:
1) It connects all the island’s villages through an 11kV grid and eliminates the
numerous mini-grids now in place. All generation would be centralised.
2) It develops the capacity to locally produce all the biofuel needed to power the
centralised electricity supply, including water pumping.
43. In effect the project completely replaces the patchwork electrification that is now
present and develops a local capacity to produce coconut oil based biofuel in
sufficient quantities to fuel the central generator.
A. 11 KV CENTRALISED GRID AND CENTRAL POWER STATION
44. The project would require construction of a 32 km 11 kV grid, either above or
below ground, around the perimeter of the island, including branches to the three
water-pumping stations and the villages in the westernmost part of the island. There
18
Some systems run the centrifuge twice, with one basket to remove solids and a second to
remove liquids.
19
In 2004, Rotuma exported 801 tonnes of copra at an average value of FJ$485 minus F$84
shipping cost. Although several growers reported receiving FJ 8¢/kg of kernel, a Three
Sisters employee on Rotuma said the payment was actually FJ 12¢/kg, in which case, the
growers received 15% of the value of the copra or FJ$48,000.
Appendix 2 - 15
would probably be 18 (possibly less) step-down transformers required. The PWD,
which tends to estimate very high rural electrification costs, has calculated a cost for
an above-ground pole-mounted grid system (including all supplies, labour and
shipping to Rotuma) of F$80,000 per km (US$46k/km) or about US$1.47million. The
REEP consultants estimate a lower cost of about US$25k/km or US$0.8 million.
Underground reticulation, preferable in a hurricane prone country, would cost
considerably more.
45. Each village already has an underground distribution system, often only several
years old. However, the homes are not individually metered so provision will need to
be made for meters. A provision of US$27,000 is made for this (535 meters at US$50
per meter).
46. Rotuma will require about a 250 kVA system to meet present and anticipated
needs plus back-up and around an additional 50 kVA for the internal consumption of
the proposed coconut oil mill.
B. BIOFUEL PRODUCTION
47. The production of 122 KL/yr of oil (about 500 l/day assuming a 5-day workweek
for 50 weeks per year) will require the collection of about 732,000 nuts or nearly
3,000 nuts per workday. Equally spread among 15 villages, this is only 200 nuts for
each village per day. Provision is made for one truck with a driver and labourer to
collect the nuts and transport them to a central facility.
48. The preferred fuel is coconut oil, filtered as required, rather than a more complex
esterification process. Dehusking, defibring, deshelling and grating the nuts should
require no more than two unskilled labourers. The processing of the copra and the
production of 500 litres of fuel daily from the copra, should require no more than one
skilled and one unskilled worker.
C. MANAGING THE ENTERPRISE
49. Currently the Ahau power system and all other remote government centre power
systems are managed by the PWD. There has been no policy decision to change
this. However, there have been informal discussions between the Ministry of Works
and Energy (of which PWD is a department) and the Fiji Electricity Authority
regarding the conditions under which FEA would be willing to take over the
management of these power systems. Thus far the main stumbling block has been
the long-standing Cabinet directive that the remote systems must charge users at the
national FEA tariff. Under this tariff, FEA would lose considerable revenue for each
kWh produced and sold. Within an ongoing Fiji Government reform process, there
has been a slow shift away from the previous public service emphasis on
implementing all activities to the oversight and management of activities undertaken
by others. Within FEA itself, there is considerable interest, and activity, in negotiating
power purchase agreements (PPAs) with independent power producers (IPPs).
When considering options for managing a centralised power system in Rotuma
(whether diesel or biofuel based) it should not be assumed that PWD is the only
alternative acceptable to the government or to Rotumans. Several options are
summarised in Table 14. Regardless of the option, Rotumans would receive a
reliable 24-hour power supply that would cost more than consumers currently pay for
their limited service. Either government subsidies – which are already substantial – or
charges would have to increase to meet costs, quite possibly both.
Appendix 2 - 16
Table 14 – Possible Alternative Mechanisms for Rotuma Biofuel Power System Management
Management
Likely Strengths
PWD
Headquarters back-up support available.
Hidden govt subsidies possibly available.
FEA
Considerable staff & financial resources.
Developing some biofuel experience.
Improved accounting and billing
Relatively professional.
May be easier to obtain and retain
government subsidies
Island Council
RESCO
2
Rotuman IPP
1
3
1
Ownership remains with Government.
Contractual operation under government
oversight could provide arms-length (i.e.
honest) operations.
Might tap skills of retired skilled Rotumans.
Ownership could be with Govt or the IPP.
Possible incentive to reduce costs through
value-added activities. 3
Might tap skills of retired skilled Rotumans
& funds of Fiji-based professional
Rotumans.
Expected Weaknesses
History of inefficiency in Rotuma (poor records &
management).
No experience with island-wide system.
Unwilling without massive tariff increase.
High staff salaries; would be expensive service.
Under law, only operate where it is profitable.
No experience with small remote systems
Limited continuity of staff and perhaps policies.
No commercial experience.
Likely to be politicised.
May expect power sales to subsidise RIC
operations or shortfalls.
Legal framework not yet established.
No true RESCOs yet exist in Fiji.
No obvious candidates.
Jealousy or mistrust among other Rotumans.
IPP contract would require good govt
supervision.
Possibly no Rotuman experience in such a
venture.
through a Rotuma provincial development company. 2 Renewable Energy Service Company.
For example selling excess oil as high-value VCO, producing commercial abrasives from shell powder, promoting
intercropping with other oil-bearing plants, etc.
50. Considering the inefficient operation of the current Ahau system, and the extreme
unlikelihood of FEA interest or ability to operate in Rotuma at low cost, the preferred
option would be some sort of private management of a government-owned facility
under an IPP or possibly RESCO arrangement.
X.
Further Project Concept Development
51. The proposed project is to design and install a centralised power generation
system powered by diesel engines operating on locally produced fuel that is based
on coconut oil. To develop the project to the design stage, the following remains to
be completed:

The current electricity demand and forecast for the future to be confirmed;

Recommendations as to equipment for the production of the fuel and for the
central generation facility

Better cost estimates for the fuel production process, the generation process
and the island wide distribution system

The institutional structure appropriate to ensure the reliable collection of
sufficient coconuts, the quality controlled production of copra, the quality
controlled production of coconut oil, the quality controlled process for the
production of the fuel from raw coconut oil, the operation and maintenance of
the centralised power system, the setting of appropriate tariffs and the
collection of fees for services provided.

An environmental impact study

An estimate of the benefits to Rotuma development by such a project
Appendix 2 - 17

Calculation of cash flows and other financial parameters.

Calculation of EIRR for the project

An overall analysis to determine the feasibility of the project
XI. Supplementary Rotuma Photographs
Photographs by J Bennett, P Johnston or staff of Fiji Department of Energy, all 2005.
The road around the perimeter of Rotuma
Village wood fuelled copra drying
Appendix 2 - 18
Coconut flesh awaiting collection
Elsio genset, Malhaha District,
with operator Charlie Kitione
Scraping coconuts for animal
feed, flesh or copra production
Maragtteu genset, Noa’tau District with
operators; installed new in 2004
Appendix 2 - 19
Mea genset, Hapmak District, with
energy use surveyor Peter Underwood
Typical village genset housing
Typical internal wiring
Genset, village unknown
Household external wiring
Junction to underground village reticulation
Appendix 2 - 20
Rotuma’s hospital at Ahau
Village fuel sales
Composite aerial photograph of Rotuma (circa 1991)
Views from Kilaga Lookout in October 2005 (P Johnston)
Much of the land in the photo to the right is covered in coconut trees
Appendix 3 - 1
APPENDIX 3
PROPOSED ENERGY EFFICIENCY ACTION PLAN FOR SAMOA 2006-2008
Appendix 3 - 2
1.1. Task 1.1 – Achieve the political involvement into energy
efficiency
3
1.2. Task 1.3 – Establish an Energy Efficiency Committee
3
1.3. Task 1.2 – Create an Energy Efficiency Section (EES) in the
Energy Unit, emply and train the staff in the management of the
activity 3
2.1. Task 2.1 – Update the input data
4
2.2. Task 2.2 – Set up the labelling program
4
2.3. Task 2.3 – Define the marketing tools
5
2.4. Task 2.5 – Set up the monitoring and evaluation system
5
Appendix 3 - 3
1.
1.1.
PHASE 1: ESTABLISH AN INSTITUTIONAL LEGITIMACY
Task 1.1
efficiency
–
Achieve
the
political
involvement
into
energy
Responsible: Government of Samoa
1.2.
Task 1.3 – Establish an Energy Efficiency Committee
A high level committee needs to be assigned the mission to develop and
achieve the different tasks of the action plan. Within the committee, working
groups may be established to look after specific tasks.
The members of the Energy Efficiency Committee needs to include
representatives from all the stakeholders, noticeably (i) the governmental
bodies (the Energy Unit within Treasury, EPC, Customs, Department of Fair
Trade), (ii) local private companies (consulting companies, retailers of
appliances), (iii) the educational and training bodies (University of Samoa),
(iv) Consumer advocates and NGOs, and (v) other relevant stakeholders.
- Issue an official statement of Government’s strong commitment in
supporting a global energy efficiency strategy and action plan
1.3.
Task 1.2 – Create an Energy Efficiency Section (EES) in the Energy Unit,
emply and train the staff in the management of the activity
- Establish the necessary positions within the Energy Unit
- Proceed recruiting the staff of the EES on a contract basis
- Achieve the staff's training
- When the staff positions become available shift contracted staff to
established staff positions.
Appendix 3 - 4
2.
2.1.
PHASE 2: IMPLEMENT THE OPERATIONAL FRAMEWORK
Task 2.1 – Update the input data
Responsible: Energy Efficiency Committee / Energy Unit
- Carry out a national survey on household energy consumption and
determine the market for energy-efficient appliances and energy saving
services
 Sample at least 2000 households
 Characterize the type and number of domestic appliances in use
 Carry out a statistical analysis of household energy consumption profiles
 Complete a socio-economic analysis of the population at household
level regarding their expectations for and understanding of household
energy use,
- Achieve a detailed statistical and cross analysis evaluation on import data
and retailer sales in order to determine the type, quantity and origin of
appliances imports over the last five years
2.2.
Task 2.2 – Set up the labelling program
- From the analysis and synthesis of the above activities, prepare
quantitative efficiency targets for the next 5 years for 3 product classes:
refrigerators, air conditioners and lighting systems:
 number of items of the three classes of labelled equipment expected to
be imported,
 projected power generation and energy savings for each year as a
result of labelling,
- Establish collaborative frameworks with the Department of Energy in Fiji
and with labelling bodies in all countries manufacturing the labelled
appliances to establish a table of equivalence for all the labels applied in
those countries and create a Samoa rating systems that cleary shows the
relative energy efficiency of imported equipment from all contries
exporting labelled appliances to Samoa.
- Analyse the data and projections and after stakeholder consultations,
establish by legislation the minimum energy efficiency requirements for
the import of refrigerators, air conditioners and fluorescent light ballasts
- Include in the legislation a timetable to grandually reduce and finally
prohibit the import of second hand refrigerators or air conditioners without
a special permit from the Energy Unit.
- Establish the procedure to remove the foreign labels and apply the proper
Samoa lable on the appliances after their import
Appendix 3 - 5
2.3.
Task 2.3 – Define the marketing tools
Responsible: Energy Efficieny Committee / Energy Unit
- Define the contents of a marketing strategy and program sustaining the
analysis and objectives obtained in task 2.1 Retailers and EPC would be
major partners in this marketing program
- Define the contents of the training program for the vendors and plan the
training sessions; design it together with the private sector
2.4.
Task 2.5 – Set up the monitoring and evaluation system
- Define the indicators to be used for monitoring the results with regard of
the objectives
- Identify the sources of information for the indicators
- Define and implement sustainable procedures for the data collection and
quality control
- Define and implement the process of evaluation of results
3.
PHASE 3: SUSTAIN THE EE & LABELLING PROGRAM
Responsible: Energy Unit
4.
CALENDAR
The calendar of the project would spread over a 36 months period with the
following breakdown:
- Phase 1: 12 months
- Phase 2: 6 months
- Phase 3: 12 months
Appendix 3 - 6
2006
7
PHASE 1: ESTABLISH AN INSTITUTIONAL LEGITIMACY
T1.1 Achieve the political involvement into energy efficiency
T1.2 Establish an Energy Efficiency Committee
T1.3 Create an Energy Efficiency Section (EES) in the Energy Unit, emply and train the staff in the management of the activity
-
Establish the necessary positions within the Energy Unit
-
Proceed recruiting the staff of the EES on a contract basis
-
Achieve the staff's training
PHASE 2: IMPLEMENT THE OPERATIONAL FRAMEWORK
T2.1 Update the input data
- Carry out a national survey on household energy consumption and determine the market for
energy-efficient appliances and energy saving services
- Achieve a detailed statistical and cross analysis evaluation on import data and retailer sales in
order to determine the type, quantity and origin of appliances imports over the last five years
T2.2 Set up the labelling program
- Establish collaborative frameworks with the Department of Energy in Fiji and with labelling bodies in all countries manufacturing
the labelled appliances to establish a table of equivalence for all the labels applied in those countries and create a Samoa
- Include in the legislation a timetable to gradually reduce and finally prohibit the import of second hand refrigerators
or air conditioners without a special permit from the Energy Unit
- Analyse the data and projections and after stakeholder consultations, establish by legislation the minimum energy efficiency
requirements for the import of refrigerators, air conditioners and fluorescent light ballasts
- Prepare quantitative efficiency targets for the next 5 years for 3 product classes: refrigerators, air conditioners and lighting systems
- Establish the procedure to remove the foreign labels and apply the proper Samoa lable on the appliances after their import
T2.3 Define the marketing tools
- Define the contents of a marketing strategy and program sustaining the analysis and objectives obtained in task 2.1
- Define the contents of the training program for the vendors and plan the training sessions; design it together with the private sector
T2.4 Set up the monitoring and evaluation system
- Define the indicators to be used for monitoring the results with regard of the objectives
- Identify the sources of information for the indicators
- Define and implement sustainable procedures for the data collection and quality control
- Define and implement the process of evaluation of results
PHASE 3: SUSTAIN THE EE & LABELLING PROGRAM
Launch the marketing program
Monitor the results and organize semestrial reviews
8
9 10 11 12 1
2007
2
3
4
5
6
7
2008
8
9 10 11 12 1
2
3
4
5
6
7
2009
8
9 10 11 12 1
2
3
4
5
6
7
8
9 10 11 12
Appendix 4 - 1
APPENDIX 4
REVIEW OF PAST AND PRESENT FIJI DOE ENERGY EFFICIENCY ACTIVITIES
AND RECOMMENDATIONS FOR THE FUTURE
Appendix 4 - 2
REVIEW OF FIJI DOE ENERGY EFFICIENCY ACTIVITIES
AND RECOMMENDATIONS FOR THE FUTURE
I.
BACKGROUND
1. The Department of Energy (DOE) is a part of the Ministry of Works and Energy. DOE was
established in early 1981 with its major purpose being to reduce the rate of growth of the
country’s imported energy costs, increase the use of indigenous forms of energy and reduce the
impacts of energy use on the local and global environment. To accomplish this, DOE promotes
the use of indigenous renewable energy resources and the efficient use of energy.
2. In practice, DOE has assumed a number of responsibilities:
•
Facilitating the provision of energy to domestic, commercial and industrial users through
public enterprises and the private sector by developing and using a policy, regulatory,
planning and implementation framework;
•
Encouraging the FEA to operate on a commercial basis, with economic regulation where
necessary.
•
Re-orienting the approach to rural electrification emphasizing informed community
choice, sustainability and containment of Government subsidy to achieve greater
penetration of electrification into rural areas;
•
Researching and promoting the development of local energy resources such as
hydropower, biomass, biofuel, solar, wave and wind energy;
•
Promoting energy conservation measures which improve both technical and economic
efficiency in energy use; and
•
Participating in the preparation of national fuel standards and smoke emission levels and
promoting more efficient and environmentally sound transport practice.
3. To accomplish its mission, DOE organizes its activities under the following programs:
•
Renewable energy development
•
Energy conservation/efficiency
•
Petroleum and transport
•
Energy information and database
•
Power sector development
•
•
Environment/gender
4. Among these programs, an “Energy Conservation” program directly and explicitly targets
energy efficiency. However, other programs – “Petroleum and transport”, “Energy information
and database”, “Power sector development”, and “Environment” – should all be considered as
important components of an energy efficiency policy, either because they constitute target areas
for energy efficiency improvements (transport, the power sector), or because they provide
energy efficiency indicators (energy information and database), or because they provide
leverage for the attainment of energy efficiency objectives (environment).
Appendix 4 - 3
1.
Institutional framework
5. The legitimacy of DOE and of its mission is not based on a well defined institutional
framework or national energy policy though a National Energy Policy is in the process of
preparation. There is no legislation relating to energy that governs the DOE activities or
provides it with specific mandates or regulatory authority. However, there are specific laws and
legal tools that regulate:
•
The activities of supply-side operators including the Electricity Act, the Petroleum Act,
the Fuel and Power Emergency Act, and the Public Enterprise Act.
•
The use of electricity production equipment in certain sectors, particularly the Hotels Aid
Act, which authorizes the installation of power generation equipment within tourism
complexes and the possibility to sell the surplus produced to the grid.
•
Energy tariffs through the “Commerce Commission” established by the 1998 Commerce
Act.
•
Environmental Issues, the Environmental Management Act of 2005 impacts on energy
development.
6. A draft legal framework aimed at developing energy services in rural areas based on the
Renewable Energy Service Company (RESCO) structure is under discussion but has not yet
been sent to Parliament for consideration.
7. Elements of a proposed revised regulatory structure for the FEA have been developed but
not approved by Cabinet. The Land Transport Authority (LTA) Act gives the LTA the power to
regulate road-based vehicle emissions and implicitly vehicle energy efficiency.
8. There is no legislative or regulatory framework in the field of energy efficiency: no quantified
national objective for energy saving or energy intensity improvement exists in Fiji’s legislation, in
the Government’s “Strategic Development Plan for 2003 - 2005”, nor in DOE’s “Strategic
Development Plan 2005 - 2007”.
9. In these two documents, there is only a “target” relating to energy saving in the public
building sector:
•
30% - 40% total energy savings from identified government buildings by 2005 (“target”
value in the Strategic Development Plan for 2003 - 2005), a goal that was not achieved.
•
20% total energy savings from identified buildings by 2007 (“target” value in DOE’s
Strategic Development Plan for 2005 – 2007).
10. As there has been no recent comprehensive energy use survey for public buildings, there is
no baseline from which a program can be developed to achieve and document these target
savings.
11. With the assistance of Australia, work is underway to implement mandatory labeling that
shows the relative energy efficiency of imported refrigerators and freezers but at present there
are no norms or standards relative to the performance of equipment and appliances. Though
the DOE has no legal basis for imposing standards and regulations of this type, the legal
components of the appliance standards and labeling process are being facilitated through the
Ministry of Commerce as they have the legal basis for imposing such standards.
B.
Past DOE activities related to energy efficiency
12. The DOE has carried out a number of energy efficiency improvement projects for
government (Table 1). The impact on the individual institutions has generally been significant, at
least in the short term, though on a national scale the projects have had little effect on annual
Appendix 4 - 4
energy imports. In addition to these activities there have been supply side energy efficiency
improvement programs, in which DOE has been involved, by FEA and demand side efficiency
improvement programs by SOPAC and the Forum Secretariat though the details were not
available to the team.
Table 1: DOE Energy Conservation Projects (1993 – 2004)
PROJECT
PLACE/PROVINCE
YEAR
AMOUNT
DESCRIPTION
(FJ$)
Gas cookers
Lautoka Hospital
1993
21,000
Steam pipe
replacement
CWM Hospital
1994 1998
634,000
Lighting system
Lautoka Hospital
1995
101,119
Lautoka Teachers
College
Fiji College of
Advanced Education
1996
135,315
1996
100,000
Lighting and airconditioning
system
Boiler
Fiji School of
Nursing
Twomey Hospital,
Tamavua
Boiler efficiency
1996
Installation of three 6-burner gas stoves and 12 open cast
iron burners.
Savings of $12,000 annually.
Boiler efficiency audit by Sinclair Knight in 1994.
Steam pipe replacement work commenced in 1994 by CR
Engineering at the Boiler House and the Laundry.
Works completed. Fuel savings of about $30,000 annually.
The steam reticulation system was upgraded in 1998 at the
CWM's Old Hospital, New Wing and Maternity Annex.
System upgraded
Audits conducted. Lighting system upgraded.
Annual savings; LTC – $14,676, FSN – $10,000 and FCAE
– $4,284.
Replacement of old boilers.
Questionnaires sent out to institutions using boilers. The
information gathered was used to prepare a one-day
training workshop for Fiji's Boiler Operators.
Replacement works commenced late in the year and was
completed in 1998, which saw the installation of a new
boiler system.
Audit of steam reticulation system.
The upgrading of the existing steam pipes commenced in
1999 and will be completed in 2000. Estimation of $40,
000 yearly savings.
Boiler
Labasa Hospital
1997
150,000
Steam pipe
reticulation
system
Lautoka Hospital
1999
50, 000
180,000
Labasa hospital
2003
80,000
Labasa hospital steam reticulation upgrade on-going
Energy Audit
Koronivia Research
Station &
Commissioner
Central’s Complex
1999
60, 000
Audit of lighting and air-conditioning systems.
Energy Audit
Fiji Museum
2001
7, 150
Energy Audit
Nasilivata House
(PWD
Headquarters) &
Labasa Hospital
2002
20, 000
Air-Conditioning
system audit
Fiji Museum
2002
15, 677
Energy audit conducted. Air-conditioning systems currently
being undertaken. Estimation of $2, 000 savings annually.
Nasinu/Naboro
2003
25,000
Energy audit preformed on lighting systems.
Lautoka-Natabua
Prison
2004
30,000
Energy assessment revealed quantitative lighting savings
through new improved lighting systems. New energy
efficient lighting
Steam pipe
reticulation
system
Prisons Audits –
Lighting systems
Prisons Lighting
Preliminary Audit
and Upgrading
Report on
appliance
labeling program
for refrigerators
and freezers in
Fiji
2004
Audit of lighting and air-conditioning systems.
Audit of the lighting and air-conditioning systems at
Nasilivata House and the steam reticulation system at the
Labasa Hospital
Market study about main factors leading to purchase of
refrigerators or freezers..
Appendix 4 - 5
13. There has apparently been no attempt to assess the actual immediate savings achieved by
some of these projects and, until 2005, no monitoring of longer-term impacts.
C.
Current DOE activities related to energy efficiency
14. DOE energy efficiency activities were summarized by Mr. Intiyaz Khan (DOE Senior
Scientific Officer) and the ICE consultants at DOE on 21 April 2005.
15. These activities cover the following fields:
•
Training for DOE staff
•
Audits
•
Appliance labeling
•
Energy balance calculation
•
Contribution to the energy strategy policy
•
Contribution to the 2005-2007 Strategic Development Plan (SDP)
•
Energy indicators (at an early stage)
•
Publication of informational brochures
•
Organization and support of events that relate to energy
•
Preparation of annual reports
•
Monitoring of the supported energy audit projects (activity started in 2005)
•
Comments on the country strategy and position concerning international negotiations on
climate change. (The Ministry of Environment is the lead Ministry; the DOE is not directly
involved.)
16. Some of the activities listed above are referenced in DOE’s annual reports. Others, in
particular DOE’s contributions to the Strategic Development Plan or in the elaboration of the
national position in international negotiations were identified during the discussion.
17. DOE is unfortunately not included in Government discussions concerning certain sector
policies that could strongly influence the country’s energy future such elaborating national
positions in the international negotiations on climate change even though the development of
indigenous energy resources and improvement of the efficiency of energy use must be key
components of any effort to reduce greenhouse gas production.
D.
Staff
18. The DOE has had a relatively rapid staff turnover in recent years. As a result, the number of
staff with long term tenure is small. DOE currently has five professional staff to implement and
follow up its various activities. The professional team would be extended to eight members if all
vacant posts are filled. One staff member is on extended study leave. With the small number of
professional staff, it is clear that there cannot be extensive direct involvement in implementation
of projects at any scale.
19. The organization chart presented in DOE’s 2003 Annual Report showed a staff of 10
operational employees of a total of 22 persons (the other 12 are mostly administrative
personnel).
20. In the field of energy efficiency, most of DOE’s employees’ time has been spent on energy
audits, energy efficiency improvement and studies in the following fields:
Appendix 4 - 6
•
Gas cookers
•
Steam pipe replacement
•
Lighting systems
•
Air-conditioning systems
•
Boiler efficiency
•
Steam pipe reticulation systems
•
Mandatory appliance labeling program for refrigerators and freezers.
21. These activities (16 projects were reported) were conducted between 1993 and 2004. Their
reported cost was F$1.5 million (excluding staff salaries). A complete list of energy conservation
projects is given in Appendix 1. The accumulated savings are estimated at around 180,000 F$
per annum for those projects which were evaluated1. Over the 11-year period of 1993-2004, the
number of audits performed is relatively small and their effects on the national energy balance
are not large.
E.
DOE’s Budget
22. The 2002 and 2003 Annual Reports present the distribution of the budget allocated to DOE
as follows:
2003
FJ$ 000
2002
%
FJ$ 000
%
DOE Expenditure Allocation
Running costs
Established staff
330.60
4.7%
399.80
6.9%
Unestablished staff
32.40
0.5%
37.70
0.7%
Travel and Communication
20.80
0.3%
20.80
0.4%
Maintenance and operation
19.10
0.3%
19.10
0.3%
Sub-total running costs
402.90
5.8%
477.40
8.2%
Purchase of goods and services
14.80
0.2%
11.60
0.2%
Energy conservation assessment
50.00
0.7%
55.80
1.0%
Energy database
25.50
0.4%
-
0.0%
Energy Conservation implementation
82.00
1.2%
-
0.0%
Muani Wave
176.50
2.5%
-
0.0%
Renewable Energy Development Program
60.00
0.9%
69.30
1.2%
Promotion of sustainable energy technologies
65.00
0.9%
90.00
1.6%
Maintenance of Energy Development projects
17.10
0.2%
17.10
Operating budget
0.3%
Rural Electrification
6 000.00
85.6%
5 000.00
86.3%
sub-total operating budget
6 490.90
92.7%
5 243.80
90.5%
111.70
1.6%
VAT
Total
1
Savings were not evaluated for some projects.
7 005.50
100.0%
72.10
5 793.30
1.2%
100.0%
Appendix 4 - 7
23. The 2003 budget reached FJ$7 million versus FJ$5.8 million in 2002. About 6% was for
running costs and 94% (VAT is not taken into account) for operations. Similar proportions are
observed for the year 2002.
24. The very modest amounts allocated to the Department’s running costs, in particular the
salaries of the professional staff, well reflect the weakness of DOE’s operational capacities. It
raises the question of the capacity of the DOE as currently structured to properly administer an
operating budget that is more than 17 times higher than the running costs.
25. The distribution of the operating budget among the various DOE programs is strongly
skewed toward the rural electrification program that alone consumes more than 85% of all
allocated funds (FJ$6 million). The allocation for the other programs has been about FJ$0.5m.
Programs that directly or indirectly relate to the energy efficiency program represent less than
3% of the operating budget. The meager level of funding allocated to energy efficiency does not
reflect the level of importance given to energy efficiency in DOE’s activity reports and discourse.
However, the budget of DOE’s rural electrification program results from Governmental priorities
that go well beyond just energy sector policy since rural electrification aims at poverty
alleviation, economic and social cohesion, economic development, health improvement and
education. In reality, the primary activities that were the basis for the creation of the DOE –
reduction of dependence on imported fuels and in the environmental effects of energy use –
receive less than 15% of the total budget since the rural electrification program is strongly
oriented toward the use of imported diesel fuel or connection to the existing FEA grid where the
added demand is met by diesel based generation.
26. The small allocation for energy efficiency in the budget shows that this field is not
considered a Government priority.
II.
DISCUSSION AND LONG TERM RECOMMENDATIONS
27. Although DOE’s creation in 1981 was motivated by the Government’s desire to control the
country’s level of dependence on imported petroleum products by developing energy efficiency
and renewable energies, no legislation was adopted to back up this mission. There is thus no
formal framework that legitimizes DOE’s activities vis-à-vis other ministries, administrations and
public enterprises in the energy sector. If DOE is to regulate energy production and use in a
legal and consistent manner, it must have the legal mandate to do so. Legislation is also
needed to clearly define the scope of those activities vis-à-vis other government agencies and
the FEA.
28. This institutional weakness has a direct effect on the nature and the organization of the
activities of the DOE. The activity reports show that DOE simultaneously takes on tasks of a
strategic nature (the participation in the development of legislation and national fuel standards
and smoke emission levels, the promotion of more efficient and environmentally sound transport
practices or input to the preparation of a national strategic plan, etc.) and the direct
implementation of projects of a technical nature such as providing energy audits and installing
renewable energy equipment. In a context where the human and financial means are limited,
this lack of a clear positioning contributes to reducing the visibility of DOE and limiting its ability
to affect government decisions on energy.
29. A national institution in charge of energy efficiency should have sufficient and competent
staff. To ensure this, DOE should be able to offer sufficiently attractive conditions of work and
salary to attract skilled, motivated and self-directed employees. In the short term, such profiles
are absolutely indispensable in order to effectively and efficiently use the relatively small funding
allocated to the Department. In the long run, the quality of human resources can have a
fundamental lever effect by permitting the development of fruitful and sustainable co-operation
with national or international bodies in energy efficiency and renewable energies and also by
Appendix 4 - 8
mobilizing the financial means of international aid through well-constructed programs and
projects. Under the existing conditions, the DOE appears to be more a training ground for
regional and international organizations than a career choice for energy professionals.
30. Finally, an experienced and high quality team should permit DOE to increase its
participation in debates and discussions relating to the national energy policy in general and to
sector policies that have a strong energy impact (transport, buildings, domestic appliances,
decentralized energy production, etc.) The visibility and legitimacy of the institution can only be
improved with these changes. Furthermore, such an evolution constitutes in turn a necessary
condition of an improved capacity to negotiate with the Ministry of Works and Energy and the
Ministry of Finance to obtain supplementary budgetary support.
31. The budget allocated to DOE to promote and improve energy efficiency is critically low. This
contributes to a relatively dispersed and ineffective strategy:
•
The audits have produced tangible results at the unit level but over an 11-year period,
has saved no more than 500 toe per year, i.e. less than 0.1% of the country’s current
energy consumption. The following example indicates the level of commitment required
to have a real impact at the national level: Let us suppose that Fiji sets as a national
target a reduction of energy imports of 5% in 2007 compared to 2003 through energy
efficiency measures. This would represent a savings in imported fuels of about 25,000
toe. If these savings are produced by investments with an average payback period of 4
years, Fiji would need to mobilize at least $US 30 million in new investments. In today’s
context of rocketing oil prices, the Government and DOE need to work to dramatically
increase the pace of energy efficiency improvements and the means to implement them.
•
Awareness raising and communication are vital activities needed to help economic
actors determine the stakes and means of improving energy efficiency. In the context of
severe budgetary restrictions, it is important to devote efforts towards the targets and
sectors where the impact will be the strongest. Communication, as an instrument to help
orient consumer choice, is effective only if the consumer can actually make a choice in a
market situation. Before engaging in consumer awareness raising, it is vital that the
market offers the consumer the means to achieve a higher efficiency of energy use once
the consumer is motivated to do so.
•
A national energy balance is an information and decision-making tool. The preparation of
the national energy balance should respect international standards and serve to inform
the various economic actors (Government, utilities and industrial operators) of the
situation in the energy sector. The energy balance should be published each year and it
should be accompanied by an analysis of the evolution of consumption in the various
sectors and an analysis of changing energy costs and tariffs. It is also useful that every
2-3 years, the energy analysis is coupled with an energy forecast that highlights the
energy and environmental stakes that result from demographic, economic, technical and
international changes. This does not require a large budget but does need a qualified
and motivated person, reliable and comprehensive data resources and a dedicated
effort. It constitutes the essential starting point of the more elaborate activity of
establishing global and sector-based energy performance indicators. It is an activity of
high priority for DOE in the present context where budgetary restrictions prevail and are
likely to continue. It offers, at a reasonable cost, an efficient means to influence the
policies and decisions of other ministries and the Government in a direction more
favorable to energy efficiency. It would also permit DOE to reinforce and legitimate its
discourse and arguments in the national development debates in which it participates.
Appendix 4 - 9
•
DOE’s energy auditing activities should be done through the private sector and based on
market demand. The mobilization of technical resources and measurements should be
handled by an engineering firm, not directly by DOE staff. The audits are a detailed and
time-consuming task that undermines the real mission of DOE, which is to act on a
national scale, not through micro-level case by case efforts. On the other hand, at the
macro level, a new activity should be developed alongside the energy balance, energy
indicators and energy forecast activities described above: the monitoring and evaluation
of governmental action in the field of energy efficiency.
32. International co-operation programs should not be considered as substitutes to national
energy efficiency efforts but should be integrated into a comprehensive national strategy. If
these programs are to have a genuine impact, they will have to be inscribed within the
framework decided by the Government and implemented by DOE in conjunction with other
national institutional and economic actors. Program content should be developed by DOE, not
proposed by international agencies for acceptance by DOE. Regional programs also have the
disadvantage of temporarily increasing the financial means available for various types of action.
Once the project is completed, the local initiative in the affected sector quickly disappears. A
small budgetary allocation is required specifically to develop strategies and communicate them
to external funding sources. This would help the DOE to receive the maximum benefit from
international co-operation and to preserve its own assets by reducing the “stop and go” effect.
33. As a conclusion, at national level, any institution established to bear the responsibility for
improving energy efficiency should have a small but high qualify staff, be endowed with
legitimacy and regulatory power through legislation, and have broad autonomy and suitable
human and financial resources to carry out its tasks. Furthermore, It should not be the task of
DOE to carry out projects itself, but to create suitable conditions for projects to be executed by
public and private agents and to ensure that they have maximum impact in terms of technical,
economic, financial, social and environmental efficiency.
III.
IMMEDIATE STRATEGY RECOMMENDATIONS
34. Although the structural changes noted above are needed for the DOE to become the major
national force for the improvement of energy efficiency in Fiji, those changes are likely to be
slow in coming and are also not likely to occur at all unless DOE is able to show that its existing
resources are utilized effectively. The strategy for energy efficiency activities needs to be one
that leverages the modest resources presently available through the motivation of businesses
and individuals to participate in a program for the improvement of energy efficiency. There are
several ways DOE can do this:
•
Through the use of bilateral and multilateral donor money for activities that the DOE
does not have resources to perform by itself. This can be done through the preparation
of a strategic energy efficiency plan and then writing project proposals that follow the
plan (Leveraging donor money)
•
By improving the business climate for the development of private sector involvement in
the promotion of energy efficiency in commerce and industry. Promotion of the EESCO
project developed by the REEP is an example of this. (Leveraging private investment)
•
By insisting on participating in the development of building codes, transport systems and
other activities that have a major impact on energy use to ensure that their development
considers energy efficiency. (Leveraging through regulation)
•
By working with importers and retailers to assist in their marketing of energy efficiency
improvement products through high leverage actions such as the development of
Appendix 4 - 10
advertising for energy efficient products that can be included in retailer media
advertising, the inclusion of advertising for energy efficiency products with utility bills,
appliance labeling, requiring increased import duties on low efficiency appliances, etc.
(Leveraging through the marketplace)
•
Through development of school programs that involve children in the improvement of
home energy use (Leveraging through family participation)
•
Through the support of training programs at FIT, TPAF and other training facilities that
focus on energy efficiency improvement technologies (Leveraging through implementer
awareness)
•
Through adjustments in import duties, tax structures and regulations to place energy
efficient products in a better market position than inefficient products. (Leveraging
through market structuring)
•
Development of revised guidelines and procedures for Government’s existing program of
subsidies , tax holidays and tax rebates to include an energy efficiency incentive for
business investments (Leveraging through investment policies)
•
Development of an energy efficiency improvement plan for government that is mandated
by Cabinet and managed by DOE but carried out by individual government departments
using their own budgets (Leveraging through mandate)
35. Each of the above actions can be carried out with limited funds and a small number of
professional staff but can yield significant improvements in national energy efficiency, far more
than can be achieved by using DOE resources for direct interventions such as energy audits of
individual premises or the purchase of energy efficiency equipment and its installation.
36. To develop and carry out programs of this type, DOE staff do not need high level technical
competency. That is available in the private sector, if necessary through short term contracts.
What is needed at DOE are planning and management skills, an ability to set realistic goals and
the skills necessary to design a process to reach those goals while engaging as many external
resources as possible.
37. Additionally, it is important to include a process for monitoring and assessing the programs
that are put into action. The resulting information is important for the improvement of future
activities and for justifying future budget allocations as well as simply giving DOE and
Government feedback regarding the relative success of their efforts.
A.
Recommendations for immediate action
38. The first action that needs to be taken is to prepare a detailed energy efficiency
development strategy/plan for the next five to ten years with great detail included in the first and
second year and decreasing detail as the plan extends farther into the future. The strategy
should focus on achieving the maximum results possible with the available staff and financial
resources while gradually increasing staff and budget allocations for energy efficiency
programs.
39. If there is to be high leverage of the modest resources at DOE, staff at DOE should have
minimal involvement with the actual implementation of energy efficiency interventions. The rate
of return on energy efficiency investments are typically very good and the private sector will take
action to gain those high returns provided the barriers that have prevented their implementation
in the past are removed. DOE’s primary role should be lowering those barriers and smoothing
the way for private implementation. The type of activities to be engaged in directly by the DOE
should only be ones that are important but are unlikely to be carried out by the private sector. In
general, household energy efficiency improvements are unlikely to be addressed by the private
Appendix 4 - 11
sector, at least without specific incentives. Non-commercial transport efficiency improvement is
also unlikely to be carried out by the private sector. Yet both private transport and household
energy use have large opportunities for improvement. In those cases the DOE will need to
directly administer the programs though the activities should be mostly done under contract, not
done directly by DOE staff. In the case of transport, DOE should work closely with the LTA.
40. Once the most efficient time line of activities is determined and agreed by Government,
specific programs should be developed to carry out the plan. This may be in the form of project
proposals to donor agencies, allocation of time and budget within DOE for the programs,
contracting to external organizations for services or interaction with other Government agencies.
41. The strategy also should consider the time scale for the preparation and implementation of
each activity. For example, the highest leverage opportunity probably is the involvement of the
private sector in implementing energy efficiency through EESCOs or comparable private sector
actions. However, this is a relatively long term process with several years needed to develop the
necessary external funding support, the local training capacity and the legal structures
necessary for its success. Activities are likely to be spread out over several years so at any
given time the resources needed are small. On the other hand, market leverage through
mandatory appliance labeling, retailer involvement and tax structuring is already well along in
development and can be implemented fairly quickly but a concentrated effort will be needed.
School programs, if oriented toward actual home efficiency improvements (e.g. student home
energy audits with vouchers for the subsidized purchase of CFLs or other efficiency improving
devices) can be implemented in a year or less using mostly outside contractors with little staff
time necessary. The objective of the plan should be to interleave several high leverage and high
visibility programs, each having different time and resource schedules, so that staff are
continuously engaged and available funding most efficiently utilized over the fiscal year.
42. The plan should provide for DOE involvement in all aspects of an activity. For example,
encouraging EESCO development will require market surveys (to show companies that there is
sufficient market for their services and to determine the type of services needed), working with
financial institutions (to educate them regarding the technologies and risks associated with
energy efficiency investments and to determine if other types of support are needed), arranging
for training for EESCO personnel (to lower the risk of failed implementations and to improve the
confidence of recipients that the interventions will work), development of a process for
measuring the performance of an intervention (to show that the payment for the intervention is
appropriate to the benefits) and working with recipients and EESCOs to ensure that a process is
in place to maintain the benefits provided by the intervention. Engaging in just one component,
such as just doing energy audits, has a high risk of failure due to problems in other associated
areas such as finance, monitoring, component selection, maintenance, etc. In the example
given of a school program, providing information to students about energy efficiency
improvement will have little effect if there is no follow-up home action tied to the information and
the home action will have little effect if the components to carry out the efficiency improvement
are not immediately available for purchase at an acceptable price.
43. It is also recommended that the initial activities chosen have a high probability of success
and good publicity value. Future government funding for the DOE energy efficiency activities will
be largely determined by the perceived success of the DOE programs. Choosing high return but
obscure program types may result in lower budget allocations than lower return programs that
are very visible and clearly beneficial. Once DOE gains a good reputation for its energy
efficiency activities, projects that are lower in visibility but offer high returns will be more
acceptable to the people who allocate Government funds.
Appendix 4 - 12
44. Considering the above criteria, a reasonable five year action plan would be:
Year 1:
•
Fast track efforts on mandatory appliance labeling for refrigerators and freezers with
attention to all segments of the process from foreign exporters through customs,
importers/wholesalers, retailers, finance institutions, and ending at the consumer level.
•
Initiate a high visibility, low risk program for consumers such as the school student audit
program outlined above.
•
Carry out a market survey to determine the type and extent of EESCO services that are
needed in commerce and industry. Using that market information, lobby for the concept
of EESCO development with donors, ADB and SOPAC with the goal of getting the
necessary resources to get the REEP program funded and operational over the next two
years.
•
Design a comprehensive government facilities energy efficiency improvement program
that can be administered by DOE but carried out through investment by each agency to
improve its own energy use. This may require cooperation with the Ministry of Finance to
develop a program of incentives for various departments and government bodies.
•
Draft legislation to formalize the mandate for DOE to be the focus for energy efficiency
improvement activities. Include the necessary regulatory powers as relates to appliance
labeling and import controls, government facility energy efficiency programs, EESCO
operations, etc.
•
Survey commercial/industrial technical training institutions to determine their need for
facilities, instructor training and training materials to provide energy efficiency training for
implementing and monitoring technicians. Develop a project proposal for the
development of the energy efficiency training capacity.
•
Work with the FTIB to develop a practical program which links government investment
incentives to improved energy efficiency in the company receiving subsidies.
Year 2:
•
Complete the comprehensive program for appliance efficiency improvement and
implement the basic labeling process whereby all imported refrigerators and freezers
have a label showing their relative energy efficiency.
•
Get Cabinet support for the DOE designed government energy efficiency program and
work with agencies to develop plans and budgetary allocations for their efficiency
improvement programs.
•
Follow up on the consumer program carried out in year 1 with further publicity and
incentives.
•
Continue to promote the development of an EESCO support program to international
funding institutions.
•
Work to get the legislation passed that was submitted in year 1
•
Work in association with the rural electrification program to improve fuel efficiency of
village diesel generators and to improve the efficiency of the use of the energy provided
by the installed generators.
Appendix 4 - 13
Year 3:
•
Assist government agencies in obtaining auditing services and establishing a program
for agency energy efficiency improvement. Do a base-line survey of energy use in each
agency.
•
Assuming funding has been found for EESCO development, initiate the program by
requiring government agencies to use EESCOs for the development of their energy
efficiency actions.
•
Assuming the proposed legislation is passed, develop import regulations that are
designed to increase the average efficiency of imported air-conditioning equipment and
household appliances.
•
Using the experience gained through the refrigerator and freezer labeling program,
commence development of an expanded labeling process covering additional
appliances.
•
Request additional staff and budget to handle the expanded energy efficiency activities
•
Work with the Land Transport Authority to prepare programs to improve private transport
efficiency through incentives and regulations.
Year 4:
•
Support the EESCOs by assisting in the marketing of their services through market
surveys and inexpensive “walk through” audits that show users the general scope for
improvement.
•
Implement the broader range of appliance labeling. Put into effect the year 3 import
regulations that are intended to improve the average energy efficiency of air-conditioners
and other high energy use commercial equipment.
•
Initiate a dialogue with local shipping companies and airlines to determine the possible
actions that can improve the energy efficiency of sea and air transport.
•
Seek funding for land transport efficiency programs designed by and to be carried out
jointly with the LTA.
•
Monitor government agency energy use and determine the effectiveness of the
interventions.
Year 5:
•
Carry out a household energy use survey in urban areas with significant samples from
low income, middle income and high income households. Using the survey data
determine the gaps in knowledge and application of energy efficiency measures for
households. Determine the current barriers to further implementation of energy efficiency
activities at the household level.
•
Design a program to address lowering of the barriers found and seeks funds for its
implementation.
•
Administer existing programs for appliance efficiency improvement, EESCO regulation,
training, air-conditioner efficiency improvement and land transport efficiency
improvement.
•
Develop proposals for air and sea transport energy efficiency improvements and seek
funding for their implementation.
Appendix 5 - 1
APPENDIX 5
SURVEY OF STANDARDS AND CERTIFICATION SYSTEMS FOR ENERGY
EFFICIENCY AND RENEWABLE ENERGY
Appendix 5 - 2
Survey of Existing Standards and Certification Methods Used for Renewable
Energy and Energy Efficiency.
I.
CONCEPTS
A.
Energy efficiency labels
1. The purpose of energy efficiency labels is to provide customers with accurate information on
energy consumption of the appliances that are offered on the consumer market. It is
expected they will then be encouraged to choose the most efficient products.
2. The mode of operation of a labelling strategy is to influence consumer’s purchase decisions
through large public information campaigns explaining the value of energy savings at the
consumer level. The quality of design of a label is a key aspect of its acceptance by the
public at large. Labels are also intended to influence manufacturers, importers and retailers
in production processes and marketing strategies toward more efficient appliances.
3. Energy labels can be categorized in three types:
•
Information-only labels: they provide information on energy performance or energy
efficiency of an appliance, but do not give any numerical basis for direct comparison with
competing products.
•
Comparison labels : in addition to information on energy performance or energy
efficiency, these labels provide a basis for comparison between products of similar types
ranked on a categorical scale (e.g. Class A, B, C,) or a continuous scale (e.g. energy
consumption in kWh/year). These labels are particularly suitable when energy
consumption may vary widely for the same category of product. Typical cases for this
type of label application are refrigerators and air conditioners.
•
Endorsement labels : these labels work like a seal of approval that the product belongs
to the an energy efficient class of products. They do not give any more detailed
information on energy performance other than meeting basic class criteria.
4. Table 1 (tables are at the end of this Annex) shows examples of information-only labels,
comparison labels and endorsement labels, in different countries.
B.
Standards
5. Standards consist of regulations and procedures that products or systems must comply with.
Sets of standards are designed specifically for each product class (refrigerator, lighting
appliances, solar water heater, etc.).
6. There are three main types of standards :
prescriptive standards: these standards require a particular feature or device to be installed in
all new products. They can also require a product to pass specific testing procedures.
minimum energy performance standards (MEPS): the MEPS prescribe minimum efficiencies (or
maximum energy consumption) values that products must meet before they can be legally sold.
fleet-average or class-average standards: these standards prescribe that a sales-weighted
average energy efficiency, based on all the models of the same product class, must be
achieved or exceeded by each manufacturer.
Appendix 5 - 3
7. Prescriptive standards and MEPS may be combined and attached to the same product
class. For instance for a PV solar home system, prescriptive requirements can be put on PV
modules and MEPS criteria prescribed for daily energy output of the whole system.
8. MEPS and fleet-average standards represent two different ways to measure energy
performance of electric appliances. In general MEPS are used mostly in Europe and North
America while fleet-average standards have been used mainly in Japan and Switzerland.
MEPS or fleet-average standards define only the performance targets and not the
technologies or design to use, that remains the manufacturer’s responsibility. Thus
standards of these types do not deter technological innovation.
C.
Regulatory issues
9. The main regulatory issues are to decide:
•
which labels and standards are to be implemented
•
whether labels and standards should be voluntary or mandatory.
•
Whether MEPS should be set at high or low levels
10. Because they apply to mass produced goods, labels and standards can have a very large
impact on the energy consumption structure at the national level. The key point is to identify
what are the best targets. For instance in Samoa where lighting, refrigeration and air
conditioning represent 67% of domestic consumption and 38% of total sales of electricity, it
can reasonably be expected to achieve mid to long term substantial benefits on the energy
balance by introducing labels and standards for these categories of appliances and actively
promoting them through public information programs.
11. It can be tempting to impose mandatory labels and high levels of standards to impact the
energy consumption on the short term. But doing so can be inefficient if the actors and the
market structure are not prepared to these changes. For instance, in Samoa where many of
the refrigerators purchased are second hand (mainly from New Zealand and Australia) units
because price is the most important buying criteria for the purchasers, setting immediate
high mandatory MEPS that apply to all refrigerator imports would result in severely
restricting the choice of consumers to new, much more costly – and possibly unaffordable –
refrigerators a situation that would be unacceptable from a social perspective.
12. Decisions about labels and standards must be taken by the authorities at the country level
based on the best compromise between energy savings targets, the economic situation,
social and cultural data, political orientations and the ability of the government to enforce
them. For this reason, these decision should be the result of a consultative process among
all the actors including consumers, the private business sector, industry and Government.
Ref. [4] gives an example of such a process for labelling room air conditioners as was used
in Ghana.
13. Experience indicates that a good way to start with is to combine labelling and rather low
MEPS strategies. Labelling alone will have only limited impact and putting too high a level
of MEPS right from the start may block the expected market transformation.
14. Table 2A and Table 2B (tables are at the end of this Annex), extracted from Ref. [2], reflects
the diversity of approaches found in the world regarding the mandatory or voluntary nature
of labels and standards . From the table it can be seen that:
Appendix 5 - 4
endorsement labelling is generally on a voluntary basis, while comparison labels are rather
mandatory ;
MEPS are already made mandatory in a large number of countries.
D.
Implementation schemes
15. The success of labelling programmes is dependent on fully implementing all aspects of the
process. In [Ref.1], the following step-by-step procedure to develop standards and
procedure is proposed:
I. decide whether and how to implement energy-efficiency labels and standards: such a
decision needs to be based on clear assessments including (i) social, institutional and
regulatory environment regarding labels and standards, (ii) the government’s capacity to
implement and enforce labelling, (iii) the availability of statistical data needed to design
the labels and standards, and (iv) the products to target with the highest priority.
II. develop a testing capability, which means designing test procedures and building a
testing centre for the selected products. That does not mean starting from zero, but
rather adapting existing work to the specificities of the country, and even relying on
testing centres from outside or on private laboratories (this approach be particularly
relevant in the context of small-scale economies like those of Fiji and Samoa)
III. design and implement labelling programs: the detailed knowledge of consumer sociocultural preferences and the way they are reflected in the label design is a key condition
for a successful impact.
IV. analyse and set standards programs : setting standards will be the result of different
types of analyses : (i) engineering analysis (energy performance), (ii) national impact
analysis (energy balance, environmental benefits, social cost-benefits), (iii) consumer
analysis (impact on the consumer's welfare), (iv) manufacturers and retailers analysis
(impact on the commercial activity).
V. maintain and enforce compliance : ensuring the effective application of the labels and
standards will need the implementation of controlling and regulating capacities at the
national level by an agency having adequate capacity and competence. The
requirements for achieving this capacity and competence have to be identified.
VI. Monitor and continuously evaluate the label and/or standards setting program: after the
labels and standards are set, feedback information will be needed to assess their impact
and identify possible corrective measures where problems are seen. Monitoring and
analysis procedures have to be designed for this purpose and resources assigned to
carry them out.
II.
STANDARDS AND CERTIFICATION METHODS
16. Tables 3A and 3B (tables are at the end of this Annex) present a summary of standards and
certification methods used internationally for energy efficiency and renewable energy.
Appendix 5 - 5
17. The main international organizations issuing standards and certification methods at the
international level are:
•
The International Organization for Standardization (ISO). It is the world's largest
developer of standards.
•
The International Electrotechnical Commission (IEC). The IEC is the leading global
organization that prepares and publishes international standards for all electrical,
electronic and related technologies.
•
The Institute of electrical and electromechanical engineers (IEEE). A non-profit, technical
professional association that is a leading authority for a wide range technical areas
including computer engineering, biomedical technology, telecommunications, electric
power, aerospace and consumer electronics.
•
The Global Approval Program for Photovoltaics (PV GAP). PV GAP is a non-profit
international organization that certifies the quality of PV systems and components. It is
dedicated to the sustained growth of global photovoltaics (PV) markets to meet energy
needs world-wide in an environmentally sound manner.
A.
Energy efficiency
18. For energy efficient appliances, prescriptive requirements will generally be related to
compliance with general safety ISO/IEC standards set for each product category of
appliance.
19. Performance criteria will generally be expressed in MEPS for given standard operating
conditions that should be representative of the environment in the country. For example, a
MEPS performance criteria for room air conditioners is the Energy Efficiency Ratio (EER).
20. Standards and certification procedures for appliances are normally defined at the national
level but are typically based on internationally accepted methods of implementation. Test
protocols, for example, have been published by the ISO for numerous categories of
appliances.
B.
Renewable energy
1.
Solar water heaters
21. For solar water heaters (SWH), prescriptive requirements are typically related to component
specifications regarding food and health regulations (use of drinkable water, authorized
insulation material), corrosion resistance and other specific material and design tests that
must be passed.
22. Performance criteria will be expressed through:
•
the yearly energy output under standard climatic conditions (energy delivered/year),
•
the solar energy factor (percentage of the energy provided by the SWH vs. total energy
required for water heating),
•
or in the case of large commercial or industrial SWH, a guarantee of performance
(minimum acceptable energy delivery/year)
Appendix 5 - 6
23. Joint efforts at the regional level have lead to the design of international testing protocols
and certification methods such as those developed by the ALTENER and Solarkeymark
projects in Europe, or by the Solar Rating and Certification Corporation in the USA.
2.
Photovoltaic systems
24. For photovoltaic systems, prescriptive requirements will typically concern:
•
component specifications: compliance to general ISO standards (e.g. for PV modules),
specific requirements (e.g. linked to environmental constraints such as the marine
environment of the Pacific islands), technical features of components, metering devices
(e.g.. for grid-connected systems), etc.
•
sizing and balance-of-system rules such as reference to the solar radiation
characteristics, the ratio between PV module power and battery capacity, and the
maximum acceptable electrical losses.
•
installation rules including the agreement of technicians to follow the rules, on site
training of users or beneficiaries, methodology for installation.
•
after-sales services: commercial warranties on components, and system energy
availability and tariff, availability and location of basic spare parts and requirements for
the proper training for service personnel.
25. Performance criteria will be mainly related to the mean daily or yearly performance
(kWh/day or kWh/yr) and the time the system can operate from fully charged conditions with
no sun (in days, applies only to stand-alone systems with energy storage).
3.
Wind energy
26. For wind energy systems, prescriptive requirements will typically involve:
•
safety requirements,
•
design of components: rotor, blades, gearbox, mechanical structure, etc.
•
compliance with local environmental regulation: noise level, noise measurement
procedures, noise declaration, etc.
•
performance: power performance and noise measurement techniques, etc.
27. Performance criteria will be mainly related to the total yearly energy output (MWh or TWh
per year) and statistical power availability according to the wind resource.
28. Grid-connected wind farms are now a fully mature RE technology for which a full set of IEC
norms and standards have been developed (IEC 61400)
III.
REFERENCES AND BIBLIOGRAPHY
[1] Energy efficient labels and standards: a guidebook for appliances, equipment and
lighting (Stephen Wiel and James E. MacMahon, Collaborating labelling and appliances
standards program, CLASP USA, 2001)
Appendix 5 - 7
[2] Energy labelling and standards throughout the world (Lloyd Harrington and Melissa
Damnics, The National Appliance and Equipment Energy efficiency committee, Australia, 2001)
[3] European test facilities for solar combisystems and heat store, (International Energy
Agency, 2002)
[4] Transforming the West African Market for Energy Efficiency: Ghana Leads the Way
with Mandatory Standards and Labels (CLASP – Ghana Energy Foundation, 2001)
[5] Operating guidelines and minimum standards for certifying solar water heating
systems (SRCC Document OG-300, Solar Rating and Certificating Corporation, 2002)
[6] Universal technical standards for solar home systems (Thermie B SUP 995-96, ECDGXVII, 1998)
[7] Survey of national and international standards, guidelines and QA procedures for
stand alone PV systems (IEA PVPS T3-07:2000, 2000)
[8] Standards for renewable energy generation (Vergnet SA, 2004)
Appendix 5 - 8
Table 1 – Samples of energy efficiency labels
Appendix 5 - 9
Table 2A
Appendix 5 - 10
Table 2B
Appendix 5 - 11
Table 3A
Appendix 5 - 12
Table 3B 2.1 Interconnection
IEEE 1547
IEEE P1547.1
IEEE P1547.2
IEEE P1547.3
Standard for interconnecting Distributed resources with electric power systems
Draft Standard for Conformance Test Procedures for Equipment Interconnecting Distributed Resources with Electric Power Systems
Application Guide for IEEE Std.1547 Standard for Interconnecting Distributed Resources with Electric Power Systems
Guide for monitoring, information exchange and control of distributed resources interconnected with electric power systems.
2.2 Hybrid Systems
IEEE P1561
Guide for sizing Stand-Alone Hybrid Energy Systems
2.3 Photovoltaic
IEC 60364-7-712
Electrical installations of buildings - Part 7-712: Requirements for special installations or locations - Solar photovoltaic (PV) power supply systems
IEC-EN
IEC-EN
IEC-EN
IEC-EN
IEC-EN
60891
60904-1
60904-2
60904-3
60904-5
IEC-EN 60904-6
IEC-EN 60904-7
IEC-EN 60904-8
IEC-prEN 60904-9
IEC-EN 60904-10
IEC-EN 61173
IEC-EN 61194
IEC-EN 61215
IEC-EN 61277
IEC-EN 61345
IEC 61427
IEC-EN 61646
IEC-EN 61683
IEC-EN 61701
IEC-EN 61702
IEC-EN 61721
IEC-EN 61724
Procedures for temperature and irradiance corrections to measured I-V characteristics of crystalline silicon photovoltaic devices
Photovoltaic devices. Part 1: Measurement of photovoltaic current-voltage characteristics
Photovoltaic devices. Part 2: Requirements for reference solar cells
Photovoltaic devices. Part 3: Measurement principles for terrestrial photovoltaic (PV) solar devices with reference spectral irradiance data
Photovoltaic devices. Part 5: Determination of the equivalent cell temperature (ECT) of photovoltaic (PV) devices by the open-circuit voltage
method.
Photovoltaic devices. Part 6: Requirements for reference solar modules
Photovoltaic devices. Part 7: Computation of spectral mismatch error introduced in the testing of a photovoltaic device
Photovoltaic devices. Part 8: Measurement of spectral response of a photovoltaic (PV) device
Photovoltaic devices. Part 9: Solar simulator performance requirements
Photovoltaic devices. Part 10: Methods of linearity measurement
Overvoltage protection for photovoltaic (PV) power generating systems. Guide
Characteristic parameters of stand-alone photovoltaic (PV) systems
Crystalline silicon terrestrial photovoltaic (PV) modules – Design qualification and type approval
Terrestrial Photovoltaic (PV) power generating systems – General Guide
UV test for photovoltaic (PV) modules
Secondary cells and batteries for solar photovoltaic energy systems – General requirements and method of test
Thin film terrestrial photovoltaic (PV) modules – Design qualification and type approval
Photovoltaic systems – Procedure for measuring efficiency
Salt mist corrosion testing of photovoltaic (PV) modules
Rating of direct coupled photovoltaic (PV) pumping systems
Susceptibility of a photovoltaic (PV) module to accidental impact damage (resistance to impact test)
Photovoltaic system performance monitoring. Guidelines for measurement, data exchange and analysis
Appendix 5 - 13
IEC-EN 61727
IEC-prEN 61730-1
IEC-prEN 61730-2
IEC-EN 61829
IEC 61836
IEC 61853
IEC-prEN 62093
IEC 62108
IEC 62109
IEC 62116
IEC-prEN 62124
IEC 62145
IEC 62234
IEC 62253
EN 50380
IEEE 928
IEEE 929
IEEE 937
IEEE 1013
IEEE 1144
IEEE 1145
IEEE 1262
IEEE P1361
IEEE 1374
IEEE P1479
IEEE 1513
IEEE P1526
IEEE P1562
UL 1703
Photovoltaic (PV) systems. Characteristics of the utility interface.
Photovoltaic module safety qualification – Part 1: Requirements for construction
Photovoltaic module safety qualification – Part 2: Requirements for testing
Crystalline silicon photovoltaic (PV) array. On site measurement of I-V characteristics.
Solar photovoltaic energy systems – terms and symbols
Performance testing and energy rating of terrestrial photovoltaic (PV) modules
Balance-of-systems components for photovoltaic systems – Design qualification and type approval
Concentrator photovoltaic (PV) receivers and modules – Design qualification and type approval
Electrical safety of static inverters and charge controllers for use in photovoltaic (PV) power systems
Testing procedure – Islanding prevention measures for power conditioners used in grid connected photovoltaic (PV) power generation systems
Photovoltaic (PV) stand alone systems – Design Verification
Crystalline silicon PV modules – Blank detail specification
Safety guidelines for grid connected photovoltaic (PV) systems mounted on buildings
Direct coupled photovoltaic pumping systems – Design qualification and type approval
Datasheet and nameplate information for photovoltaic modules
IEEE Recommended Criteria for terrestrial photovoltaic power systems
IEEE Recommended Practice for Utility Interface of Residential and Intermediate Photovoltaic (PV) Systems
IEEE Recommended Practice for Installation and Maintenance of Lead-Acid Batteries for Photovoltaic (PV) Systems
IEEE Recommended Practice for Sizing Lead-Acid Batteries for Photovoltaic (PV) Systems
IEEE Recommended Practice for Sizing Nickel-Cadmium Batteries for Photovoltaic (PV) Systems
IEEE Recommended Practice for Installation and Maintenance of Nickel-Cadmium Batteries for Photovoltaic (PV) Systems
IEEE Recommended Practice for Qualification of Photovoltaic (PV) Modules
Guide for the selection, test and evaluation of lead acid batteries for stand-alone photovoltaic (PV) systems
IEEE Guide for terrestrial photovoltaic power system safety
Recommended practice for the evaluation of photovoltaic (PV) module energy production
IEEE Recommended Practice for Qualification of Concentrator Photovoltaic (PV) Receiver Sections and Modules
IEEE Recommended Practice for Testing the Performance of Stand Alone Photovoltaic Systems
Guide for array and battery sizing in Stand - Alone Photovoltaic (PV) Systems
Flat-Plate Photovoltaic Modules and Panels
2.4 Wind Turbine
IEC 60050-415
IEC WT 01
IEC-EN 61400-1
IEC-EN 61400-2
IEC 61400-3
IEC 61400-4
IEC-EN 61400-11
IEC-EN 61400-12
IEC 61400-13
International electrotechnical vocabulary – Part 415: Wind turbine generator systems
IEC System for conformity testing and certification of wind turbines – Rules and Procedures
Wind turbine generator systems. Part 1: Safety requirements
Wind turbine generator systems. Part 2: Safety of small wind turbines
Wind turbine generator systems. Part 3: Design requirements for offshore wind turbines
Wind turbine generator systems. Part 4: Design requirements for gearboxes for wind turbines
Wind turbine generator systems. Part 11: Acoustic noise measurement techniques
Wind turbine generator systems. Part 12: Wind turbine power performance testing
Wind turbine generator systems. Part 13: Measurement of mechanical loads
Appendix 5 - 14
IEC 61400-14
IEC-prEN 61400-21
IEC 61400-23
IEC 61400-24
IEC 61400-25
IEC 61400-121
prEN50308
prEN50376
2.5 Fuel Cells
IEC-EN 61982
IEC-prEN 62282
UL 2262
2.6 Small hydro
IEC-EN 61116
IEC 62006
IEEE 1020
2.7 Converters
IEC-EN 60146-1-1
IEC 60146-1-2
IEC-EN 60146-2
Wind turbine generator systems. Part 14: Declaration of sound power level and tonality values
Wind turbine generator systems. Part 21: Measurement and assessment of power quality characteristics of grid connected wind turbines
Wind turbine generator systems. Part 23: Full-scale structural testing of rotor blades
Wind turbine generator systems. Part 24: Lightning protection
Wind turbine generator systems. Part 25: Communication standard for remote control and monitoring of wind power plants
Wind turbine generator systems. Part 121: Power performance measurements of grid connected wind turbines
Wind turbines - protective measures – requirements for design, operation and maintenance
Declaration of sound power level and tonality values of wind turbines
Secondary batteries for the propulsion of electric road vehicles – Part 3: Performance and life testing (traffic compatible, urban use vehicles)
Fuel cell technologies
Portable proton exchange membrane (PEM) type fuel cell power plants with or without uninterruptable power supply (UPS) features and portable
proton exchange membrane (PEM) type fuel cell modules for factory installation in original equipment manufacturer (OEM) type equipment for
indoor use
Electromechanical equipment guide for small hydroelectric installations
Hydraulic machines - Acceptance tests of small hydro turbines
IEEE Guide for Control of Small Hydroelectric Power Plants
Semiconductor converters – General requirements and line commutated converters - Part 1-1: specifications of basic requirements
Semiconductor converters – General requirements and line commutated converters - Part 1-2: Application guide
Semiconductor converters – General requirements and line commutated converters - Part 2: Self – commutated semiconductor converters
including direct d.c. converters
IEC 60146-6
Semiconductor converters – General requirements and line commutated converters - Part 6: Application guide for the protection of semiconductor
converters against overcurrent by fuses
IEC 62109
IEC 62116
UL 1741
Electrical safety of static inverters and charge controllers for use in photovoltaic (PV) power systems
Testing procedure – Islanding prevention measures for power conditioners used in grid connected photovoltaic (PV) power generation systems
Inverters, Converters, and Controllers for Use in Independent Power Systems
2.8 Batteries
IEC 60050-481
IEC 60050-486
IEC-EN 60086
IEC-EN 60095
IEC-EN 60254
IEC-EN 60622
IEC-EN 60623
International Electrotechnical Vocabulary – Part 481: Primary cells and batteries
International Electrotechnical Vocabulary – Part 486: Secondary cells and batteries
Primary cells and batteries
Lead acid starter batteries
Lead acid traction batteries
Secondary cells and batteries containing alkaline or other non-acid electrolytes – Sealed nickel-cadmium prismatic rechargeable single cells
Secondary cells and batteries containing alkaline or other non-acid electrolytes – Vented nickel-cadmium prismatic rechargeable single cells
Appendix 5 - 15
IEC-EN 60896
IEC-EN 61056
IEC/TR2 61430
Stationary lead acid batteries – General requirements and test methods
General purpose lead-acid batteries (valve-regulated types)
Secondary cells and batteries – Test methods for checking the performance of devices designed for reducing explosion hazards – Lead-acid
starter batteries
IEC/TR3 61431
IEC-EN 61434
Guide for the use of monitor systems for lead-acid traction batteries
Secondary cells and batteries containing alkaline or other non-acid electrolytes – Guide to designation of current in alkaline secondary cell and
battery standards
IEC-EN 61660-1
IEC 62060
EN 50272
IEEE 485
IEEE 1106
Short-circuit currents in d.c. auxiliary installations in power plants and substations – Part 1: Calculation of short-circuit currents
Secondary cells and batteries – Monitoring of lead acid stationary batteries – User guide
Safety requirements for secondary batteries and battery installations
IEEE Recommended Practice for Sizing Lead-Acid Batteries for Stationary Applications
IEEE Recommended Practice for Installation, Maintenance, Testing and Replacement of vented nickel-cadmium batteries for stationary
applications
IEEE 1115
IEEE Recommended Practice for Sizing Nickel-Cadmium Batteries for Stationary Applications
2.9 UPS
IEEE 446
IEEE 1184
IEEE Recommended Practice for Emergency and Standby Power Systems for Industrial and Commercial Applications
IEEE Guide for the Selection and Sizing of Batteries for Uninterruptible Power Systems
2.10 Cogeneration
IEEE 502
UL 2200
IEEE Guide for Protection, Interlocking, and Control of Fossil-Fueled Unit-Connected Steam Stations
STANDARD FOR SAFETY Stationary Engine Generator Assemblies
2.11 Power Quality
EN 50160
IEC 61000-1-4
Voltage characteristics of electricity supplied by distribution systems
EMC – Part 1-4: Rationale for limiting power-frequency conducted harmonic and interharmonic current emissions from equipment, in the
frequency range up to 9 kHz
IEC-EN 61000-2-2
EMC – Part 2-2: Environment. Section 2: compatibility levels for low frequency conducted disturbances and signalling in public low-voltage power
supply systems
IEC-EN 61000-2-4
IEC/TR3 61000-2-6
EMC – Part 2-4: Environment. Section 4: Compatibility levels in industrial plants for low-frequency conducted disturbances
EMC – Part 2-6: Environment. Section 6: Assessment of the emission levels in the power supply of industrial plants as regards low-frequency
conducted disturbances
IEC/TR 61000-2-8
IEC-EN 61000-2-12
EMC – Part 2-8: Environment – Voltage dips and short interruptions on public electric power supply systems with statistical measurement results
EMC – Part 2-12: Environment. Section 12: Compatibility levels for low-frequency conducted disturbances and signalling in public medium-voltage
power supply systems
IEC/TR 61000-3-1
IEC-EN 61000-3-2
IEC-EN 61000-3-3
EMC – Part 3-1: Limits - Overview of emission standards and guides - Technical Report
EMC – Part 3-2: Limits – Limits for harmonic current emissions (equipment input current up to and including 16 A per phase
EMC – Part 3-3: Limits – Limitation of voltage changes, voltage fluctuations and flicker in public low-voltage supply systems, for equipment with
rated current <= 16 A per phase and not subject to conditional connection
Appendix 5 - 16
IEC/TS 61000-3-4
EMC – Part 3-4: Limits – Limitation of emission of harmonic currents in low-voltage power supply systems for equipment with rated current greater
than 16 A
IEC/TR2 61000-3-5
EMC – Part 3-5: Limits – Limitation of voltage fluctuations and flicker in low-voltage power supply systems for equipment with rated current greater
than 16 A
IEC/TR3 61000-3-6
IEC/TR3 61000-3-7
IEC 61000-3-9
EMC – Part 3-6: Limits – Assessment of emission limits for distorting loads in MV and HV power systems – Basic EMC publication
EMC – Part 3-7: Limits – Assessment of emission limits for fluctuating loads in MV and HV power systems – Basic EMC publication
EMC – Part 3-9: Limits for interharmonic current emissions (equipment with input power <= 16 A per phase and prone to produce interharmonics
by design)
IEC 61000-3-10
IEC-EN 61000-3-11
EMC – Part 3-10: Emission limits in the frequency range 2 ... 9 kHz
EMC – Part 3-11: Limits – Limitation of voltage changes, voltage fluctuations and flicker in public low-voltage supply systems – Equipment with
rated current <= 75 A per phase and subject to conditional connection
IEC-prEN 61000-312
EMC – Part 3-12: Limits for harmonic currents produced by equipment connected to public low-voltage systems with input current <- 75 A per
phase and subject to restricted connection
IEC-EN 61000-4-4
IEC-EN 61000-4-5
IEC-EN 61000-4-7
EMC – Part 4-4: Testing and measurement techniques – Electrical fast transient/burst immunity test
EMC – Part 4-5: Testing and measurement techniques – Surge immunity test
EMC – Part 4-7: Testing and measurement techniques – General guide on harmonics and interharmonics measurements and instrumentation, for
power supply and equipment connected thereto
IEC-EN 61000-4-11
IEC-EN 61000-4-13
EMC – Part 4-11: Testing and measurement techniques – Voltage dips, short interruptions and voltage variations immunity tests
EMC – Part 4-13: Testing and measurement techniques – Harmonics and interharmonics including mains signalling at a.c. power port, low
frequency immunity tests
IEC-EN 61000-4-14
IEC-EN 61000-4-15
IEC-EN 61000-4-16
EMC – Part 4-14: Testing and measurement techniques – Voltage fluctuation immunity test
EMC – Part 4-15: Testing and measurement techniques – Flickmeter – Functional design specifications
EMC – Part 4-16: Testing and measurement techniques – Test for immunity to conducted, common mode disturbances in the frequency range 0
Hz to 150 kHz
IEC-EN
IEC-EN
IEC-EN
IEC-EN
EMC
EMC
EMC
EMC
tests
61000-4-17
61000-4-27
61000-4-28
61000-4-29
IEC-prEN 61400-430
IEEE 519
IEEE 1159
IEEE 1250
IEEE 1346
IEEE P1409
IEEE P1453
IEEE P1495
IEEE P1564
– Part 4-17: Testing and measurement techniques - Ripple on d.c. input power port immunity test
– Part 4-27: Testing and measurement techniques – Unbalance, immunity test
– Part 4-28: Testing and measurement techniques – Variation of power frequency, immunity test
– Part 4-29: Testing and measurement techniques - Voltage dips, short interruptions and voltage variations on d.c. input power port immunity
EMC – Part 4-30: Testing and measurement techniques – Power quality measurement methods
IEEE Recommended Practices and Requirements for Harmonic Control in Electrical Power Systems
IEEE Recommended Practices for monitoring electric power quality
IEEE Guide for service to equipment sensitive to momentary voltage disturbances
IEEE Recommended Practices for evaluating electric power system compatibility with electronic process equipment
IEEE Guide for the application of power electronics for power quality improvement on distribution systems rated 1 kV through 38 kV
IEEE Recommended Practice for measurement and limits of voltage flicker on AC power systems
Standard for harmonic limits for single-phase equipment
IEEE Recommended Practice for the establishment of voltage sag indices
Appendix 5 - 17
2.12 Metering
IEC 60870-5-102
IEC 62056
IEC 61334-4
Telecontrol equipment and systems – Part 5: transmission protocols – section 102: companion standards for the transmission of integrated totals
in electric power systems
Electricity metering – Data exchange for meter reading, tariff and local control
Distribution automation using distribution line carrier systems – Part 4: Data communication protocols
Appendix 6 - 1
APPENDIX 6
PROPOSED STANDARDS FOR RESCO SHS INSTALLATION AND
MAINTENANCE
Appendix 6 - 2
TABLE OF CONTENTS
1.
BACKGROUND
3
2. GENERAL CONDITIONS
3
2.1. Service delivery indicators............................................................................................................3
2.2. System typology .............................................................................................................................3
2.3. Components of the SHS ................................................................................................................4
3. DOCUMENTATION
4
3.1. User manual .....................................................................................................................................4
3.2. Technician manual..........................................................................................................................5
4. REQUIREMENTS FOR INSTALLATION
6
4.1. General..............................................................................................................................................6
4.2. PV Array............................................................................................................................................6
4.3. Batteries ...........................................................................................................................................6
4.4. Lamps ...............................................................................................................................................7
4.5. Wiring................................................................................................................................................7
5. REQUIREMENTS FOR MAINTENANCE
7
5.1. Services ............................................................................................................................................7
5.2. Periodical routine visit ...................................................................................................................7
5.3. Repair visits .....................................................................................................................................9
6. MAINTENANCE REPORTING
9
6.1. Maintenance monthly report .........................................................................................................9
6.2. Maintenance annual report ...........................................................................................................9
Appendix 6 - 3
PROPOSED SPECIFICATIONS FOR RESCO SHS INSTALLATION AND MAINTENANCE
1.
BACKGROUND
Although these specifications could be used for any solar home system (SHS)
application, they are written specifically for the Renewable Energy Service Company
(RESCO) model implemented by the Fiji Department of Energy (DOE). This RESCO
model can be summarized as follows:
• Technical design, purchasing, and system ownership by DOE;
• Users are self-selected and clustered in groups of a size that is appropriate for
economically reasonable periodic maintenance by the RESCO;
• Users are required to pre-pay a monthly fee that covers an appropriate portion of
the capital cost of the installed system and the full cost of operation, maintenance
and repair of the systems;
• Maintenance and repair services are to be provided by private contractor RESCO
operators with technical support, evaluation, certification and regulation by the
DOE;
• Financial controls and technical controls will be put into place and administered
by the DOE to ensure continuing financial and technical responsibility by the
RESCO contractors;
• DOE will establish a continuing technical and business training process for
personnel of the RESCOs
2.
2.1.
2.1.1.
2.2.
2.2.1.
2.2.2.
GENERAL CONDITIONS
Service delivery indicators
The following service delivery indicators are to be provided for any proposed SHS :
a)
The daily energy service is the minimum energy daily available at the output
of the battery charge regulator, as guaranteed by the supplier, under the
Reference Climatic Conditions mentioned in the Tender documents. The daily
energy service is expressed in Watt-hour per day (Wh/day)
b)
The SHS operating autonomy is the minimum number of days during which
the system can provide the daily energy service starting from a 100% charged
battery, the PV array being disconnected from the battery charge regulator.
System typology
The categories of SHS to be provided within the RESCO program are :
a)
Category A - « basic » : minimum daily energy service of 225 Wh/day
b)
Category B - « standard » : minimum daily energy service of 450 Wh/day
The SHS operating autonomy must be at the minimum 5 days for any SHS category
Appendix 6 - 4
2.3.
2.3.1.
2.3.2.
2.3.3.
3.
3.1.
3.1.1.
Components of the SHS
The mandatory components of the SHS are :
a)
PV module(s)
b)
PV array mounting structure
c)
Battery(ies)
d)
Battery charge and discharge regulator
e)
Lamps in quantities defined in 2.3.3 below
f)
All wiring accessories: switches, cables, fasteners, junction boxes, etc.
g)
Enclosures
The optional components of the SHS are :
h)
DC outlet
i)
Prepayment system
j)
DC-AC inverters
Unless specified differently in the tender documents, the maximum number of lamps
to be provided in each SHS category are:
k)
SHS Category 1: four (4) lamps including one (1) outdoor
l)
SHS Category 2: seven (7) lamps including one (1) outdoor
DOCUMENTATION
User manual
The RESCO must provide all users a User’s Manual with simple functional
descriptions for the end-user. The manual must be in English and in local language.
The documentation should be simple and easy to understand. Sketches or graphics
should be used to make the manual user friendly. The documentation is to include
the following:
a)
How the SHS works: battery charging by the array, functions, battery low
voltage protection, and battery overcharge protection. The relationship
between energy available on a daily basis and sunlight conditions should be
clearly and simply explained.
b)
A description of all interactive hardware including disconnect switches and
status indicators.
c)
Procedures for proper system operation, including a list of load limitations and
any problem loads. These procedures should include suggested operation,
including load conservation, during periods of inclement weather, and/or a low
voltage disconnect event. The procedures for checking that the photovoltaic
array is not shaded and how to prevent shading must be explained. For
portable SHS, instructions must be given on how to orient the PV module to
maximize energy generation.
d)
Any user maintenance items.
Appendix 6 - 5
3.2.
3.2.1.
e)
Emergency shut down procedures and recommendations for extended
periods of system non-use.
f)
A user trouble shooting guide to be followed before calling the field technician.
g)
A block diagram showing the main components
Technician manual
The RESCO must prepare a Technician’s Installation, Operations and Maintenance
Manual to be used by the service technicians. The manual must be in English. The
manual will include the specific details on installation, operation and maintenance.
This will include:
a)
A detailed technical description of the system.
b)
A complete copy of the Users Manual.
c)
A complete list of all system components, with associated manufacturers
literature, specifications, and warranties.
d)
Complete installation instructions.
e)
Recommended post-installation acceptance test procedures, including all
appropriate set points and test procedures.
f)
They will include:
· Verification that the installation of the photovoltaic array with regard to
position, direction, inclination and shading avoidance will maximize energy
generation.
· Procedures to ensure that the battery has received an equalization charge
just before installation.
· How to use a shunt to measure the current and voltage from the array under
charging conditions to verify the array charging current. The shunt resistor
rating should be approximately equal to Vmp2/Wp. Where Vmp is the
voltage at maximum power point of the PV module and Wp is the Peak Watt
rating of the module. The wattage rating of the shunt resistor should be
equal to the peak watt rating of the module.
· Procedures to test all of the loads for proper operation.
· How to make system-wide voltage drop measurements in the sub-circuits to
verify that connections meet the required maximum allowable voltage drop.
· How to measure voltage drop across switches to ensure their continued
quality
· Require that technicians note all measurements in the system log.
· Explanation to the technician the system operating principles, load
management requirements, impact of shading of the array and how to check
and avoid it, as well as technician maintenance checks and how to conduct
them.
g)
A recommended annual maintenance schedule, with complete maintenance
instructions for each level of maintenance. This must include battery-watering
requirements.
h)
A detailed troubleshooting guide referencing all the system components. This
shall include repairs and diagnostic procedures that can be done by the
technician in the field. Repairs and procedures not to be attempted by field
technicians shall be identified.
Appendix 6 - 6
4.
4.1.
i)
A functional block diagram, electrical single-line drawing showing the
placement of all hardware and ratings of all component will be prepared along
with a physical layout diagram.
j)
Emergency shut down procedures.
k)
Procedures to follow when a system will be left unused for more than a one
month period.
REQUIREMENTS FOR INSTALLATION
General
4.1.1.
The SHS components must be packaged to provide convenient installation at a
remote customer home site by a qualified technician
4.1.2.
All the necessary installation materials (screws, connectors, fittings, etc.) must be
included into the SHS supply.
4.1.3.
The battery and associated containers should be packaged to handle transport
down rough dirt roads
4.1.4.
All installations details should respect professional mounting techniques
4.2.
PV Array
4.2.1.
The PV modules must face the geographic North (not magnetic North), with a
tolerance of ± 10°.
4.2.2.
The PV modules shall be tilted to an angle from the horizontal that is between 10°
and 20°
4.2.3.
On each location, the site of the PV array shall be chosen so that minimal shade
occurs on the array between 9 AM and 3 PM at any time of the year.
4.2.4.
The modules must be at least 2.5 meters off the ground. The pole must be anchored
in concrete or tightly packed soil at least 1meter deep in the ground.
4.3.
Batteries
4.3.1.
For dry-charged batteries, the electrolyte must be transferred to the battery at the
time of battery installation on the site.
4.3.2.
A complete equalization charge of the battery is mandatory before first use for
supplying a load and that must occur just after it has been filled with electrolyte.
Each of these operations must be recorded into a logbook.
4.3.3.
The battery enclosure must be located in a well ventilated space.
4.3.4.
Provisions must be taken to avoid an accidental short circuit of the battery terminals.
4.3.5.
Failed batteries must be properly recycled and procedures for recycling must comply
with Fijian environmental regulation.
Appendix 6 - 7
4.4.
4.4.1.
4.5.
Lamps
Lamps will be installed strictly according to the manufacturer’s requirements at a
height no greater than 3 meters from floor level.
Wiring
4.5.1.
All wiring, independent switches, sockets and junction boxes should be surface
mounted. When buried, cables should be protected by an appropriate cable conduct
4.5.2.
Wiring must be secured to support structures or walls to fully avoid mechanical
forces on other elements (connection boxes, ballasts, switches, etc)
4.5.3.
Cables must be fixed on walls and other supports at appropriate and constant
intervals (minimum 0.30 m) .
4.5.4.
In general, all cable lays must be horizontal or vertical, never oblique.
4.5.5.
The use of 2 or more cables laid in parallel for a single connection is allowed if
needed to meet voltage drops requirements.
4.5.6.
In the connection boxes, there should be one single cable per cable gland
4.5.7.
Outdoor connection box and switches, if any, should use a bottom cable entry
(water drop mounting)
4.5.8.
Switches will be wall mounted at a level of 120 cm from ground level
4.5.9.
The control switch of lamp installed outside the house should preferably be placed
inside the house.
4.5.10.
The cable between array pole and building and between two different buildings must
be buried using the proper type of direct burial cable or in conduit at a depth of not
less than 30cm
5.
5.1.
5.1.1.
5.2.
5.2.1.
REQUIREMENTS FOR MAINTENANCE
Services
The contractor will carry out :
a)
Periodical routine maintenance visit to each SHS
b)
Repair visits upon warning of the customers
Periodical routine visit
The tasks to be carried out during the periodical routine visit are:
a)
Inspect the system battery and record the battery voltage
b)
Record any changes to the installation since the previous routine visit
c)
Inspect system controls
d)
Check solar panels
e)
Replace and repair any faulty equipment
Appendix 6 - 8
f)
5.2.2.
5.2.3.
5.2.4.
5.2.5.
5.2.6.
5.2.7.
Inform customers on the proper procedures of operating the system
A general inspection will be first carried out to review the system condition and
operation, including:
a)
Mounting Bracket: no visual damage, properly fixed,
b)
PV panel wiring: no visual damage, properly fixed
c)
Battery: no visual damage, electrolyte level, charge level, battery terminals
d)
Wiring : no visual damage, properly fixed
e)
Appliances : no visual damage, operational
f)
Enclosures: no visual damage, properly installed/ fixed, operational, seals
Intact
The solar panel has to be checked on following points:
a)
Check the solar panel for damage (front and back side)
b)
Check the junction box for sealed lids and glands (do not open the junction
box).
c)
Check the solar panel operation, only upon indication of malfunction: open
circuit voltage and short-circuit voltage
The metal support structure has to be checked on the following points:
a)
Check that all nuts and bolts are sufficiently tightened
b)
Check the metal structure for damage or excessive corrosion (if necessary
replace or paint parts)
The battery has to be checked on the following points:
a)
Check the seal or lock of the battery enclosure. If removed by the customer,
record it on the logbook
b)
Remove the seal and check that no water or insects are present inside
c)
Check the level of electrolyte and if necessary, add distilled water to the cell(s)
until they are filled up to the correct maximum level
d)
Measure the specific gravity of the electrolyte and record it on the logbook, in
order for the RESCO supervisor to decide whether or not the battery needs to
be replaced.
e)
After checking, relock or put a new seal on the enclosure
The battery charge regulator has to be checked on the following points:
a)
Replace any controller clearly showing a fault, do not attempt a field
adjustment or repair
b)
If the controller includes operational indicators ensure that their indication is
consistent with the level of charge in the battery.
The appliances and switches have to be checked on the following points:
c)
Check for proper operation
d)
Ensure wires are properly fixed and connections are tight
Appendix 6 - 9
5.3.
Repair visits
5.3.1.
Repair visits are made on request of the customer, following an agreed procedure
that is to be described in the service contract between the customer and the
operating and maintenance contractor.
5.3.2.
In case of a system failure preventing the customer from using the SHS, the repair
visit has to be made within a maximum delay of three (3) days following the day
when notification of the problem was received at the operating and maintenance
contractor’s office.
6.
MAINTENANCE REPORTING
6.1.
Maintenance monthly report
6.1.1.
6.2.
6.2.1.
The operating and maintenance contractor must provide a monthly report including :
a)
The list and location of the routine maintenance visits made during the month
b)
The list and location of the repair visits made during the month
c)
The number of components replaced during the month, for each component
category
d)
The work program for the next month
e)
Any other useful data and information
Maintenance annual report
The operating and maintenance contractor must provide an annual report including :
a)
A consolidation of the monthly reports
b)
A statistical analysis of the component behaviour and of the mean availability
of the SHS
c)
Any other useful data and information
Appendix 7 - 1
APPENDIX 7
PROPOSED STANDARD SPECIFICATIONS FOR RESCO MANAGED SOLAR
HOME SYSTEMS (SHS)
Appendix 7 - 2
TABLE OF CONTENTS
1. BACKGROUND
4
2. GENERAL CONDITIONS FOR THE SHS
4
2.1.
Service delivery indicators............................................................................................................4
2.2.
System typology .............................................................................................................................4
2.3.
Components of the SHS ................................................................................................................5
3. WARRANTIES
5
3.1.
PV modules ......................................................................................................................................5
3.2.
Other components ..........................................................................................................................5
3.3.
Certification requirements ............................................................................................................6
COMPONENT SPECIFICATIONS
7
1. REFERENCE CLIMATIC CONDITIONS
7
1.1.
Global solar radiation.....................................................................................................................7
1.2.
Ambient temperature......................................................................................................................7
1.3.
Relative humidity ............................................................................................................................7
1.4.
Wind speed ......................................................................................................................................7
1.5.
Other conditions .............................................................................................................................7
2. PHOTOVOLTAIC MODULES
7
2.1.
Eligible technology .........................................................................................................................7
2.2.
Certification......................................................................................................................................7
2.3.
Mechanical specifications .............................................................................................................8
2.4.
Electrical specifications ................................................................................................................8
2.5.
Labelling ...........................................................................................................................................8
3. PV ARRAY MOUNTING STRUCTURE
8
3.1.
Design ...............................................................................................................................................8
3.2.
Fasteners..........................................................................................................................................9
4. STORAGE BATTERIES
9
4.1.
Type of batteries .............................................................................................................................9
4.2.
Design ............................................................................................................................................ 10
4.3.
Electrolyte ..................................................................................................................................... 10
4.4.
Enclosure ...................................................................................................................................... 10
4.5.
Labelling ........................................................................................................................................ 10
5. BATTERY CHARGE REGULATOR
11
Appendix 7 - 3
5.1.
Type of charge regulators .......................................................................................................... 11
5.2.
Functions....................................................................................................................................... 11
5.3.
Protections .................................................................................................................................... 11
5.4.
Set points ...................................................................................................................................... 12
5.5.
Internal losses .............................................................................................................................. 12
5.6.
User interface ............................................................................................................................... 12
5.7.
Labelling ........................................................................................................................................ 13
6. LAMPS
13
6.1.
Types of lamps and design ........................................................................................................ 13
6.2.
Mechanical specifications .......................................................................................................... 13
6.3.
Electrical specifications ............................................................................................................. 13
6.4.
Protections .................................................................................................................................... 14
6.5.
Labelling ........................................................................................................................................ 14
7. NIGHT LIGHTS
14
7.1.
Types of night lights and design............................................................................................... 14
7.2.
Mechanical specifications .......................................................................................................... 15
7.3.
Electrical specifications ............................................................................................................. 15
7.4.
Protections .................................................................................................................................... 15
7.5.
Labelling ........................................................................................................................................ 15
8. CONDUCTORS AND OTHER EQUIPMENT
15
8.1.
Types of conductors ................................................................................................................... 15
8.2.
Technical characteristics ........................................................................................................... 16
8.3.
Other equipment .......................................................................................................................... 16
9. OPTIONAL EQUIPMENT
16
9.1.
Description.................................................................................................................................... 16
9.2.
DC power point socket................................................................................................................ 17
9.3.
DC/DC converter .......................................................................................................................... 17
9.4.
DC/AC inverter.............................................................................................................................. 17
9.5.
Prepayment system..................................................................................................................... 18
10. DOCUMENTATION
10.1.
19
Technician manual .................................................................................................................... 19
Appendix 7 - 4
SYSTEM SPECIFICATIONS
1.
BACKGROUND
Although these specifications should be useful for any solar home system (SHS)
application, they are written specifically for the Renewable Energy Service Company
(RESCO) model implemented by the Fiji Department of Energy (DOE). This RESCO
model can be summarized as:
• Technical design, purchasing, and system ownership by DOE;
• Users are self-selected and clustered in groups of a size that is appropriate for
economically reasonable periodic maintenance by the RESCO;
• Users are required to pre-pay a monthly fee that covers a DOE designated
portion of the capital cost of the installed system and the full cost of operation,
maintenance and repair of the systems;
• Maintenance and repair services are to be provided by private contractor RESCO
operators with technical support, evaluation, certification and regulation by the
DOE;
• Financial controls and technical controls will be put into place and administered
by the DOE to ensure continuing proper financial and technical responsibility by
the RESCO contractors;
• DOE will establish a continuing technical and business training process for
personnel of the RESCOs
2.
2.1.
2.1.1.
2.2.
2.2.1.
2.2.2.
GENERAL CONDITIONS FOR THE SHS
Service delivery indicators
The following service delivery indicators are to be provided for any proposed SHS :
a)
The daily energy service is the minimum energy daily available at the output
of the battery charge regulator under a global daily irradiation and a mean
ambient temperature as defined at 1.1.1 and 1.2.3. of the Reference Climatic
Conditions. The daily energy service is expressed in Watt-hour per day
(Wh/day)
b)
The SHS operating autonomy is the minimum number of days during which
the system can provide the daily energy service starting from a 100% charged
battery, the PV array being disconnected from the battery charge regulator.
System typology
The categories of SHS to be provided within the RESCO program are:
a)
Category A - « standard » : minimum daily energy service of 225 Wh/day
b)
Category B - « shigh capacity » : minimum daily energy service of 450 Wh/day
The SHS operating autonomy must be at the minimum 5 days for any SHS category
Appendix 7 - 5
2.3.
2.3.1.
2.3.2.
2.3.3.
3.
3.1.
3.1.1.
3.2.
3.2.1.
Components of the SHS
The mandatory components of the SHS are :
a)
PV module(s)
b)
PV array mounting structure
c)
Battery(ies)
d)
Battery charge/discharge regulator
e)
High luminous efficiency lamps in quantities defined in 2.3.3 below
f)
All wiring accessories: switches, cables, fasteners, junction boxes, etc.
g)
Enclosures
The optional components of the SHS are :
h)
DC outlet
i)
Prepayment system
j)
DC/DC converter intended for radio operation
k)
DC-AC inverter intended for video systgem or TV operation
Unless specified differently in the tender documents, the maximum number of lamps
to be provided in each SHS category are:
l)
SHS Category A: four (4) lamps including one (1) outdoor
m)
SHS Category B: seven (7) lamps including one (1) outdoor
WARRANTIES
PV modules
The minimum warranty period applicable to solar modules should be 20 years.
Warranties will provide for compensation should module output fail more than 15%
below stated manufacturer specifications or should a defect in manufacture result in
corrosion or degradation of the structure of the module. Module defects are defined
as those which are recognized as the failures listed in the CEC specifications N°
501/502, and include frame separation, broken glass, electric connections broken or
unmade, cell in contact with the metallic frame, presence of bubbles between cell
and the edge forming a continuous linkage, broken cell or any other defect that may
interfere with the correct operation of the module and cannot be repaired in the field.
Other components
The minimum warranty period of components from the date of installation will be:
• PV array mounting structures
• Batteries
10 years
2 years
• Charge/discharge controllers 5 years
• Prepayment meters
5 years
• Inverters
2 years
Appendix 7 - 6
3.3.
3.3.1.
3.3.2.
• Battery enclosures
10 years
• Others (excluding bulbs)
2 years
• Lamp Bulbs
1 year
Certification requirements
PV GAP Quality Mark
a)
All components bearing the PV GAP Mark will be acceptable
b)
PV GAP (www.pvgap.org) is a worldwide organization created on initiative of
the PV industry associations, research and development bodies, the World
Bank and the United Nations Development Program to promote quality for the
assurance of performance of PV products (components and systems). PV
GAP established the PV Quality Mark for PV components and the PV Quality
Seal for PV systems. Requirements to obtain the license to display the PV
Quality Mark on products requires an IECQ (IEC Quality Assurance System
for Electronic Components) (www.iecq.org) certification that the manufacturer
has a valid ISO 9001:2000 or similar Quality Management System (QMS)
certification, and that the product(s) have a certificate that it was successfully
tested according to an applicable International Standard or Specification by an
accredited PV testing laboratory or in the manufacturer's in-house testing
laboratory under the surveillance of IECQ. An important additional
requirement is that the manufacturer completes PV GAP's Product Quality
Assurance Specification (PQAS), which prescribes when the modules have to
be re-tested.
When equipment does not bear the PV GAP quality mark, they should have a
certificate from an accredited testing and certification organization acceptable to the
DOE or have a proven record of at least five years of reliable service in a similar
type of installation in the Pacific Islands.
Appendix 7 - 7
COMPONENT SPECIFICATIONS
1.
1.1.
REFERENCE CLIMATIC CONDITIONS
Global solar radiation
1.1.1.
The reference value of global solar radiation to be used for the expression of
performances and services delivered by a SHS is 4500 Wh/m² per day. If solar
radiation measurements are made in the installation area for one year or more,
those values may be used for the sizing of SHS for that installation area.
1.1.2.
The above reference value is that on a surface with a tilt angle of 15 degrees
oriented toward geographic North.
1.2.
Ambient temperature
1.2.1.
The maximum operating ambient temperature of the SHS is 40°C.
1.2.2.
The minimum operating ambient temperature of the SHS is 10°C.
1.2.3.
The reference temperature to be used for the expression of performance and
services delivered by a SHS is 25°C.
1.3.
1.3.1.
1.4.
1.4.1.
1.5.
1.5.1.
2.
2.1.
2.1.1.
2.2.
2.2.1.
Relative humidity
The maximum operating relative humidity of the SHS is 100% but without
condensation
Wind speed
Where there are cyclone risks, the reference wind speed to be considered for the
design of the support structures and their anchoring is 180 km/h.
Other conditions
The entire system shall be designed and built to withstand the environmental
conditions found in tropical, coastal countries. Aggressive marine conditions (e.g.,
salt laden air) are frequently encountered.
PHOTOVOLTAIC MODULES
Eligible technology
The PV modules shall be either of mono-crystalline or poly-crystalline technology
unsing at least 36 series connected cells for 12V battery charging. Other solar
photovoltaic technologies shall not be accepted.
Certification
The mono-crystalline or poly-crystalline PV modules PV shall be tested and certified
according to IEC-61215 standard.
Appendix 7 - 8
2.2.2.
The homologation of type shall be certified by a testing report issued by an
accredited testing laboratory. The homologation shall be made according to the IEC
QC 001002 standard.
2.2.3.
The certification documents shall be made available on simple request of the
contracting authority.
2.3.
Mechanical specifications
2.3.1.
The modules must be framed in such a way as to ensure their rigidity and allow
secure attachment to the module mounting structure. The material of the mounting
frame must be fully protected against corrosion.
2.3.2.
The PV modules must be factory equipped with a weather-proof junction box with
screw type terminals that allow safe and long lasting wiring connection to the
module using 4mm2 wire. The junction box shall be compliant with IP54 standard; it
will be equipped with cable glands for all cable passages. The polarity of the
terminal strip will be clearly signalled inside the junction box.
2.4.
Electrical specifications
2.4.1.
The PV modules shall comprise no less than 36 series-connected single or polycrystalline silicon solar cells.
2.4.2.
The actual peak power of any delivered PV module shall not be less than 90% of the
nominal peak power when operated at standard conditions.
2.4.3.
The voltage-current curves shall be provided for of each proposed model of PV
module for the following conditions: radiation of 1000 W/m² and cell temperatures of
25°C, 40°C and 60°C.
2.4.4.
If multiple PV modules are used in one SHS, all shall be of the same model. It is
forbidden to associate PV modules of different models or peak rating powers within
one SHS.
2.4.5.
Each PV module shall be equipped with by-pass diodes to protect against "hotspots".
2.5.
2.5.1.
3.
3.1.
Labelling
Each module must be labelled indicating at a minimum: Manufacturer, Model
Number, Serial Number, Peak Watt Rating, Peak Current, Peak Voltage, rated
voltage or amperes at the maximum power point, Open Circuit Voltage and Short
Circuit Current, country of manufacture.
PV ARRAY MOUNTING STRUCTURE
Design
3.1.1.
The PV array mounting structure must be of the "pole mounting" type.
3.1.2.
No manual tracking or seasonal adjustment device is to be installed.
3.1.3.
The tilt angle of PV modules must be 15°, with a tolerance of ± 5°
Appendix 7 - 9
3.1.4.
Array orientation must be adjustable in the field for both tilt and direction within the
allowable raqnge of ± 5° in tilt and ± 360° in direction
3.1.5.
The design of the mounting pole structure must assure stable and secure
attachment of the PV array while withstanding the reference maximum wind speed
in § 1.4.1
3.1.6.
The length and type of the pole must ensure stability on any kind of soil and provide
a minimum of 2.50 meters between ground level and the lower extremity of the PV
array.
3.1.7.
The array mounting structure must be made of materials that must resist at least 20
years of outdoor exposure without corrosion or damage due to the environment. Any
treatment against corrosion employed must be clearly described. The following are
acceptable :
a)
Marine grade stainless steel
b)
Double hot dipped galvanised iron with a minimum layer of 30 µm of
galvanization. All holes and cuts must have been made before galvanisation.
c)
Anodised aluminium
d)
Anti-rot treated wood for the pole
3.1.8.
In case of different metals being used in the mounting system, proper electrical
isolation has to be ensured between those different metals to avoid corrosion.
3.1.9.
Full technical specifications of the PV array mounting structure shall be provided by
the supplier. These must specifically include physical size, and details of materials
used in construction, complete drawings showing the construction and assembly of
the mounting structures and the mounting of the modules thereon. This should
include, if relevant, wood species and chemical treatment characteristics.
3.2.
3.2.1.
4.
4.1.
Fasteners
Only marine grade stainless steel fasteners (screws, nuts, locking rings, etc.) should
be used .
STORAGE BATTERIES
Type of batteries
4.1.1.
The type of battery to supply with the SHS is at the minimum to be deep-cycle rated,
flat plate type lead-acid flooded battery that is specifically designed for SHS
applications.
4.1.2.
The SHS may alternatively be equipped with deep cycle, tubular plate lead-acid
flooded batteries.
4.1.3.
Sealed batteries, “maintenance free” batteries, automotive batteries and engine
starting batteries are not acceptable.
Appendix 7 - 10
4.1.4.
Batteries should be supplied dry charged with sufficient acid supplied separately for
filling at the time of installation.
4.1.5.
The rated capacity of the battery is the 20-hour nominal battery capacity in amphours, measured at 20°C and discharged to a voltage of 1.8 V/cell
4.2.
4.2.1.
Design
The battery as described in 4.1.1 must meet the following requirements:
a)
The thickness of each plate must exceed 2 mm
b)
Electrolyte volume must be equal or higher than 1.15 litres/cell per 100 Ah of
C20 rated capacity.
c)
The maximum permissible self-discharge rate is 6% of rated capacity per
month at 25 ºC.
4.2.2.
The cycle life of the battery (i.e., discharge cycles possible before its residual
capacity drops below 80% of its nominal capacity) at 25°C must exceed 300 cycles
when discharged down to a depth of discharge of 50%.
4.2.3.
The 20-hour nominal battery capacity in amp-hours should not exceed 30 times the
PV generator short-circuit current in amps (measured at Standard Test Conditions)
4.2.4.
The maximum depth of discharge should not exceed 50% of the rated capacity of
the battery supplied.
4.3.
Electrolyte
4.3.1.
The density of the electrolyte should be intended for tropical use and must not
exceed 1.25 kg/l
4.3.2.
The electrolyte must be prepared from concentrated sulphuric acid and distilled
water, according to DIN 43350 or equivalent
4.4.
Enclosure
4.4.1.
Each battery bank must be supplied with a battery box constructed of impact and
acid resistant material and designed for outdoor exposure. The material and design
should be resistant to water, UV and shocks. Wooden boxes are not acceptable.
4.4.2.
The battery box should prevent insect penetration.
4.4.3.
The battery box should be designed to lock or to allow use of lead or other type of
seals to restrict the access to the batteries to approved staff.
4.4.4.
All passages of cable into the box should be through appropriate cable glands to
avoid any insect and water penetration and mechanical stress on the cable
terminals
4.4.5.
The battery box should be equipped with venting holes near the top of the
enclosure.
4.5.
4.5.1.
Labelling
Each battery terminal must be labelled indicating its polarity + or - The label must
be undeletable.
Appendix 7 - 11
4.5.2.
5.
5.1.
5.1.1.
5.1.2.
5.1.3.
5.2.
5.2.1.
5.3.
5.3.1.
5.3.2.
Each battery must be labelled indicating at a minimum: Manufacturer, Model
number, and capacity.
BATTERY CHARGE REGULATOR
Type of charge regulators
The mode of generator regulation implemented in the regulator may be one of the
following :
a)
Series regulator
b)
Shunt regulator
The mode of battery charge regulation implemented in the regulator may be one of
the following :
a)
Two-step(on-off) regulation
b)
Pulse Wave Modulated (PWM) regulation
c)
Regulation based on a algorithm that is based of the type and state of charge
of the battery
All the charge regulator terminals should easily accommodate 4 mm² section wire.
Functions
The functions of the battery charge regulator is to provide protection against:
a)
Battery overcharge and excessive water consumption
b)
Battery undercharge and excessive deep discharge
Protections
The enclosure of the regulator must comply to the following requirements :
a)
its protection degree is at least IP32 according to IEC 529
b)
its design must prevent inside condensation
c)
its design should protect against insect penetration
d)
it should be provided with integrated mounting brackets or fixtures
The battery charge regulator must include the following protections:
a)
Circuit protection against reverse polarity of any load
b)
Circuit protection against reverse polarity of panels or battery
c)
Circuit protection against short circuit of any load: this protection must be
ensured by a fuse or equivalent device that may be replaced/reset by the
user,
d)
Protection of controls against lightning induced transients
e)
Circuit protection against damage by the high PV panel open circuit voltage
when it is connected to the controller without a battery.
Appendix 7 - 12
5.3.3.
5.3.4.
5.4.
5.4.1.
5.4.2.
5.5.
The charge regulator must handle without any damage for a minimum one-hour
duration:
a)
A charging current equal to 125% of the array's rated short circuit current
b)
A discharging current equal to 150% of the maximum expected continuous
load (e.g., assuming all end use devices are simultaneously on)
The charge regulator must not produce radio frequency emission in any operational
condition that causes AM, FM, TV or communications radio interference beyond a
distance of 1 meter from the regulator.
Set points
The charge controller set points must be factory preset with the set points applicable
to the specified battery characteristics, according to the following requirements:
a)
The “load-disconnection” voltage should correspond to a maximum depth of
discharge of the value equal to values defined in § Error! Reference source not
found. when the discharge current, in amps, is equal to the daily load
consumption, in amp-hours, divided by 5.
b)
“Load-disconnection” and “load-reconnection” should be accurate to within
±1% (±20 mV/cell, or ±120 mV/battery of 12 V) and remain constant over the
full range of possible ambient temperatures
If electro-mechanical relays are used, the resetting of the control conditions should
be delayed for between 10 seconds and 5 minutes
Internal losses
5.5.1.
Internal voltage drops between the battery and generator terminals of the charge
regulator must be less than 4% of the nominal voltage (≈ 0.5 V for 12 V) in the worst
operating conditions, i.e., with all the loads “off” and the maximum current from the
PV array generator.
5.5.2.
Internal voltage drops between the battery and load terminals of the charge
regulator must be less than 4% of the nominal voltage (≈ 0.5 V for 12 V) in the worst
operating condition, i.e., with all the loads “on” and no current from the PV array
generator.
5.5.3.
Maximum current drawn by the controller and pre-payment meter in combination
should not exceed 10 mA under normal operating conditions
5.6.
5.6.1.
5.6.2.
User interface
Provided 5.5.3 is met, the charge/discharge controller may include battery level
indicators. If included they shall provide the following minimum user information :
a)
Battery connected, sufficient battery state of charge
b)
Battery disconnected, too low state of charge
Where indicators are present, an intermediate warning indication is recommended
that indicates when there is a near term risk of battery disconnection due to
decreasing battery charge.
Appendix 7 - 13
5.7.
Labelling
5.7.1.
Each terminal of the regulator must be labelled indicating its polarity + or - The label
must be undeletable.
5.7.2.
Each regulator must be labelled indicating at a minimum: Manufacturer, Model
number, rated voltage, input and/or output current in amperes, set points, country of
manufacturing.
6.
6.1.
6.1.1.
LAMPS
Types of lamps and design
The types of lamps to be proposed with SHS are :
a)
Fluorescent lamps with straight or circular tubes
b)
Compact fluorescent lamps (CFL type including PL lamps)
6.1.2.
Lamps wattage should be in the range 6 – 15 watts
6.1.3.
Unless specified in the tender document, the reference norms for the characteristics
of electronic ballasts are IEC 458, IEC 921, IEC 924 and IEC 925.
6.1.4.
The lights must meet at a minimum, the following requirements:
6.2.
c)
Each fluorescent lamp should have its own ballast
d)
The rated life of the ballast must equal or exceed 10000 hours when operating
at rated voltage.
e)
Rated bulb lifetime must equal or exceed 5000 hours
6.2.1.
The lamp must be provided with suitable mounting bracket to be either wall or
overhead mounted.
6.2.2.
The terminals of the ballast :
6.2.3.
a)
Should allow a screw type connection of the power wires,
b)
Should easily accommodate at least 2,5 mm2 wires
c)
Should be clearly marked with polarity indicators
If the lamp includes a cover, its fixing should provide:
a)
Protection against insect penetration
b)
Easy dismantling for bulb replacement
6.2.4.
The electronic ballast/lamp combination should withstand at least 5000 switching
cycles with each cycle consisting of 60 seconds on and 150 seconds off
6.2.5.
Outdoor lamps should have a IP 54 protection or be mounted in an IP 54 enclosure.
6.3.
6.3.1.
The minimum operating frequency of the ballast is 20 kHz
Appendix 7 - 14
6.3.2.
The luminous yield for the total ballast and fluorescent lamp system must be at least
35 lumens per rated watt (= rated voltage times rated current of the lamp) at nominal
voltage
6.3.3.
Ballasts must ensure safe and regulated ignition in the voltage range from –15% to
+25% of the nominal voltage (10.3 V to 15 V for 12 V battery)
6.3.4.
The minimum operating voltage when the tube will strike (start) should be at least
85% of the rated input voltage when using the fluorescent lamp specified by the
supplier
6.3.5.
The maximum continuous operating voltage without damage to the inverter circuit
must be at least 125% of the rated voltage
6.3.6.
The minimum electrical efficiency of the ballasts must be 70% in all the range of the
operating voltage (–15% to +25% of the nominal voltage)
6.3.7.
The electrical waveform at the fluorescent lamp terminals must be symmetrical in
time to within 10 percent (i.e., 60%/40% waveform maximum difference in
symmetry) over the voltage range of 11.0 to 12.5 VDC at an ambient temperature of
25°C
6.3.8.
The maximum crest factor (ratio of maximum peak to RMS voltage of the waveform
applied to the fluorescent tube) should be less than 2 over the voltage range from 11
to 12.5 V at an ambient temperature of 25°C
6.3.9.
The direct current components of the lamp operating current may not exceed 2 % of
the RMS
6.4.
6.4.1.
6.4.2.
6.5.
6.5.1.
7.
7.1.
7.1.1.
Protections
Ballasts must be protected against destruction when:
a)
the lamp is removed during operation or the ballasts are operated without the
lamp.
b)
the lamp does not ignite.
c)
the supply voltage polarity is reversed.
d)
the outputs of the electronic ballast are short circuited.
Ballast must not produce radio frequency interference that causes AM, FM, TV or
communications radio interference beyond a distance of 1 meter from the ballast..
Labelling
Lights must be marked with the manufacturer, model number, rated voltage, wattage
and date of manufacture or batch number.
NIGHT LIGHTS
Types of night lights and design
Night lights to be
illumination
provided with SHS are to use one or more white LEDs for
Appendix 7 - 15
7.1.2.
Night light wattage should be in the range 0.5 to 1 Watt
7.1.3.
A manual on/off switch is acceptable but an ambient light sensor to automatically
turn off the night light during the daytime is preferred.
7.1.4.
The lights must meet at a minimum, the following requirements:
7.2.
e)
The rated life of the night light must equal or exceed 50000 hours when
operating at rated voltage and temperature.
f)
Be constructed of maerials and in a manner that does not degrade under
marine, tropical conditions
7.2.1.
The lamp must be provided with a suitable mounting bracket to be either wall or
overhead mounted.
7.2.2.
The terminals of the lamp:
7.2.3.
7.3.
7.3.1.
7.4.
7.4.1.
7.5.
7.5.1.
8.
8.1.
g)
Should include screw type connection for the power connections,
h)
Should easily accommodate at least 2.5 mm2 section wires
i)
Should be clearly marked with polarity indicators
If the light includes a cover, its fixing should provide protection against insect
penetration
Lamps must function normally and without damage between 10.2VDC and 16VDC
Protections
Lamps must be protected against destruction when the input polarity is reversed
Labelling
Lights must be marked with the manufacturer, model number, rated voltage,
wattage, country of origin and date of manufacture or batch number.
CONDUCTORS AND OTHER EQUIPMENT
Types of conductors
8.1.1.
Only stranded and flexible insulated copper wiring must be used.
8.1.2.
External cables must be specifically adapted to outdoor exposure according to the
international standard IEC 60811 or to the national standard in Fiji.
8.1.3.
All cable terminals must allow for a secure and mechanically strong screw type
electrical connection. They must have low electrical resistance; leading to voltage
losses less than 0,5% of the nominal voltage. This applies for each individual
terminal at the maximum current condition
Appendix 7 - 16
8.1.4.
Cable terminals should not be prone to corrosion arising from junctions or dissimilar
metals
8.1.5.
Crimp type terminal lugs shall not be used
8.1.6.
All wiring shall be colour coded and/or labelled as to polarity.
8.2.
8.2.1.
8.2.2.
Technical characteristics
Minimum acceptable cross-section of the wire in each of the following sub-circuits is
as follows:
a)
From PV module to battery charge regulator: 2-conductor, no earth, 4 mm²
cross-section
b)
From to battery charge regulator to battery: 2-conductor, no earth, 4 mm²
c)
From to battery charge regulator to loads: : 2-conductor, no earth 2.5 mm²
Notwithstanding the above minimum wire size requirements, all wiring must be sized
to keep line voltage losses to, at the maximum current conditions (i..e. with all loads
switched on):
a)
less than 3% of voltage losses between PV modules and charge regulator,
b)
less than 1% between battery and charge regulator,
c)
less than 5% between charge regulator and any load in the worst conditions,
ie all appliances on and a 5 ampere load drawn on the DC outlet if such outlet
is installed.
8.2.3.
All indoor and outdoor cable connections should use screw type terminals and be
housed in connection boxes.
8.2.4.
Colson rings and appropriate concrete and wooden walls fixation devices are
recommended for all cable attachments
8.3.
Other equipment
8.3.1.
Connections boxes must cornform to IP 54
8.3.2.
Switches must conform to IP 54, and be appropriately sized for use with the DC
current consistent with the loads to be applied.
9.
9.1.
9.1.1.
OPTIONAL EQUIPMENT
Description
Following devices are not part of standard supplies but may be proposed as options
in the tenders.:
a)
DC power point socket
b)
DC/DC converter with 3V, 4.5V and 6V and 9V adjustable output
c)
12V DC / 230 V 50Hz AC inverter
Appendix 7 - 17
9.1.2.
9.2.
Audio and Video equipment are not part of the standard tender supply but a list of
recommended type of products available on local market should be provided to the
SHS users.
DC power point socket
9.2.1.
The DC power point socket should be of a different design than that normally used
for AC wiring and prevents insertion in any but the correct polarity of connection
9.2.2.
The DC power point should be IP 54.
9.2.3.
The power point must accommodate 2x2.5 mm² cable.
9.3.
DC/DC converter
9.3.1.
The DC/DC converter will include the appropriate connector so it can be plugged
into the system DC power point socket
9.3.2.
The minimum input voltage range should be 11V – 15 V.
9.3.3.
The minimum protection should be IP 32
9.3.4.
The nominal input current should be in the range 0.7 A – 1.2 A.
9.3.5.
The DC/DC converter should require less than 30 mA of operating current when no
output load is connected.
9.3.6.
The operating efficiency of the converter should exceed 85%
9.3.7.
The DC socket on the converter should be protected against reverse polarity.
9.4.
DC/AC inverter
9.4.1.
The DC/AC inverter must not be used as the installation central power supply but
only to power specific devices for which no DC alternatives are presently available
on local market.
9.4.2.
The DC/AC inverter will be hard wired to the device to be powered at the time of
installation to prevent general use of the inverter as an AC supply for other
appliances
9.4.3.
The DC/AC inverter will be used only with the larger category B SHS
9.4.4.
The DC/AC inverter should meet following criteria
a)
Matched to the load requirements but with a maximum rated power 150 VA
b)
Minimum Input Voltage range between 10.5V – 16 V
c)
True or pseudo sine wave output
d)
AC output frequency range : ± 2%
e)
AC output voltage range: ± 8%
f)
Minimum Efficiency should be 80% at 50% of nominal load power
g)
A 200% overload current for 5 seconds should be tolerated without
diceonnection or damage
Appendix 7 - 18
9.5.
h)
protection against output short circuit
i)
protection against overtemperature during operation
j)
protection against reversed polarity of input connection
k)
standby power consumption should be less than 2% of nominal power
l)
ability to start operation under full load of the connected appliance
m)
On/Off switch
Prepayment system
9.5.1.
A prepayment system may be installed to help ensure timely payment of fees
9.5.2.
The prepayment system is intended to require the customer to pay in advance for a
period of utilisation of the solar system (typically one month) which may vary
according to the amount paid. As soon as there is no more time credit available, the
prepayment unit disconnects the load.
9.5.3.
The prepayment system includes the following items
9.5.4.
9.5.5.
a)
The prepayment units, each SHS being equipped with such a prepayment
unit
b)
The prepayment vending terminals, managed to sell the services to the
customers
The prepayment units must meet the following specifications:
a)
It can be combined with the battery charge controller or be an independent
unit. If combined with the charge/discharge controller, the unit must meet all
specifications for both the charge/discharge controller and the prepayment
meter.
b)
It should provide a proven and high level of protection against user attempt of
any form of tampering.
c)
The system used should be highly user-friendly for the customers and the
suppllier of the services.
The prepayment vending terminals must meet the following specifications:
a)
As many vending terminals as necessary should be disseminated in the
operating zone of the RESCO contractor, as to be available at a reasonable
distance from the customers.
b)
It should allow to sell at least a one month period credit to the customer.
c)
It should include all the required software and side equipment, namely power
supply source if required.
9.5.6.
Credit card type, code type, data token type or any other prepayment technology
can be acceptable if a proven reliability in large scale SHS projects in similar tropical
coastal context is demonstrated.
9.5.7.
Any component of the prepayment system must be able to permanently operate
reliably under the climatic conditions mentioned in 1.2 and § 1.3
9.5.8.
The supplier must provide, with the prepayment system:
Appendix 7 - 19
a)
All the technical documentation required to operate and maintain the system,
both in paper and electronic form.
b)
All the required training to the RESCO contractor's staff. The training must be
done in Fiji, with a minimum of one month duration of on site training,
monitoring and demos. The training program has to be fully described in the
supplier's proposal.
c)
A one year full technical support to the RESCO contractor, with a permanent
phone hotline and a program of control visits to Fiji, that has to be described in
the supplier's proposal.
d)
A full replacement warranty of 2 years or more must be provided
10.
DOCUMENTATION
10.1.
Technician manual
10.1.1.
The supplier must provide a Technician’s Installation, Operations and Maintenance
Manual to be used by the service technicians for all components supplied. The
manual must be in English. The manual will include the specific details on
installation, operation and maintenance.
a)
A detailed technical description of the system.
b)
All associated manufacturer’s literature, specifications, and warranties.
c)
Complete installation instructions.
d)
Recommended post-installation acceptance test procedures, including all
appropriate set points and test procedures.
e)
A recommended maintenance programme to cover each component
ssupplied with complete maintenance instructions.
f)
A detailed troubleshooting guide referencing all the components supplied.
This shall include repairs and diagnostic procedures that can be done by a
qualified third party (e.g., RESCO technician).
g)
A clear description of any safety hazards or issues relating to the components
supplied witll be provided and will include a description of procedures
appropriate to minimise those hazards.
h)
Requirements that are to be met for proper storage of components and for the
maintenance of components installed in an SHS that is not to be used for an
extended period.
i)
Emergency shut down procedures for components where appropriate.
Appendix 8 - 1
APPENDIX 8
TRAINING COURSE FOR SOLAR PHOTOVOLTAICS INSTRUCTORS IN FIJI (910 FEBRUARY 2006)
CURRICULUM FOR SOLAR PV AT FIT (2005)
Appendix 8 - 2
Overview
With expectations of rapidly increasing numbers of solar home systems for rural electrification in
Fiji, there isa need for training of technicians to service the installations. The Centre for
Appropriate Technology and Development (CATD) has provided basic technical training in solar
PV for home electrification since 1989 but the course content and facilities have not changed
since 1989 and are in need of modernizing. The Fiji Institute of Technology (FIT) in 2005 began
to initiate curriculum development for solar photovoltaics training with courses to start in midFebruary 2006. The Trade and Productivity Authority of Fiji (TPAF) also has a demonstrated
interest in developing a training capability for solar photovoltaics but has not yet developed
formal training courses.
To support this expansion in PV training, the REEP consultants reviewed PV training course
curricula and delivered a two day course in solar PV technology for rural electrification designed
for instructors at FIT, TPAF and CATD. Additionally, the Fiji DOE, Fiji Telecom and two private
companies with an interest in solar photovoltaics sent participants to the training course.
The two days available for the training were arranged so that the course consisted of about 75%
lectures and 25% practical works and demonstrations. The primary need for support for
instructors was seen to be in the theory and computational aspects of the training rather than
the laboratory work.
Future solar technology training that will be provided by CATD, FIT and TPAF will be integrated
into their regular ongoing training programmes. Also all three institutions will provide intensive
short courses to be delivered on demand when there is a need for technician training.
The curriculum for integrating the solar training as a part of ongoing courses has been
developed and is in place at FIT and CATD with the first courses at FIT underway the first term
of 2006.
Appendix 8 - 3
Solar Photovoltaics Training – FIT 9-10 February, 2006
Course Content
Location: FIT (Ratu Mara Road, Suva) Electrical Trades Section.
Day 1: Solar PV Basics
Theoretical 0830-1030
Background of solar PV development and use
Introduction to solar PV with comparison of solar PV and rainwater collection
systems
Quick review of DC electricity basics
Solar Panel, theory and construction
Panel characteristics, physical and electrical
Panel mounting and maintenance
1015-103- Morning tea and discussions
Batteries for solar use, types and characteristics
Battery safety, installation and maintenance
Controllers for charging and discharging
Lunch Break (1300-1400)
Practical Works 1400-1445
Solar Panel experiments and demonstrations, battery preparation
Appliances and loads for SHS
Installation rules
SHS maintenance
Day 1 comprehension examination
Appendix 8 - 4
Day 2: Advanced
Theoretical (0830-1300)
Wire sizing and connections
Estimating energy requirements for SHS
System sizing for independent power systems (with battery)
Tea break 1045-1100
AC systems using PV – independent power systems (with battery)
Grid connected PV principles
Problems on sizing and wire size calculations
Lunch Break (1300-1400)
Practical Works 1400-1500
Battery capacity test, inverters, voltage drops in wires, CFL tests,
Special problems and discussions
Appendix 8 - 5
Course Participants
Name
Address
email
Akanisi Varani
FIT-Mechanical Engineering
[email protected]
Anish Pratap
Telecom
[email protected]
Ashwin Kumar
FIT-Electrical Engineering
[email protected]
David
Clay Engineering
[email protected]
Elenoa Baleinaniudrau
[email protected]
Eli Fong
[email protected]
Eremasi Tamanisau
[email protected]
Gyanend Singh
[email protected]
Jiten Lal
[email protected]
Jope Rokotuibau
CATD
[email protected]
Lawrence Delanimati
[email protected]
Liang Wai Qiang
[email protected]
Marfaga Solomone
TPAF
[email protected]
Meli Rabaro
[email protected]
Moritekei Ravulala
[email protected]
Patersio Laliqavoka
[email protected]
Paula Katirewa
DOE
pkatirewa#fdoe.gov.fj
Paula Tuivanuyalewa
[email protected]
Paula Vuli
[email protected]
Peni Vinakadina
CATD
[email protected]
Peni Volavola
Telecom
[email protected]
Radesh Lal
USP
[email protected]
Ravindra Singh
[email protected]
Saimoni Matawalu
[email protected]
Sebiuta Rakanace
[email protected]
Semi Kendrawaca
DOE
[email protected]
Sitiveni Daunakamakama
[email protected]
Sovaia Vakasoqo
[email protected]
Susana Pulini
DOE
[email protected]
Tevita Manamana
DOE
[email protected]
Ulaiasi Halofaki
[email protected]
Ulaiasi Gudru
[email protected]
Wilimone Quinawasa
[email protected]
Vinil Sudhir
[email protected]
T. Vonivate
[email protected]
Appendix 8 - 6
Proposed FIT Solar PV Curriculum (2005)
All certificate candidates must have completed Basic Electricity courses E1101 through
E1201 before commencing specialty courses in Solar Technology
1. PROGRAMME:
SOLAR POWER GENERATION SYSTEM DESIGN and
INSTALLATION
2. CODE:
E2115
3. UNIT NAME: SOLAR PHOTOVOLTAIC SYSTEM (Theory)
4. LEVEL: 2
5. CREDITS: 7.5
6. LEARNING HOURS:
7. ISSUED:
Class Contact 60 - 90
Self Directed 90 – 60
JUNE 2005
8. PURPOSE of the UNIT
This unit is to provide students the principles of the solar photovoltaic system, its components,
operation, application, construction and maintenance(TPM).
9. LEARNING OUTCOMES
On the completion of this unit the student should be able to:
9.1 Appreciate and explain the solar photovoltaic system and what is its purpose
9.2 Know the component parts of the system.
9.3 Identify components of the solar power generation system
9.4 Know the types of wire and connections
9.5 Know the purpose of solar panels and name their characteristics
9.6 Determine the method of obtaining optimal voltage or current
9.7 State the purpose of batteries and name the types for solar use
9.8 State the use of controllers and name the types.
9.9 List the electric appliances suitable for solar systems and their features.
9.10 Select the right appliance for the solar power systems
9.11 Explain the types of inverters
9.12 List the characteristics of inverters
10. CONTENTS
TOPIC 1
The Solar Photovoltaic System
1.1 Purpose of solar photovoltaic systems – solar cells (briefly),
1.2 Systems components.
1.3 Principles of operation - storage, controller, wiring.
1.4 Appliances
TOPIC 2
Electricity & Wire Sizing and Selection
Appendix 8 - 7
2.1 Electricity- power, energy, application of Ohms Law, resistance
2.2 Circuits – series, parallel; current generator, voltage generator
2.3 Direct current (dc), RMS, alternating current (ac).
2.4 Conductors (electrical wires) – relation of wire size to power loss, voltage drop across wires
2.5 Determine correct wire size – types of wires
TOPIC 3
Photovoltaic Panels
3.1 Purpose of photovoltaic panels – reliability.
3.2 Physical characteristics, electrical characteristics; current characteristics
3.3 The relation of load, current, voltage
3.4 Panel Connection and power/energy outputs – series, parallel
3.5 Factors affecting panel (maximum) output
TOPIC 4
Battery
4.1 Purpose of battery – types
4.2 How batteries work – for lead-acid type, chemical reaction during charging; discharging.
4.3 Selecting type of battery for Solar System: Electrical capacity, measurement of charge level;
measurement of ampere-hour capacity
4.4 Safety measure for battery and personnels.
4.5 Installation of battery – battery failure modes.
4.4 Maintenance – three steps.
TOPIC 5
Controllers
5.1 Purpose of controllers – regulators, load controllers
5.2 Charge controllers – types: parallel, series. Principles of controller operating cycles
5.3 Discharge controller – principles of operation; reset process.
5.4 Other control features – lights, meters, alarm etc.
5.5 Controller specifications
TOPIC 6
Appliances
6.1 Solar Lights –
6.1.1 Lamp characteristics
6.1.2 Types of lamps and choosing lights for solar systems
6.1.3 Installing and maintenance
6.2 Photovoltaic Refrigerators –
6.2.1 Refrigeration principles – compression refrigeration; evaporator; condenser;
expansion valve; accessories (thermostats etc.).
6.2.2 Photovoltaic Compression Refrigerators – cabinets, compressor unit; duty cycle;
6.2.3 Maintenance
6.3 Pumping Systems
6.3.1 Use of pumping systems – drinking water, irrigation etc.
6.3.2 Basic hydraulics for pumps – Flow and total pump head; friction losses
6.3.3 Pumps – types: positive displacement, centrifugal; (propeller type)
6.3.4 Installation of solar energy type pumps – surface mounted; submersible
6.3.5 Solar powered Pumping systems design: Pump selection.
Appendix 8 - 8
TOPIC 7
Inverters
7.1 Inverters – classes
7.2 Characteristics – input & output voltage, o/p voltage regulations, transient load response,
starting characteristics, ac frequency, frequency stability, Waveform, etc.
7.3 Inverter selection – appliances with most load from motors
- appliances without significant load from motors
7.4 Maintenance
1.
PROGRAMME: CERTIFICATE IN PHOTOVOLTAIC ENERGY
2.
CODE: E2116
3.
UNIT NAME: PROJECT
4.
LEVEL: 2
5.
CREDITS:
6.
LEARNING HOURS:
7.5
Class Contact 20 – 15
Self Directed 40 - 45
7.
ISSUED:
JUNE, 2005
8.
PURPOSE of the UNIT
In this unit students are taught to undertake largely self directed work, which involves the
analysis of data, construction and testing of circuit, system or pieces of equipment.
The unit also enables students to learn specific techniques for designing photovoltaic
systems for a given amount of loads, and also install or construct the appropriate system
according to the design as the solution.
The unit will also teach students about scientific report writing.
9.
LEARNING OUTCOMES
On completion of this unit, the student should be able to:
9.1
Plan and document a logical and sequential process to enable a project to be completed
within a specified time according to specified requirement.
9.2
Specify key performance parameters to be used in assessing electric appliances for the
project specifications
9.3
Analyse circuit/system to determine expected performance parameters, using computer
based tools or test instruments where appropriate
Appendix 8 - 9
9.4
Perform tests to determine key performance parameters and to evaluate compliance with
specified performance criteria.
9.5
Present oral report of analysis, construction and testing, in a seminar environment to FIT
staff and students.
9.6
Produce a final report of the project.
10.
CONTENT
TOPIC 1.
1.1
Loads
Calculate the load (electrical equipment) to be driven.
TOPIC 2.
2.1
Inverter
Determine the inverter capacity and specification
TOPIC 3
3.1
Battery
Determine the battery capacity and specification.
TOPIC 4.
Initial Presentation
4.1
Present an oral report of the stages 1 to 3 in a seminar environment to FIT staff
and the students.
4.2
Use of appropriate visual aids to support explanation of project outcome
4.3
Answering of questions from FIT staff and students
TOPIC 5.
5.1
Determine the photovoltaic array capacity and specifications
TOPIC 6.
6.1
Charge/Dischrage Controller
Determine the charge controller specifications
TOPIC 7.
7.1
Photovoltaic Array
Wiring
Determine the wiring specifications
Appendix 8 - 10
TOPIC 8.
8.1
8.2
8.3
8.4
Complete other installation/construction requirements
Test circuit/system
Document test results
Compare measured performance parameters with those predicated
TOPIC 9.
9.1
9.2
9.3
9.4
FINAL PRESENTATION
Present an oral report in a seminar environment to FIT staff and students
Use of appropriate visual aids to support explanation of project outcomes
Demonstration of circuit/system operation
Answering of questions from FIT staff and students
TOPIC 10.
10.1
10.2
10.3
10.4
10.5
Installation/Construction
FINAL REPORT
A comprehensive and systematic documented account of all stages of project
Progress report detailing outcome from previous stages
Summary of project outcomes
References
Table of contents
Appendix 9 - 1
APPENDIX 9
FACILITY REQUIREMENTS FOR PV TECHNICIAN TRAINING
Appendix 9 - 2
Facility Requirements for PV Technician Training (CATD, FIT, TPAF)
STUDENT LABORATORY KITS
Laboratory exercises are expected to be carried out in two person teams so the facilities listed
represent those needed for each pair of students.
2 - Solar panels 25Wp to 50Wp, polycrystalline or monocrystalline type. The smaller panels are
preferred since they provide the same training experience as the larger ones and take less
storage space
1 - Aluminum rack to support two of the above solar panels with adjustable stand to allow for
positioning at various tilt angles.
1 - 45Ah-65 Ah open cell lead acid battery. An ordinary car battery is satisfactory for the
purpose of laboratory experiments
1 - Basic charge/discharge controller, relay type such as those manufactured in Kiribati by the
Solar Energy Company for use in their rural electrification projects. A relay type controller is
proposed since its operation is easy to monitor with simple equipment and provides both a
visible and an audible indication of operation. That type is also the most common type in the
Pacific due to its high reliability.
1 - 12V fluorescent light that has an electronic ballast that can be separated from the bulb and
has wire leads, not a socket type of mounting. Two pin PL type bulb and ballast for 7W to
11W bulb is recommended since that is widely used in the Pacific and a light of this type has
been manufactured in quantity in Fiji by Poly Products and Clay Engineering for 1993 and
2000 EU PV projects.
1 - Hydrometer for battery testing
1 - 12V automobile head lamp that requires from 4A to 5A to operate
2 - Battery terminal clamps with bolt type connectors for wire attachment
1 - in-line automotive type fuse socket
5 - 10A automotive type fuses
1 - DC toggle switch of the type used in solar installations for appliance switching
1 - roll of 2.5mm2 red wire (50 meters)
1 - roll of 2.5mm2 black wire
1 - Plastic tool box containing:
Good quality wire stripper
Electrician’s pliers
Needle nose pliers
Diagonal cutting pliers
Small adjustable spanner wrench
Small blade type screwdriver suitable for tightening terminal block screws
Medium cross-head (Phillips) type screwdriver suitable for panel wiring connections
Simple inclinometer and level (for setting solar panel angles)
2-Basic digital millimeters capable of measuring 0-50 DV volts and 0-250 AC volts, basic
resistance measurements and DC amperes up to 10A
Appendix 9 - 3
Tape measure (at least 5 meters)
two wire, screw type terminal blocks large enough for joining 2.5mm2 wires
4-1,200 ohm 5% resistors for demonstrating series, parallel and combination connection of
resistance
4-2,400 ohm 5% resistors for demonstrating series, parallel and combination connection of
resistance
2-single battery holders with lead wires suitable for “D” type dry cells
2-single battery holders with lead wires suitable for “AA” type dry cells
Lockable wooden box with handles for carrying sufficient in size to hold the above equipment
with internal clamps to hold the panel, toolbox and battery from shifting during carrying
ADDITIONAL LABORATORY EQUIPMENT FOR GROUP DEMONSTRATIONS AND
EXPERIMENTS
Assumes 20 students, larger classes will need additional equipment to allow multiple
demonstrations
1 - 12V-230V square wave type inverter (cheapest variety), 50 Watt capacity or larger
1 - 12V-230V modified square wave type inverter (cheapest variety) 50 Watt capacity or larger
1 - 12V-230V good quality pure sine wave type inverter, 50 Watt capacity or larger
1 - Commercial semiconductor type charge/discharge controller-basic type, such as a low end
Morningstar controller
1 - Commercial microprocessor type charge/discharge controller, complex type such as
Plasmatronics or STECA type controllers.
10 - Well regulated but low cost variable voltage/current power supplies 0-20VDC 0-5ADC. No
panel meters requires. Basic type units with locally added 10 turn type fine control in series
with the single turn voltage control included with the unit (needed for precise voltage
adjustment to allow exact measurement of voltages for controller experiments).
1 - inexpensive oscilloscope to show 50HZ wave shape of inverters and charging patterns of
semiconductor controllers.
2 - High quality millimeters to allow the demonstration of the calibration of the inexpensive
meters provided with laboratory kits
5 - high power variable resistors 0-50 ohms, 100Watt capacity (for showing IV curve of panels)
1 - 50-75Wp solar panel, poly crystalline or mono-crystalline, 36 cells.
1 - 50-75Wp solar panel, amorphous silicon type
1 - 100Wp Demonstration system installed on a school facility showing proper pole type
mounting, wiring, battery and controller mounting, switches, proper light installation and fuse
protection.
Appendix 9 - 4
ESTIMATED COST OF EQUIPMENT FOR PV TECHNICIAN TRAINING
Quantity
2
1
1
1
1
1
1
2
1
5
1
1
1
1
1
1
1
1
1
1
1
1
1
5
4
4
2
2
1
Student laboratory kits
25Wp solar panels
dual panel frame
45Ah car battery
Relay type controller
12V PL Light
Hydrometer
12V car head light
Battery connectors
Fuse socket
10A fuses
Switch
Roll of red wire
Roll of black wire
Tool box
Wire stripper
Electrician's pliers
Needle nose pliers
Diagonal cutting pliers
Small adjustable spanner
Small blade screwdriver
Medium cross-head screwdriver
Inclinomter/level
Tape measure
Two wire terminal blocks
1,200 Ohm resistors
2,400 Ohm resistors
"D" cell battery holders
"AA" cell battery holders
Wooden box
Student Laboratory Kit
TOTAL COST OF 10 KITS (20 students)
Each
(US$)
175.00
75.00
55.00
120.00
25.00
15.00
17.00
2.00
1.00
0.50
3.00
2.50
2.50
7.50
15.00
8.00
7.00
8.00
6.00
3.00
3.00
9.00
7.50
1.25
0.25
0.25
2.50
2.50
250.00
TOTAL
Total
(US$)
350.00
75.00
55.00
120.00
25.00
15.00
17.00
4.00
1.00
2.50
3.00
2.50
2.50
7.50
15.00
8.00
7.00
8.00
6.00
3.00
3.00
9.00
7.50
6.25
1.00
1.00
5.00
5.00
250.00
$1,014.75
$10,147.50
Appendix 9 - 5
1
1
1
1
1
10
1
2
5
1
1
1
Additional Laboratory Equipment
12VDC to 230V AC square wave inverter
12VDC to 230VAC modified sine inverter
12VDC t0 230VAC sine wave inverter
Basic semiconductor controller
Microprocessor type controller
Variable voltage/current supplies with vernier
control
Basic oscilloscope
High quality millimeters as references
High power variable resistors
50Wp solar panel - mono or poly crystalline
50Wp solar panel-amorphous silicon
100Wp complete home lighting system
TOTAL COST FOR ALL PV TRAINING HARDWARE
Each US$
35.00
40.00
75.00
50.00
75.00
Total US$
35.00
40.00
75.00
50.00
75.00
175.00
250.00
450.00
75.00
350.00
300.00
1,200.00
TOTAL
1,750.00
250.00
900.00
375.00
350.00
300.00
1,200.00
$5,400.00
$15,547.50
Appendix 10 - 1
APPENDIX 10
REGIONAL WORKSHOP ON RENEWABLE ENERGY AND ENERGY EFFICIENCY
FIJI, 20-24 FEBRUARY, 2006
Appendix 10 - 2
Overview of the Pacific Regional Renewable Energy and Energy Efficiency Workshop 2024 February 2006, Suva, Fiji
The final workshop for the REEP was held on 20-24 February, 2006 with 20-23 February
consisting of a technical workshop on renewable energy and energy efficiency and 24 February
a regional agency and donor meeting. The participants were invited from each of the 12 Pacific
Forum Island Countries (Cook Islands, Federated States of Micronesia, Fiji, Nauru, Niue,
Marshall Islands, Palau, Samoa, Solomon Islands, Tonga, Tuvalu and Vanuatu) plus Tokelau.
Funding for the workshop came from the REEP budget in the amount of $50,000 and from the
Technical Centre for Agricultural and Rural Cooperation (CTA) in the amount of $20,000. The
participant from Tokelau was funded by UNDP, Apia. Additionally SOPAC provided the
considerable administrative support needed for the workshop. All the persons who were
accepted to participate are directly responsible for designing and/or implementing rural energy
policy and/or development projects that have renewable energy and energy efficiency as a
focus. They were typically persons from governments, utilities or the private sector who have an
energy or environmental focus and their work supports natural resource development in the
form of indigenous energy resources and their management as it relates to energy provision.
Though there have been several regional and sub-regional workshops on specific renewable
energy technologies, notably solar, wind and biofuels, the last regional workshop that reviewed
all forms of renewable energy technology and their relative applicability to the Pacific was over
15 years ago. Therefore the 20-23 February technical sessions focused on the changes in
renewable energy technologies and on the progress of renewable energy implementation in the
Pacific over the past decade.
The workshop targeted renewable energy, energy use efficiency and independent rural power
development, each having strong links to poverty reduction through agricultural production (e.g.
production of the feedstock for biofuels) or agricultural processing (e.g. solar powered water
pumping, crop drying, rural energy delivery systems to allow the use of electricity and biofuels
for processing energy) and gender (e.g. replacement of wood fuels with more efficient and less
harmful energy sources, increased income generating opportunities for women).
The four days of technical presentations were held at the Fiji Centre for Appropriate Technology
and Development (CATD). The Centre is a boarding school for training Fijian villagers in basic
technical skills (including solar photovoltaics, engine repair, basic carpentry, metal work and
plumbing) located away from urban areas approximately 45 minutes by bus from Suva. The
participants remained at the CATD rural campus full time from early 20 February to early 24
February and were then transferred by bus to Suva for the regional agency and donor sessions
held at the Southern Cross Hotel.
From Fiji, Government, academe, NGOs, regional agencies and the private sector were invited
to send representatives to the workshop with no fee required and with lunch provided. The
workshop was honoured to have as a regular participant the Ambassador to Fiji from France.
From Samoa, participants from Government, the private sector, academe and the utility were
funded by the workshop to participate.
Special evening sessions were scheduled at CATD to allow other organizations to take
advantage of the presence of energy officers, utility personnel and private sector participants
from around the region. The Secretariat of the Pacific Regional Environment Programme
(SPREP) used the opportunity to obtain input for a proposed renewable energy support program
and a meeting was scheduled for the Pacific Energy Group (PEG), a group focused on gender
and energy. On the morning of 24 February, a meeting of the Fiji REEP Steering Committee
was held that reviewed the REEP Draft Final Report and the progress of the REEP efforts in Fiji.
Appendix 10 - 3
The goals of the workshop were to:
•
Disseminate the lessons learned from the REEP that were pertinent for the region
•
Introduce the donor community and regional agencies to the projects proposed by the
REEP and seek funding for their further development
•
Transfer technology and experience among the Pacific countries, particularly as relates
to institutional structures for renewable energy powered rural electrification
•
Provide a review of, and update the participants on, the renewable energy and energy
efficiency technologies that can be economically developed in the Pacific Islands
•
Introduce new (for the Pacific) forms of renewable energy use, notably grid connected
wind and grid connected solar PV.
•
Update the participants on the state of the art of ocean energy systems (OTEC, tidal and
wave power)
•
Provide a forum for problem solving, project development and interactive discussions of
the topics presented in the workshop.
•
Place the participants in direct contact with world class experts in the fields of renewable
energy important to the Pacific (Solar, Wind, Biomass, Biofuels)
The evaluation of the workshop by the participants indicated that the workshop met those goals
and that the information received would be of value throughout the region for the development
of renewable energy and energy efficiency efforts.
Appendix 10 - 4
WORKSHOP PROGRAM
MONDAY 20 FEBRUARY 2006:
Opening, Renewable Energy Overview and Energy Efficiency
8.00 – 9.00
Transfer of overseas participants and
resource persons from Peninsula Hotel to
CATD by bus1
9.00 – 10.00
Arrive at CATD
Opening Ceremony – Master of Ceremonies, Herb Wade, REEP Team Leader
10.00 – 10.05
Opening Prayer
Pastor Isimeli
10.05 – 10.10
Opening Statement
Hon. Col. Savenaca Draunidalo
Minister for Works and Energy
Mr. Fernando Garcia
10.10 – 10.20
Opening remarks
10.20 – 10.30
Opening remarks
10.30 – 10.50
Official Photograph
10.50 – 11.15
MORNING TEA
Regional Deputy Director, South
Pacific Sub-regional Office, Asian
Development Bank
Ms. Cristelle Pratt,
Director, SOPAC
Session 1: Renewable Energy Update
11.15 – 12.00
Renewable Energy Technology Update
Status of solar, wind, biomass, biofuel,
biogas, gasifier, OTEC, wave energy
Mr. Herb Wade,
12.00 – 12.30
Trends in the use of renewable energy
in the Pacific
Mr. Jan Cloin, Energy Adviser,
SOPAC
12.30 – 13.30
LUNCH
1
REEP team leader
Most participants arrived in Fiji by the evening of 19 February and resided at the Peninsula
hotel in Suva. Transfer was by bus (about a one hour journey) from the hotel to CATD and
departed at 0800 on 20 February. Those arriving by plane early on 20 February were picked
up at the Nausori Airport.
Appendix 10 - 5
Session 2: Energy Efficiency
13.30 - 14.15
Demand side energy efficiency update
Commercial, industrial, and transport
efficiency improvement
Domestic sector energy efficiency
improvement
Mr. José Lopez
REEP Consultant
Energy Efficiency Service Company
(EESCO) design
14.15 – 15.00
15.00 – 15.30
15.30 – 16.00
Barriers to implementing industrial and
commercial energy efficiency measures.
Using the Energy Efficiency Service
Company (EESCO) concept to lower them.
The Roles of Government, utilities and the
private sector.
Domestic Energy Efficiency
Programmes
The governmental and private sector roles
in domestic DSM
Mr. Felix Gooneratne,
International Institute for Energy
Conservation IIEC
Mr. Felix Gooneratne,
International Institute for Energy
Conservation IIEC
AFTERNOON TEA
Green Productivity Demonstration
Project on Energy Efficiency
Ms. Ranjana Lal,
By the Training & Productivity Authority of
Fiji (TPAF)
Training Officer, Env. Mgmt.
Trade and Productivity Authority
of Fiji (TPAF)
16.30 – 17.00
Improving Energy Efficiency in the
Transport Sector
Mr. Rupeni Mario, Energy
Adviser, SOPAC
17.00 – 17.30
Informal discussion groups: Government
and private sector roles in DSM
Chair: Rupeni Mario,
17.30 – 18.30
Traditional Fijian Welcome with Sevusevu
18.30 – 19.30
EVENING MEAL
16.00 – 16.30
Panel of resource persons
Evening Programme with posters, videos and discussions
Appendix 10 - 6
TUESDAY 21 FEBRUARY 2006: Solar Energy
7.00 – 8.00
BREAKFAST
Session 3: Solar Energy
Components for Solar Home Systems
8.00 – 8.45
Specification of panels, controllers,
switches, batteries, wiring. Use of inverters
with SHS. Larger SHS to do more than
lighting.
Mr. Luc Hoang-Gia,
REEP Consultant
PV SHS Rural electrification.
8.45 – 9.30
Private sector involvement. The Renewable
Energy Service Company (RESCO)
approach in Kiribati
9.30 – 10.00
MORNING TEA
10.00 – 10.45
10.45 – 11.30
11.30 – 12.30
12.30 – 13.30
SEC Kiribati
RESCOs – The Fiji Experience
Mr. Paula Katirewa,
Update on the RESCO experiences and an
outline of future plans for replication
Energy Analyst, Fiji Department
of Energy
Nabouwalu Hybrid System Experiences
Mr. Inia Saula,
Update on the history, experiences and
outlook for hybrid power systems in Fiji
Energy Analyst, Fiji Department
of Energy
Stand-Alone Systems
PV mini-grids, their concept and application
Mr. Heinz Böhnke
Technosol, Germany
LUNCH
Grid Connected Solar PV
13.30 - 14.30
Mr. Terubentau Akura,
Concept and application of solar PV for grid
connection. The German experience
Solar Thermal – Technical Options
14.30 – 15.00
Trends in solar water heating and their
appilcations
15.00 – 15.15
AFTERNOON TEA
15.15 – 17.00
Country Presentations
17.00 – 18.30
Walking tour: visit to neighbouring village
18.30 – 19.30
EVENING MEAL
Mr. Heinz Böhnke
Technolsol, Germany
Mr. Herb Wade,
REEP Team leader
Palau, Cook Islands, Greenpeace
Appendix 10 - 7
WEDNESDAY 22 FEBRUARY 2006: Biofuels
7.00 – 8.00
BREAKFAST
Session 4: Biofuels
8.15 – 8.35
Opportunities for Biofuels in the
Pacific
Introduction
Mr. Jan Cloin,
Energy Adviser, SOPAC
8.35 – 10.00
Biofuel Fundamentals
From plants to fuel
Dr. Gilles Vaitilingom,
CIRAD, France
10.00 – 10.30
MORNING TEA
10.30 – 11.00
REEP proposal for biofuel in Fiji
(Rotuma)
Mr. Herb Wade,
REEP Team leader
11.00 – 11.30
Petroleum Fuel Outlook for the Pacific
Current situation and outer island supply
problems; hidden subsidies
Mr. Jared Morris,
Pacific Islands Forum Secretariat
11.30 – 12.30
Experience with Biofuels by SPC, in the
Pacific & Evaluation of Welagi and
Lomaloma biofuel projects, Fiji.
Mr. Patrice Courty
REEP Consultant & Rupeni Mario,
12.30 – 13.30
LUNCH
13.30 – 14.30
Community Development and Biofuels
The Philippines experience
14.30 – 15.00
Group discussion on Small Scale
biofuel applications
15.00 – 15.15
AFTERNOON TEA
15.15 – 16.15
Biofuels for the Pacific – Technical
Options
Coconut biofuel options: raw, filtered,
blends, esters.
16.15 – 17.00
Questions & Answers on Biofuels
Expert panel and interactive discussion
Ms. Perla Manapol
UN Foundation (UNF) Consultant
Panel of experts
Dr. Gilles Vaitilingom
CIRAD, France
Dr. Gilles Vaitilingom, Mr. Jared
Morris, Mr. Patrice Courty, Ms.
Perla Manapol
18.00 – 19.00
EVENING MEAL
19.00 – 20.00
Evening Programme with social gathering and kava drinking.
Appendix 10 - 8
THURSDAY 23 FEBRUARY 2006: Wind, Biomass and Ocean Energy
7.00 – 8.00
BREAKFAST
8.15 – 8.45
Overview of Wind Energy in the Pacific
What is happening with wind energy in the
Pacific?
Mr. Thomas Jensen
Associate Programme Specialist
ReP-PoR UNDP
8.45 – 9.30
Wind Resource Assessment
Theory, software, tools; from meters per
second to kWh
Mr. Jan Cloin, Energy Adviser,
SOPAC
9.30 – 9.45
Wind Yield Analysis
Experience with the wind turbine in Nabua,
Suva
Ms. Winnie Veikoso, Project
Officer, SOPAC
9.45 – 10.15
MORNING TEA
10.15 – 10.55
Grid connected, stand alone and
hybrid wind systems
The advantages and disadvantages of each
configuration. Characteristics of technology
needed
Session 5: Wind Energy
Mr. Jerome Sudres, Manager,
Vergnet Pacific
Session 6: Biomass Gasification, Ocean Energy, Future Alternatives
10.55 – 12.00
Biomass Gasification
State of the art, state of the industry.
Environmental issues.
CPC Biomax Gasifier experience in
Philippines.
Dr. Gilles Vaitilingom
CIRAD, France & Ms. Perla
Manapol, UNF Consultant
12.00 – 12.30
Solomon Islands, Tonga
12.30 – 13.30
LUNCH
13.30 – 14.20
Vanuatu, Papua New Guinea
14.20 – 15.00
Ocean Energy
Tidal, wave and OTEC technologies and
their application to the Pacific
Mr. Anthony Derrick,
Co-Director, IT Power
15.00 – 15.15
AFTERNOON TEA
15.15 – 15.45
Hydrogen, Fuel Cells and Other Energy
Technologies
State of the art, commercialization,
Problems for PICs; siting of conversion
equipment; economics.
Mr. Rupeni Mario,
15.45 – 16.15
Tuvalu, Samoa
16.15 – 16.20
Closing Prayer for the CATD Sessions
Peni Delai
17.30 – 18.30
EVENING MEAL (Fiji Traditional Lovo)
19.00 – 20.00
Informal evening programme with kava drinking and music.
Appendix 10 - 9
FRIDAY 24 FEBRUARY 2006: Regional Programme Progress Review and Consultations
7.00 – 8.00
BREAKFAST at CATD
8.00 – 9.00
Transfer from CATD to Suva by bus2
9.00 – 10.00
Participants book into Peninsula Hotel and
walk down to the Southern Cross Hotel
10.00 – 11.30
Welcoming Tea at the Southern Cross Hotel
11.30 – 13.00
REEP Programme review
13.00 – 14.00
LUNCH
2
REEP Consultancy Team
Overseas participants were housed in the Peninsula Hotel in Suva on the evening of the
24th. Transfer was by bus (1 hour ride) from CATD to the hotel departing at 8.00 am on
24th February.
Appendix 10 - 10
Regional Agency and Donor Meeting at the Southern Cross Hotel, Suva
Programme Friday 24 February 2006
14.10 – 14.40
REEP Results Presentation
14.40 – 14.50
European Commission activities in the
energy sector in the Pacific region
14.50 – 15.00
PPA Regional Energy Activities
REEP Consultancy Team
Mr. Horst Pilger
Adviser, Infrastructure and Energy,
Delegation of the European Commission for
the Pacific
Mr. Tony Neil
Executive Director, Pacific Power
Association
Mr. Thomas Jensen
15.00 – 15.10
Activities of ReP-PoR in the Pacific
Associate Programme Specialist ReP-PoR
UNDP
Mr. Solomone Fifita
15.10 – 15.20
PIGGAREP – Update on progress
15.20 – 15.30
PIEPSAP – Highlights
15.30 – 15.40
Small Scale Electrification Initiative for
the Pacific islands
15.40 – 15.50
ESCAP Activities on Renewable Energy
15.50 – 16.00
Pacific Islands and Renewable Energy
16.00 – 16.30
Discussions on the way forward for
Renewable Energy in the Pacific
16.30 – 17.00
Closing Tea
Chief Technical Adviser, Secretariat of the
Pacific Regional Environment Programme
(SPREP)
Mr. Gerhard Zieroth
Manager PIEPSAP, SOPAC
H.E. Eugène Berg,
Ambassador of the republic of France to Fiji
Mr. Antti Piispanen,
Programme Officer, UNESCAP Pacific
Operations Centre (UN-EPOC)
Mr. Paul Fairbairn,
Manager Community Lifelines Programme,
SOPAC
Moderator: Mr. Herb Wade
Appendix 10 - 11
PARTICIPANT LIST
COOK ISLANDS
Alistair Newbigging
Samabula, Suva
G.P.O. Box 2493
Government Buildings
Suva, Fiji Islands
Tel:
[679] 338 6006
Fax:
[679] 338 6301
Te Aponga Uira o Tumu-Te-Varocaro
Box 112
Rarotonga
Tel:
[682] 20054
Fax:
[682] 21944
Email: [email protected]
Tangitamaiti Tereapii
Energy Division
P.O.Box 129
Rarotonga
Tel:
[682] 24484
Fax:
[682] 24483
Alternative Email: [email protected]
Inia D Saula
Senior Scientific Officer
Intiyaz Khan
Senior Energy Analyst - Energy Efficiency,
Biofuels, Renewables
Jimione Fereti
Scientific Officer
E-mail: [email protected]
Makareta Sauturaga
FEDERATED STATES OF MICRONESIA
Acting Director
Ms Carleen Solomon
Manager Alternate Energy Division
Pohnpei Utilities Corporation
Kolonia, Pohnpei FM96941
Federated States of Micronesia
Tel:
[691] 320 3236
Fax:
[691] 320 3235
Mika Belena
FIJI ISLANDS
Coconut Industry Development
Authority (CIDA)
Centre for Appropriate Technology and
Development (CATD)
Nadave, Nausori
Private Mail Bag
Fiji Islands
Tel: [679] 347 7699 / 3479776
Energy Analyst - Renewables
Paula Katirewa
Acting Senior Energy Analyst - Renewables
Susana Pulini
Scientific Officer
1st Floor Garden City, Raiwaqa
P.O Box 5160
Tel: [679] 327 5030
Fax: [679] 327 5035
Sekope Bula
Inosi Navoto
Coconut Technical Specialist
Instructor
CATD
Tevita Kete
Peni Delai
Instructor
CATD
Coconut Development Specialist
Appendix 10 - 12
TRAINING & PRODUCTIVITY
AUTHORITY OF FIJI
KIRIBATI
Ranjana Lal
Acting Energy Planner
Ministry of Works & Energy
P O Box 498
Betio, Tarawa
Tel:
[686] 26192
Fax:
[686] 26172
Training Officer – Env. Mgmt
Productivity & Quality Training Department
PO Box 6890
Nasinu Fiji Islands
Tel: [679] 339 2000 Ext 289
Fax: [679] 339 8973
Web site: www.tpaf.ac.fj/pqtd
ORGANIC PACIFIC LIMITED
Peni Drodrolagi
Organic Pacific Limited
PO Box 12813, Suva
Fax: [679] 330 5693
POLY PRODUCTS (FIJI) LTD
Jitendra Mehta
Managing Director
P.O Box 5171, Raiwaqa
Suva, Fiji Islands
Tel: [679] 3385 544
Fax: [679] 3370 052
Kireua Bureimoa Kaiea
Terubentau Akura
Manager
Kiribati Solar Energy Company
Solar Energy Company
Betio, Tarawa
[email protected]
MARSHALL ISLANDS
William (Billy) Schutz
Solar Engineer
Marshall Energy Company
P.O. Box 1439
Majuro, Marshall Islands
Tel:
[892] 625 5885
Fax:
[892] 625 5886
Fiji Prime Minister’s Office
P.O.Box 2353
Suva, Fiji Islands
Tel: [679] 321 1699
Fax: [679] 331 5751
Akuila Ratu
Julia Tamane
Rakesh Prasad
Saipora Mataikabara
NAURU
Abraham Aremwa
Utilities Superintendent
Central Utilities
Ministry of Utilities Government Offices
Boe District
Republic of Nauru
Central Pacific
Tel:
[674] 444 3521
RES, Ltd.
Krishn Raj
Director
RESCO Limited
P.O Box 5045
Labasa, Fiji Islands
Tel: [679] 881 2618
Fax: [679] 881 5018
Mobile: [679] 992 3018
NIUE
Speedo Hetutu
General Manager
Nuie Power Corporation
P.O Box 198
Alofi, Niue Island
Ph:
[683] 4119
Fax:
[683] 4385
Appendix 10 - 13
PALAU
Greg Decherong
Energy Programs Manager
Ministry of Resources & Development
Bureau of Public Works
PO Box 100
Koror
Republic of Palau
Tel:
[680] 488 96940
Fax:
[680] 488 2536
PAPUA NEW GUINEA
Collin Kalimba
Department of Petroleum & Energy
Energy Division
PO Box 494
Waigani NCD
Papua New Guinea
Tel:
[675] 325 3233
Fax:
[675] 325 1678
Idau Kopi
Department of Petroleum & Energy
P O Box 494
Waigani, NCD
PNG
Tel:
[675] 325 3233
Fax:
[675] 325 1678
SAMOA
Grant Percival
PO. Box 1872
Apia, Samoa
Tel: [685] 24177 / 20368
Mau Simanu
Head of the Electrical Division
Samoa University,
Institute of Technology
Sili`a Kilepoa-Ualesi
Energy Coordinator
Economic Policy and Planning Division
Ministry of Finance
Tel:
[685] 34 333/34341
Fax:
[685] 21 312/24779
Siloma Tago
Mechanical Team Leader
Power Generation
Electrical Power Corporation
Tel:
[685] 65611/7786314
Fax:
[685] 23430
SOLOMON ISLANDS
John Korinihona
Director of Energy
Department of Mines & Energy
PO Box G37
Honiara, Solomon Islands
Tel:
[677] 21521
Fax:
[677] 25811
[email protected]
David Iro
Technician
Willies Electrical
P.O.Box R169
Ranadi-Honiara
Solomon Islands
Tel:
[677] 30508 / 75126
Fax:
[677] 30477
TONGA
‘Ofa Sefana
Energy Officer
Energy Planning Unit
Ha'apai PV Project Manager
Pangai
Ha’apai, Tonga
Tel:
[676] 60 510
Fax: [676] 60 200
Wesite: www.lands.gov.to
Talanoamoeloto `Aholahi
Energy Officer
EPU/Niuafo’ou PV Project Manager
Ministry of Lands Survey and Natural Resources
P.O. Box 5, Nuku’alofa, TONGA
Tel:
[676] 23-611
Fax:
[676] 23- 216
Website : www.lands.gov.to
Appendix 10 - 14
TOKELAU
Kapuafe Lifuka
John Bosco Petelo
Energy Officer
Chief Engineer
Fakaofo, Tokelau
Tel:
[690] 3124
Fax:
[690] 3103
Email:[email protected]
VANUATU
Donald Wouloseje
Energy Economist
Energy Unit
PMB 9067
Port Vila
Vanuatu
Tel: [678] 25201
Fax: [678] 23586
E-mail:[email protected]
TUVALU
Ministry of Works & Energy
Funafuti, Tuvalu
Tel:
[688] 20056
Fax:
[688] 20207
Molipi Tausi
Energy Planner
CROP- EWG
Secretariat of the Pacific Regional
Environment Programme (SPREP)
Solomone Fifita
Chief Technical Advisor
Secretariat of the Pacific Regional Environment
Programme (SPREP)
PO Box 240, Apia, Samoa
Tel: [685] 21929
Fax: [685] 20231
Website: www.sprep.org
Pacific Power Association
Naibati House
Goodenough Street
Private Mail Bag
Suva
Tel: [679] 330 6022
Fax: [679] 330 2038
Tony Neil
Executive Director
Gordon Chang
Assistant Director
Pacific Islands Forum Secretariat
Jared Morris
Import Management Advisor
Trade & Investment Division
Pacific Island Forum Secretariat
Private Mail Bag
Suva, Fiji
Tel: [679] 331 2600
Fax: [679] 331 2226
Web site: www.forumsec.org.fj
South Pacific Applied Geoscience
Commission (SOPAC)
Private Mail Bag GPO
Suva, Fiji
Tel: [679] 3381 377
Fax: [679] 337 0040/338 4461
Website: www.sopac.org
Cristelle Pratt
Director
Appendix 10 - 15
Paul Fairbairn
‘Emeline Veikoso
Manager Community Lifelines Programme
Project Officer Energy
Allison Woodruff
Gerhard Zieroth
Resource Economist
PIEPSAP Manager
Jan Cloin
Anare Matakiviti
Energy Adviser
Energy Adviser PIEPSAP
Pooja Pal
Yogita Chandra
Project Assistance
Project Officer - PIEPSAP
E-mail:[email protected]
Rupeni Mario
Adviser - Energy
INTERNATIONAL ORGANIZATIONS PARTICIPATING
ASIAN DEVELOPMENT BANK
South Pacific Subregional Office
Level 5, Ra Marama Building
91 Gordon Street, Suva, Fiji Islands
Tel: [679] 331 8101
Fax: [679] 331 8074
Webssite: www.adb.org/spso
EUROPEAN COMMISSION
Delegation of the European
Commission of the South Pacific
Horst Pilger
Tina Seniloli
Infrastructure and Energy Advisor
Private Mail Bag
GPO Suva
Fiji Islands
Tel: [679] 331 3633
Fax: [679] 330 0370
Assistant Project Analyst
GREENPEACE
Fernando Garcia
Regional Deputy Director, South Pacific Subregional Office
IT POWER
Anthony Derrick
Grove House
Chineham Court
Lutyens Close, Chineham,
Basingstoke - Hampshire
RG24 8AG, UK
Tel: 44 (0)1256 392700
Fax: 44 (0)1256 392701
website: www.itpower.co.uk
Koin Etuati
Climate / Energy Campaigner
Green peace
Suva, Fiji
Tel: [679] 331 2861
Fax: [679] 331 2784
TRANSITION INSTITUTE P/L
Dr. Karl Mallon
Transition Institute P/L
PO. Box 440, Church Point
NSW 2105, Australia
Tel: [61-0] 412 25 75 21
Appendix 10 - 16
UNDP
ESCAP
Roderic Evers
Pacific Regional Entrepreneurship Development
Specialist
Private Mail Bag, Suva
Tel: [679] 330 0399 (0)
Fax: [679] 330 1976
Web: www.regionalcentrepacific.undp.org.fj
Antti Piispanen
Programme officer
UNESCAP Pacific Operations Centre
(UN-EPOC)
Suva, Fiji
SUSTAINABLE RURAL ENTERPRISE
Thomas Jensen
Associate Programme Specialist
Asia-Pacific Regional Energy
Programme for Poverty Reduction
(REP-PoR)
UNDP Samoa
Private Mail Bag
Apia, Samoa
Tel: [685] 23 670
Fax: [685] 23 555
Perla L Manapol
President
Sustainable Rural Enterprise
Alkan State University, Main Campus – Banga,
Aklan, Philippines
Tel: [63 3] 6 267 6811
Mobile: [63 9] 16 316-1094
Fax: [63 3] 6 268 4765
Web: http:/coconutsgalore.blogspot.com
OVERSEAS RESOURCE PERSONS
Dr.Gilles Vaitilingom
Biofuels
Biomass Energy
Forestry Department-CIRAD
French Agricultural Research Centre for
International Development
TA 10/16. 73, rue. J.-F.Breton
34398 Montpellier Cedex 5, France
Tel: [33 4] 67 61 5762
Fax: [33 4] 67 61 65 15
Email:
[email protected]
Website: www.cirad.fr
Felix Goonerate
Asia Director
International Institute for Energy Conservation
Asia Regional Office
12th Floor UBC II Building Suite
1208 591 Sukhumvit Rd Wattan
Bangkok 10110, Thailand
Tel:
[66 2] 662 3460 5
Fax:
[66 2] 261 8615
Heinz Böhnke
Technosol
Dipl.-Ing. H.-W. Böhnke
Yachthafenstraße 17, D-21635 Jork
Tel: [49 4] 162 942 707
Fax: [49 4] 162] 942 708
Mobile: 0179- 22 68 693
Appendix 10 - 17
REEP TEAM
BURGÉAP
Herbert Wade
27, Rue de Vanves
92772 Boulogne – Billancourt. France
Tel: 33 146 10 2540
Fax: 33 1 46 10 2549
Web site: www.burgeap.fr
Jose Lopez
Luc Hoang Gia
Patrice Courty
Peter Johnston
Appendix 11 - 1
APPENDIX 11
CASE STUDIES OF RENEWABLE ENERGY AND ENERGY EFFICIENCY
FINANCIAL MECHANISMS AROUND THE WORLD
Appendix 11 - 2
A.
INTRODUCTION
1. This study develops two aspects of energy policy: access to energy, particularly through
renewable energy, and energy conservation.
2. Access to energy is the subject of the first part of this report, and deals with the
development of renewable energy technologies in rural areas. To reach a satisfying rate of
electrified population in remote areas, it is necessary to structure supply through schemes
allowing to take into account the local population will (technology and service) and constraints
(capacity and willingness to pay). Case studies present the possible ways of doing so while
taking into account the lessons learned and the obstacles observed in other developing
countries.
3. Energy conservation amelioration through implementation of financial mechanisms is the
subject of the second part of this report. The studied funds have different functioning, and target
different types of projects. However, they have one major characteristic in common: they will
mainly operate in urban areas, since they all need sufficient concentration of energy
consumption in order to minimise the transaction costs compared to the return expected by both
the funds themselves, and their targets.
4. The common aspect of all case studies lies in fact that they depend on the local government
capacity and willingness to develop a sustainable energy policy. The politician will to do so is a
critical condition of success.
B.
Access to energy in remote areas
5. A major difficulty concerning rural electrification in the Pacific Developing Member Countries
(PDMCs) comes from the fact that the cost of providing electricity is very high, because
consumers are dispersed and domestic markets are small.
6. Overmore, remote communities from the islands are the most disadvantaged because of
their isolated locations. Because the level of energy consumption depends on the availability of
energy services and their affordability, adaptation of energy supply costs to the communities’
financial capacity is critical for poverty alleviation.
7. In the remote rural areas, greater use of renewable energy, coupled with improved energy
efficiency offer populations the possibility of meeting their energy requirements. In addition, as
most of the islands are well endowed with a great potential for renewable energies, renewable
energy technologies are potentially competitive with conventional energy, especially when
environmental externalities are factored into the cost of the analysis.
8. We have included four case studies that fit the following categories of possible institutional
arrangements:
9. Strategic partnerships, generally between private companies and NGOs, or photovoltaic
service companies, that help to finance, supply, install and maintain photovoltaic systems in
exchange of periodic payments. A case study shows the functioning of strategic partnerships
between NGOs and retail business operators in Sri Lanka (Case study n°1).
10. Village committees, lobbying for the access to electricity in their communities. Once a
system is in place, the committee operates and maintains it, collects payments or replacement
charges, amortises credits, and procures replacement parts. Committees are rarely formal legal
entities, have particular decisionmaking methods, and own no assets, but they are easy and
inexpensive to organise and run, they tend to legitimate representatives of their communities,
and they can work even if not all users participate. Such an arrangement is illustrated in the
case study n°2 (in Northeast Brazil).
Appendix 11 - 3
11. Local vendor representatives: some photovoltaic vendors use local agents to perform basic
maintenance and encourage adequate battery replacement. These agents also troubleshoot
and give advice. Although their fees add to the cost of the systems, they provide a necessary
understanding of local needs and problems. Illustrating this model, a sizable, private, largely
unregulated photovoltaic industry has been developed in Kenya (case study n°3).
12. Rural energy corporations. Compared with other rural energy organisations, they are more
expensive to develop and require greater managerial sophistication and more centralised
decisionmaking. But they have a formal legal structure, well-defined administrative and
accounting procedures, and flexible capitalisation mechanisms. Argentina rural electrification
programme gives good ideas of what can be done in order to grant concessions to private
companies while minimising subsidies and promoting renewable energy (RE) sources (Case
study n°4).
13. Rural electric cooperatives. This type of administration requires a willing attitude among
most users and intensive organisational development and training. They provide a formal legal
structure, have well-defined administrative and accounting procedures, tend to be selfregulating, and use democratic decisionmaking. An interesting legal framework for such entities,
named SCIC (Sociétés Coopératives d'Intérêt Collectif) was created in France in 1999, one of
these cooperatives, SINCO, operating in the rural electrification field in Senegal and Mali, shall
be interviewed to gain from its experience.
14. The consultant introduces the main lessons to be learned at the international level
concerning institutional arrangements and financing mechanisms that could possibly be
replicated in the PDMCs. It will be necessary in the near future to deepen the analysis in order
to select the schemes compatible with existing policies, socioeconomic structures, and socio
cultural traditions prevailing in the PDMCs. To achieve this objective, a selection of institutions
that shall be interviewed is presented in appendix.
C.
Energy conservation financial mechanisms
15. The implementation of energy efficient programmes leads to a significant potential reduction
of the running costs for companies and institutions and helps governments achieve their energy
development goals. This fact is true in general, but is particularly accurate in the case of
countries with high energy dependancy, and which costs to access energy services are high.
16. The Pacific Islands illustrate perfectly this situation, and political action should compensate
the difficulty of obtaining the necessary financing, which constitutes too often a major barrier to
the achievement of energy conservation projects, by promoting efficient financial mechanisms in
the field of energy conservation.
17. For a few years, various financial mechanisms have been set up, mainly in the western
countries, in order to break up this barrier. But innovative funds have also been developed in
emerging and developing countries, such as in Thailand or in Eastern Europe. They try to adapt
to the specificity of developing countries and countries in transition as these countries face
several barriers to the development of energy efficiency projects. Those innovative financial
mechanisms are often opposed to classic or traditional Funds. Yet, the relation between them is
rather a complementarity than an opposition, since they need each other to work efficiently or
develop their projects portfolio. A selection of three funds illustrating four mechanisms (the
investment fund example including the creation of an ESCO) implemented in different part of the
world will be presented in this report:
18. Equity participation and indirect investment through ESCOs illustrated by the DEXIA–
FONDELEC fund (Case study n°1).
Appendix 11 - 4
19. Grants and low interest loans to municipalities exemplified by the Canadian Green Municipal
Investment Fund (case study n°2).
20. Zero-interest loans to banks developed by the Thai Revolving Fund for Energy Conservation
(case study n°3).
II.
A.
CASE STUDIES: RURAL ELECTRIFICATION
Rural electrification framework
21. The cost for the production of new technologies is constantly and drastically reducing. But
transmission costs are still a major barrier to the expansion of networks in isolated or not very
populated areas. As a result, it is mainly the urban poors who stand the greatest chance of
benefiting from network reforms. For the rural poor, alternative solutions encompassing
organisational innovations are required.
22. Three key factors could drive service improvements in rural areas:
23. Technological advances that reduce costs and increase ease of use and maintenance of
small-scale electricity systems by households and communities,
24. Organisational innovations that help communities choose, implement, and maintain
improved systems,
25. Innovations in financing that help poor households overcome the hurdle of high capital costs
for new services.
a.
Technology limits and need of local involvement
26. Off grid development raises difficult questions for the policy designers:
27. Technology: what technology is most appropriate to bring electricity service to a given
population? What are the costs and benefits of the options, and how should the choice among
them be made?
28. Organisation: a distribution utility, with professional management, may not be involved in
delivering off-grid electricity service. Who is going to introduce, operate, maintain, and repay the
costs of the institutions and technologies for service provision?
29. Financing: off-grid electricity service tends to have much higher capital costs than grid
service. How are these to be financed, given the limits of short-term credit and the low incomes
of most who live off-grid? Many off-grid electricity sources have a long useful life, but their
installation must be amortised over much shorter terms.
b.
Technology drivers
30. By contrast with grid-based supply, the technology options off-grid are very diverse - in
generation technique, in cost characteristics, and in the kind and quality of electricity service
delivered.
31. Governments’ decisions about which off-grid technology to develop in priority are based on
four main criterias:
32. Kilowatt-hour per kilometer of line. Consumption density is used as a criterion to decide
whether to build a line or not. The decision must be adjusted to reflect prevailing net revenues
and line construction costs.
33. Distance from the line. Where density, consumption, and construction costs are similar.
Appendix 11 - 5
34. Least cost. Some algorithms estimate the cost of providing a kilowatt-hour to consumers
using different technologies under different conditions. However, they generally fail to take full
account of the potential benefits from each source.
35. Highest net economic benefit. Estimates of net economic benefit take into account quality
differences between energy sources and compare their potential benefits. But they must be
prepared for every project by qualified staff and are expensive.
36. The central planning–type approach by governments and donors to technology selection
does not work in most places. Customers and service suppliers are not consulted in any
meaningful way, there is no strong sense of ownership of projects, and users lack an
understanding of the true costs of supply. The government should allow customers and service
companies to make the technology decisions, while assuming a facilitating role.
c.
Limits of renewable energy technologies
37. Off-grid electricity differs from grid electricity in that consumption must be actively adjusted
to supply:
38. Some systems provide service for only a few hours a day and thus would not allow
refrigeration and other continuous or off-peak electricity uses. Households and businesses
would use kerosene or LPG for cooking, and fossil fuels to power productive equipment.
39. A mini-hydro plant either supplies insufficient power to meet peak demand or has excess off
peak capacity. So consumers must ration their electricity or develop uses for off-peak supply to
ease the financial burden.
40. Wind – or solar – powered minigrids require an expensive bank of batteries, which puts a
financial cap on the system’s capacity. Electricity service is often limited to fluorescent lights,
radio, and television, and mechanisms are needed to prevent excessive consumption by users.
41. A variety of energy sources can be used to meet off-grid communities’ energy needs.
Lighting and some electronics might be powered by photovoltaic systems, while refrigeration
and cooking depend on LPG or kerosene. Markets for alternative energy sources such as LPG
and kerosene can be stimulated in parallel with limited-supply electricity sources.
d.
A successful electrification programme
42. Energy policy aiming at making energy accessible to remote areas must put in place the
proper environment:
43. A broad universe of projects to choose from. With many diverse projects, a funding agency
can select the projects with the best demand profile and organisational make up and an
adequate willingness and capacity to pay. As the market develops, projects aiming at reaching
more marginal users will become increasingly feasible.
44. Appropriate system designs. System designs must meet the customer’s functional
requirements - no more, no less.
45. Technical support. Training and organisational development must be part of the initial
investment package.
e.
Conclusion
46. Successful off-grid energy projects must understand and address, at the local level, the
nature of the demand and its interaction with:
47. The local energy source.
Appendix 11 - 6
48. The local operating organisations.
49. All possible project development actors, beginning with the communities.
50. Other market agents, such as local vendors.
51. Other energy suppliers.
52. For off-grid to develop, it needs an expanded role for users, a diversity of organisational
models, a greater reliance on local organisations, and a greater knowledge on both the energy
supply in the broadest sense and the energy demand on site.
B.
A programme suited for strategic partnerships in Sri Lanka
53. Since the mid 90s, end-user finance of solar home systems has widely developed through
different and complementary schemes in Sri Lanka. There are many lessons to learn from the
relative success and failure of existing schemes. However, this case demonstrates that
microfinance institutions may well be the most suitable entities to facilitate finance for rural
energy services.
1.
Government/Donor Initiative
54. In 1996, the funding of the Energy Services Delivery Project (ESD) by World Bank’s Asia
Alternative Energy Unit and the Sri Lankan government opened the door for many types of
renewable energy project developers and participating credit institutions (PCIs) to provide solar
home systems to the rural market. A key component of the scheme xas the credit program (the
two others being pilot wind farm and capacity building) that consisted in providing medium and
long term financing to private sector firms, non-governmental organisations, micro finance
institutions and community co-operatives for (a) grid-connected mini hydro projects (typically < 5
MW), (b) off- grid village hydro (VH) schemes, (c) solar home systems (SHS), (d) other
renewable energy investments and (e) energy efficiency/demand side management
investments.
2.
Organisations
a.
Private-Sector SHS Vendors
55. Solar Power & Light Company, which has installed over 150 SHSs since 1997, had its
dealers serve as lenders and collection agents for loans to buyers. Another vendor, Alpha
Thermal, installed 100 SHSs in a similar manner. Difficulties were reported concerning
repayments collection from customers.
56. One of the difficulties under this model is the varying degree of ability and commitment each
dealer feels toward financing.
b.
Large Microfinance NGO
57. Sarvodaya Shramadana Society is one of the largest NGOs in Sri Lanka. It has an extensive
rural network and is involved in education, health care, and social, agricultural, financial, and
energy-related activities. Sarvodaya Rural Technical Services, the technical division of
Sarvodaya, had been involved in SHS since its initial demonstration projects with the Solar
Electric Light Fund in 1991. Sarvodaya already had a rural lending programme administered by
the Rural Enterprises Programme. These organisations were managed by village residents and
provided microfinance for agriculture, home improvement, and small business.
58. Two divisions within Sarvodaya coordinated to implement the SHS project, the Rural
Enterprises Programme, and the Sarvodaya Rural Technical Services. The Rural Enterprises
Appendix 11 - 7
Programme negotiates with the PCI to secure the ESD funding while Sarvodaya Rural
Technical Services markets, installs, and services the SHS. Both divisions ensure that
repayments are made on time.
c.
Private Finance Companies
59. The Finance Company (TFC), a private company quoted on the Colombo Stock Exchange,
provides funds for consumer goods in rural areas. TFC has an extensive regional network and
operates in remote regions. Currently, TFC continues to finance SHS through the local dealers
of Solar Power & Light Company. Ironically, the financing of SHS does not have the sanction of
TFC’s head office; the decision to finance is made by the regional offices. As such, it does not
get much publicity.
d.
Rural Cooperatives and Banks
60. The most prominent specialised rural lending organisation in Sri Lanka is the Thrift and
Credit Cooperative (SANASA). Established in 1906, SANASA boasts more than seven million
member households. The organisation has three tiers (village cooperatives, regional centers,
and the country-level federation). A unique feature of SANASA is the autonomy the village-level
cooperatives have in their operations. All the collected savings only get utilised in the village,
except for the membership fees for the federation. The federation, in turn, provides the financial
management systems, training, and other infrastructure inputs.
61. One of the latest developments with SANASA is the establishment of the SANASA
Development Bank, which is a legitimate entity to access the ESD funds as a PCI.
e.
Commercial Banks
62. Hatton National Bank (HNB) lends directly to SHS customers, with an SHS vendor
supporting the marketing and technical sides of the operation.
63. The vendor, Solar Power & Light Company, identifies interested SHS customers from an
area near an HNB branch. Potential customers have to be an HNB customer or open an
account with the branch. Then, after the bank does the necessary credit evaluation, it finances
70% of the cost of the SHS.
64. Grant Scheme: as part of the ESD project, there is a $100 grant per system provided by the
GEF. This amount is to be held in the customer’s account at the HNB branch until the loan is
repaid, thus giving the bank some financial guarantee while serving as an incentive for the
customer to pay the loan. This amount is returned at the end of the three-year period - which
acts as a bonus for the customer, as part of it could be used to replace the existing battery.
Further, HNB secured a guarantee from Solar Power & Light Company, which ensures that the
product will be repurchased by the company in the event of a customer default.
3.
Lessons learned from the current mechanism
65. As the lending culture of private-finance companies tends to be urban-oriented, such
institutions frequently view rural borrowers as offering returns too small to be worth their
attention. Moreover, rural people may distrust the "urban formalities."
66. Private, supplier-led initiatives have had more success because they tend to work more
closely with the villagers to provide reliable customer service. Moreover, their pricing policies
reflect market rates that foster sustainable market growth. These initiatives, however, often
experience difficulty in carrying out the functions of rural finance and cost recovery.
67. SEEDS (Sarvodaya Economic Enterprise Development Services), has shown good
progress by using its strength in both rural finance and technology transfer. Finance schemes
Appendix 11 - 8
are most successful when operated at a "grassroots" level with some central supervision. A
"bottom-up" approach empowered the rural community to understand the technology as well as
manage the micro-credit programmes.
4.
Obstacles
68. A number of obstacles exist including:
•
•
•
•
•
The market is isolated in remote areas of the country.
The cost of doing business in rural areas is high.
The cost of SHS is relatively high for the target rural market.
The urban-based banking system is uncomfortable lending in rural areas and for rural
projects.
Solar technology is relatively new to the financial institutions, policy makers, and the
market.
C.
A programme based on village committees in Brazil
1.
Donor Initiative
69. In mid-1998, FTV, a private nonprofit foundation established in 1984 in Brazil, requested
financing and technical cooperation funding from the Inter-American Development Bank (IADB)
for the Luz do Sol programme in order to introduce and strengthen solar energy service
microenterprises in rural, northeastern Brazil. Under this proposal, FTV is specifically prohibited
from becoming a financial intermediary; nevertheless, it may act as the conduit between finance
and equipment sources and solar energy microentrepreneurs at the community level. FTV
arranges financing for community leaders through the Northeast Bank of Brazil (BNB) and the
Golden Genesis Company (GGC). By maintaining the involvement of formal financial
intermediaries, FTV reduces its risk and creates favourable conditions for expanded financing in
the future.
2.
Organisations
a.
Northeast Bank of Brazil
70. BNB made $10.4 million ($U.S.) available to the Luz do Sol project, sourced from a special
government line of financing targeted to promote renewable energy. The rate payable by the
community leader on the BNB line of credit is around 8% lower than the open-market rate (of
around 20%). BNB finances half of each community leader’s initial equipment investment and
the loan is amortised over 12 years.
b.
Golden Genesis Company
71. GGC finances the other half of the initial investment and charges the community leader a
rate comparable to BNB’s. GGC pays 2% to BNB as a fee for funds management. GGC
financing is amortised over 5.5 years.
c.
FTV
72. FTV installs the battery-charging systems on the property of the community leader and the
electrical fixtures in the homes of users. GGC financed the start-up of the Luz do Sol
programme in 1996–1997, and pays FTV a fixed amount for each system installed. This fee-forservice payment is made in return for FTV’s services of identifying and mobilising communities,
establishing PV enterprises, providing business and technical training to community leaders,
and monitoring the finances of the programme.
Appendix 11 - 9
d.
Community leaders
73. Community leaders are selected by the community members to become energy service
microentrepreneurs. They borrow funds necessary to the project implementation, are
responsible for the payments of the service for the whole community and act as an intermediary
with the others actors.
3.
Lessons learned
74. Prior to the first installation, FTV carried out significant work identifying and qualifying
communities. A community must meet the following criteria to be considered for the Luz do Sol
project:
It must be at least 3 kilometers from the electricity grid and have no electricity supply.
It must indicate a willingness and ability to financially support an energy service
microenterprise. FTV makes this determination through meetings with family leaders
from the community.
• A minimum of 50 families must be willing and able to pay a $10 ($U.S.) monthly energy
bill in order for the microenterprise to be commercially viable.
75. After screening and prior to establishing a project, FTV requires at least 50 of the
prospective energy customers to pay $10 ($U.S.) each, which is used as a down payment on
the energy equipment.
•
•
4.
Obstacles
76. The main obstacle to the implementation of such a scheme lies the risk of low loan
repayment rate by community leaders. Current and potential financing agents, including banks
and energy suppliers, will not finance a community leade if they do not have confidence that the
loans will be repaid. There are two main causes for poor repayment:
•
•
Technical problems with the equipment,
Shortcomings in the financing model.
D.
Private development of the PV market in Kenya
77. Kenya offers an interesting example of PV market development mainly through private
initiative. There have been donours initiatives since the 80s, focusing on demonstration projects.
However, this has progressively led to a market of over 100 000 installed solar photovoltaic
systems for household use (lighting, radio, or television). Apart from local socio-economic
criterias (GDP, distribution of wealth…), the main reason explaining such success isn’t a
specific government policy, but rather local entrepreneurs capability, that allowed them to play a
key role in the market development process by adapting their products to the needs of the
lower-income market.
78. This case study doesn’t focus on a particular organisation or donor program. It highlights the
importance of local vendor representatives providing suppliers a good understanding of market
opportunities.
1.
Market development
79. Market development occurred in three steps:
•
1. Upper-class rural innovators and nongovernmental organisations (NGOs) working offgrid installed the first complete photovoltaic systems that generated demand for the
technology,
Appendix 11 - 10
•
•
2. Large numbers of rural people bought small photovoltaic panels and batteries,
primarily to power televisions.
3. Hire purchase and finance agencies began to offer systems, allowing far more rural
Kenyans to buy them on credit.
a.
Innovators and NGOs
80. In the 80s, donors installed demonstration systems in off-grid schools and missions. After
several initiatives trained rural photovoltaic agents to install and sell systems, local companies
went after this household market. At that stage, most common systems were well-engineered,
complete systems, up to 100 peak watts, with one battery powering up to ten lights and a black
and white television. They were targeted to upper-class farmers or businessmen owning a
permanent stone house or urban-based Kenyans with disposable income to purchase
photovoltaic systems for their rural homes.
b.
Private companies
81. When the market of large solar home systems saturated, photovoltaic dealers realised that,
as much as electric light was a priority, rural people also wanted television. The rapid massmarket growth of the photovoltaic industry had much to do with the expanded reach of the local
television network.
82. By the mid-1990s, 10 percent of local battery production - as many as 60,000 units a year was being sold in the rural television and photovoltaic system market. More and more
photovoltaic systems were being purchased a piece at a time, and vital system parts - such as
charge regulators, which help protect batteries - were being left out. Yet the poor performance
of smaller photovoltaic modules and systems did not slow sales because many consumers learn
to conserve their modules’ output by using the television and lights less. In addition, many
purchase additional modules later when they can afford them.
c.
Financial institutions
83. Under hire purchase mechanism, a wage employee signs up with a hire purchase company
that automatically deducts monthly payments from his or her salary. In 1996, a leading
photovoltaic company tried to build sales through hire purchase agencies. The company offered
attractive credit terms to hire purchase retailers and sought a wide base of agents. In 1998, the
company sold more than 1,500 systems (and modules) on credit. Today at least four leading
photovoltaic importers supply systems to hire purchase agents, and 15 percent of the solar
home system business passes through hire purchase.
2.
Lessons learned
84. The main conditions permitting to replicate Kenya’s experience are:
•
•
•
•
•
A well-developed middle class and a large number of rural people who want lights and
power for their televisions.
A good flow of customer feedback to local entrepreneurs.
A relatively progressive financial sector that has slowly incorporated photovoltaic
equipment into its consumer goods portfolio.
3.
Obstacles
Duties and VAT must be withdrawn not only from conventional rural electrification
equipment and photovoltaic modules, but also from other components of households
energy equipement (batteries, charge regulators, inverters, and efficient appliances).
Erratic equipment and installation standards. Dealers tend to undersize or leave out vital
components to win contracts, and there is little incentive for proper engineering.
Appendix 11 - 11
•
•
Prevalent sales and installation practices undermine consumer confidence in
photovoltaic equipment, especially larger systems.
Lack of trained technicians. Without systematic technician training, installation, and
hence system quality, will remain poor.
There is a need to develop financing for photovoltaic systems in order to make the
technology more widely available and functional.
E.
IV Innovative scheme for rural energy corporations in Argentina
85. Argentina rural electrification programme gives good ideas of what can be done in order to
grant concessions to private companies while minimising subsidies and promoting renewable
energy sources. Here are the main features of this on-going innovative policy:
•
•
•
•
Concessions are granted to private bidders that require the lowest subsidy for serving a
given area. Renewable energy technologies are favoured wherever possible. Higher
subsidies are paid for renewable energy options.
A model concession contract applicable to all provinces ensures that the concessionaire
maximises private investment and minimises public subsidies. The concessions don’t
have an obligatory coverage target, but concessionaires are required to provide service
to consumers who ask for it.
The subsidy paid to the concessionaire and the customer is means-based and depends
on the energy service level and chosen technology.
Subsidies decline over the fifteen-year concession period.
1.
Donor initiative
86. A misfunctioning of Argentina electricity policy quickly appeared: grid extensions were
favoured to off-grid projects. In 1999, the World Bank implemented the PERMER (Proyecto de
Energía Renovable en el Mercado Eléctrico Rural) project in several provinces in order to
provide electricity for lighting, television and radios to households. The subsidies delivered to
the concessionaires are financed by the Electricity Development Fund, a World Bank loan, and
a Global Environment Facility grant (the portion of this grant will be decreasing over time). The
province of Jujuy was one of the first in which PERMER began implementation, and will be the
focus of this case study.
87. The main difference with the dealership approach used in many other countries is that the
PERMER concessions are exclusive regulated monopolies, while dealerships allow open entry.
Consequently, the selection and regulation of the concessionaire are vital to the success of the
approach. Main advantages of such a mechanism are the following:
Creating a market with sufficient critical mass for commercially sustainable business by
granting exclusive rights over a large geographic area.
• Attracting better-organised private companies with their own sources of financing.
• Permiting easier administration and regulation.
• Offering better chances of covering a large number of customers in a few years.
• Good potential for reducing unit costs of equipment (through volume discounts),
transactions, operations and maintenance (through economies of scale), and overhead.
• Ensuring service to the consumer over a long period - the fifteen-year contract life of the
concession.
88. Main obstacles:
•
•
•
•
•
Implementation challenges in provincial areas where regulatory expertise is less
developed
Quality of service is hard to monitor.
Formal competitive bidding takes time and is costly.
Negotiated contracts may be much quicker but may be less politically acceptable.
Appendix 11 - 12
2.
Jujuy concession functioning
a.
Tariffs and subsidies
89. Considerable analytical work was done under PERMER to assess consumers’ ability to pay,
set the correct tariff levels, estimate required subsidies, decide how subsidies will be paid, and
design incentives to keep these subsidies to a minimum over time. This is intended to serve as
a model for future PERMER concessions.
90. In the case of the Jujuy concession, subsidies have been set so that rural consumers do not
spend more than they now spend on energy.
91. Capacity and willingness to pay: household spending on kerosene, candles, bottled gas,
and dry batteries are a good indicator of the upper limit of electricity tariffs that households can
afford. However, contrary to expectations, surveys have shown that willingness to pay is lower
than capacity to pay. Households may believe that switching to electricity is worthwhile only if it
lowers their energy spending, regardless of the other benefits that come with electricity.
b.
Bidding process
92. The bidding process is intended to provide incentives to minimise subsidies:
•
•
•
First, the regulatory agency calculates tariffs for off-grid electricity supplies by level of
service - for example, 50, 70, 100, 150, or 200 peak watts for solar home systems. For
this purpose the agency estimates costs based on indicative quotations and national and
international experience.
Second, the concession is awarded to the most qualified bidder - based on technical,
financial, and management criteria - offering the largest rebate to the unsubsidised tariff
schedule. The rebate is applied to reduce the subsidy. The concession must be awarded
through international competitive bidding.
Third, where there is bidding for the concession contract, the concessionaire must
procure (following its own procurement rules) and install solar home systems and obtain
certification by the regulatory agency of having done so to receive payment of the
consumer subsidy from the provincial government.
3.
Lessons learned
93. Some details in the functioning of the scheme are critical to its success:
•
•
•
Generally, the local technician is responsible for O&M of the outside parts of the system.
The client has the right to upgrade the inside installation. During the outside installation,
user training must be offered, and a short user manual is provided to the customer with
basic information on functioning, O&M and use of the system.
The customers are asked to pay their monthly invoice with the technicians or in any
office of the local electricity company. No special financial intermediaries exist. The
monthly fees are to be paid within three months as customers are invoiced three months
in advance. In case of nonpayment, the local technician is responsible for the customer
follow-up.
In every office of a local technician, a claim and recommendations book from SuSePu
enables the clients to write down their concerns regarding the provided service. In
reference to the separation definition, only claims concerning the generation part oblige
the concessionaire to repair the defect.
Appendix 11 - 13
4.
•
•
•
•
•
Obstacles
Customers understanding of the set-up of the programme and their responsibilities
within it depend on the technicians who are responsible for customer care in a certain
area.
Even if the restrictions of the systems are well understood, difficult or even lacking
access to converters may lead to an overuse of the systems.
Separation of the generation and internal installation part is rarely understood and
respected by the clients
Use of too many appliances on the clients’ part, which causes frequent failures on the
generation side.
O&M, as well as fee-collection, is costly.
Appendix 11 - 14
III.
A.
CASE STUDIES: FINANCIAL MECHANISMS SUPPORTING ENERGY
CONSERVATION PROJECTS
Energy conservation financing framework
94. Energy conservation in remote areas is a matter of rational use of public funds: when access
to energy is so costly (in the case of PV panels for example), one can not afford to waste
energy. In urban areas, every toe delivered to the end user is cheaper. However, urban areas
concentrate the most part of energy consumption, so that issues such as dependance on energy
imports and trade deficits must be fought there.
95. This part of the study deals with energy conservation development through financial
mechanisms, as illustrated by a selection of three funds operating in different parts of the world.
96. The most difficult part in the implementation of funds such as those presented thereafter
consists mainly in the accurate analysis of the local market and the dialogue with potential fund
managers. Therefore, contrary to the first part of the report, case studies focus on projects
panel, financing mechanisms and conditions of success instead of market stakeholders and
obstacles facing local authorities.
B.
Investment fund and ESCo in Eastern Europe
1.
Presentation
97. The Dexia Fundelec EEER Fund mainly operates in Eastern Euope. Its purpose is to
promote investments in energy conservation and renewable energy and to contribute to the
reduction of greenhouse gas emissions. The fund’s investment strategy includes the valorisation
of these emission reductions as carbon credits. The fund began its operations in 2000. Its
management is ensured by Fondelec Clean Energy Management Corp.
a.
Donor
EBRD, at 20 M€ (28% of the capital),
DEXIA (via its subsidiary company Dexia Public Finances Bank), at 20 M€ (28% of the
capital),
• KPIC Singapore, Kansai Electric and MARUBENI Corporation at 10 M€ each one (14%
of the capital for each one),
• Mitsui & Co Europe (for 1 M€),
• Fondelec C.E.E. Corp. management (at 0,1 M€).
98. The French Global Environment Fund (FFEM) supports the fund by covering part of the
additional cost of the operations arrangement in a region which, although in progress at the
economic and legal level, still remains difficult to access regarding private business.
•
•
b.
Beneficiaries / projects
99. It targets small and average size projects requiring a 1 to 10 M€ investment, which:
improve energy efficiency in existing plants and equipment, e.g. plant retrofits and fuel
conversions, heat recovery systems, electric transmission grids, gas and district heating
system improvements, illumination, other public facilities and industrial energy efficiency
enhancement;
• valorise the use of renewable energy.
100. Until now, the fund has more developed operations from the first category. The
"renewable" projects (two projects to date) are projects of biomass valorisation. The funds
•
Appendix 11 - 15
managers have the will to enlarge their "renewable" portfolio to other types of energy (wind and
hydraulic in particular). The expected average internal rate of return is 20%.
2.
Mechanism
a.
Project Selection
101. The projects on which the fund wishes to invest are submitted to the principal investors
for opinion. The two sponsors have fifteen days to give an opinion. If the opinion is favourable,
the project is submitted to the Investment Committee. If it is negative, the fund manager can
nevertheless present the project at the Investment Committee but with the mention "project
refused by the sponsor".
b.
Mode of intervention
102. The fund can intervene either directly on an energy conservation project or a renewable
energy production project (heat network, industrial process, etc.) or through equity participation
in companies (existing or new) specialized in the realisation of this type of projects (ESCOs).
The fund, through an ESCO, enters into contracts with individual companies or municipalities to
provide the capital, project build-out, and ongoing technical monitoring for specific projects.
c.
Project illustration
103. Example of direct intervention: in Poland, in the town of Gorlice, the fund intervened for
the retrofitting and the optimisation of the heat production infrastructures of the district heating
company, EC. Gorlice. The funds brought 3,7 M€ in capital and 3,3 M€ in convertible debt to the
company. The resources thus invested allowed the realisation of energy conservation operations
on the heat generating stations, the putting into commission of an existing turbine of 7 Mwe and
of a cogeneration plant, as well as the extension of the heat network to new industrial and
residential customers.
104. Example of intervention through specialised companies: in Hungary, the fund
repurchased in December 2000 the consulting and engineering company in energy technology
EETEK Limited. This company then was capitalized and transformed into an energy service
company (ESCO). EETEK is now able to reach potential customers, to lead feasibility studies for
the realisation of energy efficiency projects or renewable energy valorisation projects, to finance
and carry out the investment operations identified in an turn-key approach and to refund them on
the energy savings realised. On this basis, EETEK developed a project portfolio in the private
and public sectors (industry, hospital, street lighting, networks of heats, etc).
d.
Follow-up
105. In Poland and Hungary where most of the investment operations were carried out,
Fondelec detached an associate who, from day to day, ensures the follow-up of the projects at
the administrative and financial level. This restricted team takes the whole decisions relating to
the management of the investment operations carried out and to the new investments and
organises the work and the studies of canvassing new opportunities of investment. The
canvassing work of the manager in the countries where the funds has not invested yet can imply
external consultants. From the end 2001, subsidiary companies or representations of the ESCO
EETEK Hungary (developed by the fund) were created in Bulgaria, Croatia and Slovakia. In
2003, such structures were installed in Poland and Romania.
Appendix 11 - 16
3.
Key findings
An experienced management team
a.
Fondelec, the fund manager, has already worked with the World Bank, and thus has a
knowledge of the principles and methods of intervention of a development bank;
• Fondelec has already worked in the emergent countries (Latin America and to a lesser
extent Eastern Europe) and is presently creating a new fund in Asia;
• Fondelec has specialized in the management of funds dedicated to the investments in
the “utility” sector and in particular in the electricity sector within the framework of
privatisation program.
106.
The local teams are highly qualified in financial issues, have a perfect knowledge of
English and are very dynamic. This constitutes are prerequisite for the fund success.
•
Relevant size of the project
b.
This size of the project selected enables the fund to place itself on the market of SME
and municipalities of average size on which strategic investors (as Dalkia or Elyo) as well as
development banks (EBRD, the World Bank, IFC, etc.) are not very present. Moreover, the fork
of investment selected contributes to an allocation of the fund resources on a more significant
number of projects and thus to a better spread of the risk.
107.
Conditions of replication
c.
•
•
•
•
•
•
Favourable policy and regulatory environment
Reliable legal framework
A favourable business climate
A sophisticated banking system
A local high experienced staff
Economic relative stability
C.
II Green municipal funds in Canada
1.
Presentation
108. The Green Municipal Funds provides the Canadian municipal governments with tools to
implement innovative environmental projects since the yeear 2000.
a.
Donors
109. On the initiative of the Federation of Canadian Municipalities (FCM), the Canadian
Federal Government signed in 2000 an agreement with the Federation of Canadian
Municipalities in which it has engaged itself to bring 125 MCA$ (around 80 M€) to Green
Municipal Funds (GMF). The endowment was doubled to 250 MCA$ in the federal 2001-2002
budget.
b.
Fund Management
110. The FCM manages the Green Municipal Funds through its Centre for Sustainable
Community Development (20 persons). The agreement with the federal government imposes a
limitation of the annual administrative costs at 5 MCA$ (3,2 M€). They are financed by the
interest rates.
Appendix 11 - 17
c.
111. Beneficiaries: The Funds are open to all Canadian municipalities (even those not
belonging to the federation) and their public sector or private-sector partners. The partnership
between a municipality and a private organisation has to be clearly stated either by the financial
participation of the municipality in the investment, by its participation in the input (for instance by
procuring a land for a wind farm project) or by its participation in the output (by contracting a long
term renewable electricity purchase agreement with the firm for example).
112. Projects: the five eligible sectors are: energy and energy services, water, solid waste
management, sustainable transportation services and technologies and integrated community
projects. The project must significantly improve environmental performance or energy efficiency
in these areas of municipal infrastructure.
2.
2Mechanism description
a.
Project Selection
113. Completed applications are reviewed by a Peer Review Committee of two or three
independent experts in the field addressed by the project. These experts come from
government, institutions and/or the private sector. A system of quotation ranging from 0 to 1000
gives a mark to each project. Criteria as environmental improvement (150 points), replication
possibilities (100 points), partnership quality, innovation (230 points) intervene in the notation.
Most of the time, projects with a mark superior to 600 points are recommended by staff.
Recommendations from the FCM’ staff are made to the 15-member Green Municipal Funds
Council. The Council includes representatives from the Government of Canada (one-third), FCM
(one-third), and non-governmental institutions and the private sector (one-third). The council
supports or rejects staff recommendations. Final approval rests with the Board of Directors of
FCM. In theory, not more than 30% of the fund can be allocated to one of the 5 eligible activity
sectors.
b.
114.
Mode of intervention
Two types of funds with similar objectives and criteria:
The Green Municipal Enabling Fund (GMEF): it provides up to 100 000 CA$ (64 000 €)
to cover half the cost of feasibility studies for innovative environmental projects. The fund
helps the Canadian municipalities and their public or private-sector partners to determine
the technical, environmental and/or economic feasibility of municipal projects. The total
amount of GMEF is 50 MCA$ (32 M€). The government should stop providing the fund in
7 or 10 years.
• The Green Municipal Investment Fund (GMIF): GMIF has two main products: the primary
product is loans and the secondary product is grants. Green Municipal Funds Council
decided as a policy to direct half of the Fund’s capital in loans to municipalities and the
other half towards the private sector. The total federal government contribution to GMIF
is 200 MCA$ (128 M€). It is revolving and fixed for an undetermined period. There are
three types of loans:
115. Direct loans to municipalities with very low risk at the preferred interest rate of 1,5%
below the Government of Canada bond rate (which is the Country’s lowest rate: currently 4,8%
per annum for a 10 year term).
•
116.
Corporate loans to private-sector partners;
Appendix 11 - 18
117. Project finance through loans: this type of loan is more risky as, in case of project failure,
the project promoter is not bound to reimburse the loan. The interest rate is thereby higher.
118. GMIF finances up to 25% of the capital costs of a qualifying project. GMIF can also
provide loan guarantees. Loan payback periods may range from four to ten years.
119. If money is still available after the covering of the administrative costs from the interest
rates, the remaining is dedicated to the allocation of grants for GMIF Pilot Projects:
environmental projects that are highly innovative, but have a payback period in excess of 10
years. Special grant funding permits these projects to be structured in ways that offer acceptable
payback periods and levels of risk.
120. The Fund is constantly seeking to develop new loan products to overcome barriers to the
implementation of valuable projects. For example, it is developing two other special tools:
•
•
The “Emission Reduction Rights based financing”: loans will be reimbursed not in terms
of financial flux but by transferring to GMIF the carbon credits gained thanks to the
project’s emission reductions. GMIF will sale those credits to reimburse the loan and the
interest rate. The remaining proceeds from the sale of the credits will be to the benefit of
the project sponsor.
The “Reinvestment loans”: the Fund can lend to projects which are not a priori innovative
if the municipality commits itself to place the economic savings earned by the difference
between GMIF’s interest rate and another financial institutions interest rate into small but
very innovative projects.
c.
Project illustrations
121. City of Ottawa – Integrated Facility Retrofit Pilot – Phase I: Retrofitting of 49 city facilities,
implementing alternative technology applications such as solar hot water and space heating,
solar wall technology, strategic planting, shading and green roofs, rainwater collection, combined
heat and power systems.
122. The city has already achieved a 17% reduction in energy use in its facilities and has
reduced CO2 emissions by 29% since 1990. The retrofit measures will pay for themselves in
approximately 10 years and will cut energy use by 38% over 1990 levels.
123. City of Bécancour – Modernization of the Public Lighting System: this project will replace
over 1 000 existing high-pressure sodium street lights in the City of Bécancour with newly
developed induction lamps. This will cut maintenance costs and reduce electrical consumption,
for street lighting by more than 35%. The new system promises 100 000 hours of service
compared with 24 000 hours for the high-pressure sodium lights.
d.
Follow-up
124. After approbation of the project, a standardised convention is signed between the GMIF
and the municipality (or private organisation) in which a few conditions are settled. Among them,
the municipality has the obligation to sign a “Project Results Reporting Agreement” in which it
commits itself to create a monitoring system, tools to check the results of the project and to
report one year after the project achievement. A grant of 30 000 CA$ (19 000 €) is provided by
the GMIF for this purpose. Staff from the GMIF is especially dedicated to the supervision of the
evaluation process .
3.
•
Key findings
Self-financing: the fund functioning is financed by the investment returns.
Appendix 11 - 19
•
•
•
Highly experienced staff: half of the staff has a specialisation in financial issues and the
other half in environmental issues.
A thruthful fund manager
Need to find a good “niche”: The GMIF must offer really interesting products (very low
interest rates or intervention into risky innovative projects) to attract municipalities or
private partners to compete with offers from other financial institutions.
D.
III A revolving fund for energy conservation in Thailand
1.
Presentation
125. The Thai Revolving Fund for Energy Conservation promotes and develops investment in
energy conservation projects since 2002.
i.
Donors
126. Department of Alternative Energy Development and Energy Efficiency (DEDE) received
approval from the ENCON Fund Committee to use 2 billion Baht (approximately 43 M€) to set up
an EE Revolving Fund. The ENCON Fund is a special fund created by Encon Act 1992 by
collecting small taxes from the use of benzene, diesel, fuel oil and kerosene. At present, the
Fund has been accumulated to the amount of around 17 billion Baht (app. 365 M€).
ii.
Fund Management
127. The Department of Alternative Energy Development and Energy Efficiency (DEDE). A
couple of people from the DEDE are dedicated to manage the Fund and cooperate with the
participating financial institutions. As for the financial institutions, they manage risks related to
the loans, they realise the book-keeping, the credit checking and the customers’ selection.
iii.
128. Beneficiaries: Buildings and factories classified as Designated Facilities (buildings and
factories) according to the 1992 ENCON Act. They are defined as facilities which have an
installed capacity of 1175 kVA of transformers and have a peak demand of 1 MW and above,
consume 20 million MJ or more of electricity annually, use steam power and other nonrenewable energy sources. These Designated Facilities have to comply with government
regulations requiring them to manage their energy use, including lighting energy, air-conditioning
energy, and the building envelope.
129. Projects: Improvement in combustion efficiency of fuels, protection of energy loss,
recycling of energy wastes, substitution of one type of energy by another type, more efficient use
of electricity through improvements in power factors, use of energy - efficient machinery or
equipment as well as use of operation control systems and materials that contribute to energy
conservation, etc.
2.
Mechanism description
a.
•
•
Loan modalities
Term of loan: Not more than 7 years and/or the simple payback period (SPP) shall not be
more than 7 years
Maximum loan size: 50 MBaht per project (1,1 M€). No minimum size for the investment
projects has been set.
Appendix 11 - 20
Maximum interest rate: Not more than 4% per year (amount charged by financial institute
to borrower). This interest rate is intended to cover the financial institutes' management
fees and risk associated with the loan.
130. Costs included in the EE Loan: equipment and installation costs, consulting fee for
design, supervision, and guarantee of savings (e.g., for an energy service company, or ESCO),
construction of a gas pipeline from the main pipeline to the Designated Factory or Building,
transportation and demolition costs, import duties and taxes, and value-added tax (VAT) for the
above costs.
•
b.
Project Selection
131. Interested owners of Designated Facilities need to request a loan application form
through a participating financial institute. Financial institutes approve the EE project loans
according to their regular lending criteria and perform an initial financial analysis of the project.
DEDE considers and approves projects according to the its criteria and conditions.
3.
•
•
•
Key findings
The participation of banks is a key point of the whole scheme as the objective of the
Fund is to give the financial institutions experience on energy conservation projects. In
the middle and long term, DEDE hopes that this mechanism would function with a lesser
public support.
A favourable legal framework: the Energy Conservation Promotion act (ENCON Act) has
fostered energy efficiency awareness in factories and buildings.
A tough competition: saving costs has become a key action to increase competitiveness.
Appendix 11 - 21
IV.
•
MAIN REFERENCES
 www.rsvp.nrel.gov/rsvp
 resum.ises.org
 2000, Energy Services for the world’s poor, World Bank, ESMAP, Energy development
Report 2000
Energy conservation funds
• www.fondelec.com
 www.fcm.ca
 2003, FCM, Green Municipal Annual Report 2001-2002
• Institutions to be interviewed
 September 2002, UNEP Finance Initiatives, Financing Sustainable Energy Directory
Appendix 11 - 22
V.
FINANCIAL INSTITUTIONS PROVIDING RENEWABLE ENERGY FINANCE
1
E+Co
FUND MANAGER
Source of Funds: Multilateral and Foundations
FUNDS AND FINANCING TO SERVE
All, Energy Efficiency
GEOGRAPHIC FOCUS
Asia, Africa, Central and South America
DURATION
2-5 years
TERMS
Provide early stage risk capital.
Will only work with projects that have a clear social and environmental benefit. Must also be
commercially viable (i.e. competitive with conventional alternatives). Must have potential to be
self sufficient in order to attract private investment in the next stages of the development cycle.
COMMENTS
E+Co is a US based group focused on the provision of business development services and seed
capital. Their interest is in supporting indigenous enterprises that are working to provide those in
developing countries with a reliable and affordable source of clean energy.
To date E+Co has provided such support to over 60 enterprises in Africa, Asia and Latin
America. Typically, investment (debt or equity) is limited to US$250,000, but the company is
different from other sources of funding because it is willing to take a higher (but measured)
investment risk by providing a combination of business services and seed capital during the
earliest stages of an enterprise’s growth. E+Co believes that the combination of business
services, seed capital and commitment to local entrepreneurs is the key to success. E+Co comanages UNEP’s Rural Energy Environment and Development programmes (see
www.areed.com) in Africa, Brazil, and China.
CONTACT
Phil Larocco
383 Franklin Street, Bloomfield, New Jersey USA
Tel: +1 973 680 9100 / Fax: +1 973 680 8066
[email protected]
www.energyhouse.com
Appendix 11 - 23
2
Fundacja Ekofundusz
SOURCE OF FUNDS
Debt-for-environment swaps
All types
GEOGRAPHIC FOCUS:
Central and Eastern Europe
COMMENTS
The EcoFund is a foundation established in 1992 by the Minister of Finance for the purposes of
the effective management of funds obtained through the conversion of a part of Polish foreign
debt with the aim of supporting environmental protection-related endeavours (so-called debt forenvironment swaps). To date, Polish debt-for-environment swap decisions have been taken by
the United States, France, Switzerland, Italy, Norway and Sweden; hence the EcoFund is
managing funds provided by all the aforementioned countries (a total of USD 571 million to be
spent in the years 1992-2010).
The task of the Foundation is to co-fund environmental protection-related projects which not only
are of crucial
importance on a regional or national scale, but also influence the process of achieving
environmental objectives recognised as priorities by the international community on a global as
well as European level. Such EcoFund specifics, which distinguish the Foundation from other
funds providing support to environmental protection-related investment in Poland, exclude the
possibility of providing co-funding to undertakings targeting the solving of local problems only.
Another task of the Foundation is the transfer of the best technologies from donor countries to
the Polish market, as well as the stimulated development of the Polish environmental protection
industry.
CONTACT
Bracka 4 St., 00-502 Warsaw, Poland
Tel: +48 (22) 621 27 04 / Fax: +48 (22) 629 51 25
Climate protection [email protected]
Air protection [email protected]
Appendix 11 - 24
3
FMO
SOURCE OF FUNDS
Private, public
All types
GEOGRAPHIC FOCUS
Global
COMMENTS
FMO promotes sustainable development of the private sector in developing countries. Realising
sufficient returns on its risk capital is a prerequisite. Only then can FMO continue to act as an
effective risk partner and ensure the continuity of the organisation. These two aims – sustainable
development and financial returns – are therefore inextricably linked.
FMO has an investment portfolio of € 1.79 billion, making it one of the largest bilateral
development banks. FMO has excellent access to capital markets, in part attributable to the
Triple A status that was conferred in 2000.
FMO’s core activity is to provide local businesses and financial institutions in developing
countries with long-term financing, ranging from loans to equity investments in enterprises. FMO
does this on market terms and only when financing by commercial financiers is either
unavailable or inadequate. Its present portfolio covers 78 countries.
CONTACT
Mrs. B. Hamelynck
Postbus 93060, 2509 AB Den Haag, NL
Tel: +31 (0) 70 314 96 96 / Fax: +31 (0) 70 314 97 64
[email protected]
www.fmo.nl
Appendix 11 - 25
4
Global Environment Fund
FUND MANAGER
Source of Funds: The Fund is partially capitalised with proceeds raised through the issuance of
promissory notes guaranteed by the Overseas Private Investment Corporation.
FUNDS AND FINANCING TYPE
Private equity, project finance, legal structuring, corporate governance, environmental
technologies, and business enterprise development.
Clean energy, potable water, wastewater treatment, resource recovery, natural gas development
and distribution, sustainable forestry, and healthcare infrastructure sectors.
GEOGRAPHIC FOCUS
Latin America, Asia, Eastern Europe, Africa, North America
COMMENTS
Global Environment Fund is currently managing a group of private equity investment funds,
including: two funds dedicated to basic environmental infrastructure in emerging markets and a
U.S. fund focusing on technologies that promote improved efficiency in industrial processes,
energy generation and telecommunications fields.
In addition, through its own capital investment vehicle, Global Environment Capital Company,
LLC, GEF develops, finances, and takes controlling interests in principal investments for its own
account. The capital available for investment through GEF’s equity investment programmes
exceeds $300 million.
CONTACT
Benjamin Sessions, Global Environment Fund
1225 Eye Street NW, Suite 900, Washington, DC 20005 USA
[email protected]
Tel: +1 (202) 789-4500 / Fax: +1 (202) 789-4508
www.globalenvironmentfund.com
Appendix 11 - 26
5
IFC Photovoltaic Market Transformation Initiative
FUND MANAGER
Impax Capital and IT Power
SOURCE OF FUNDS
GEF
FUNDS AND FINANCING TO SERVE:
Solar
GEOGRAPHIC FOCUS
Africa, Asia
COMMENTS
The IFC/GEF Photovoltaic Market Transformation Initiative (PVMTI) is a strategic intervention to
accelerate the penetration of photovoltaics (PV) as a renewable and emission-free source of
electric power in developing countries, especially for offgrid applications. The Global
Environment Facility (GEF) has approved $30 million for the project, of which $25 million is
intended for concessional investments in PV market development projects in India, Kenya, and
Morocco. The remaining $5 million is reserved for implementation costs.
PVMTI is expected to have a significant impact in increasing sales of PV in-country, but its main
impact is expected to be in facilitating the success of several ‘beacon companies’ that will
provide examples of viable PV businesses. The successful investments will demonstrate
financial structures and business approaches that work, thus forming the basis for long-term
sustainability and replicability of projects.
CONTACT
Daniel Edmonds
Broughton House, 6-8 Sackville Street, London W1X 1DD, United Kingdom
Tel: +44 207 434 1122 / Fax: +44 20 7437 1245
[email protected]
www.impax.co.uk
Appendix 11 - 27
6
(REEF)
IFC Renewable Energy and Energy Efficiency Fund
FUND MANAGER
EIF Group, Environmental Enterprises Assistance Fund, Energy House Capital Corp. (see
E+Co)
SOURCE OF FUNDS
GEF
All types
GEOGRAPHIC FOCUS
Developing countries
COMMENTS
The $65 million Renewable Energy and Energy Efficiency Fund (REEF) is an investment fund
targeting renewable energy and energy efficiency projects in developing countries.
REEF targets investments below 50 Megawatts (MW) and small-scale PV operations. REEF’s
investments may take a variety of forms including common and preferred stock, partnership and
limited liability company interests, and convertible or subordinated debt with equity
warrants/options.
REEF may also make loans to projects or project sponsors on a bridge or permanent basis.
Equity transactions are typically structured so that the entrepreneur retains the majority of
shares and/or management of the company.
CONTACT
Projects over 7MW:
Attn: K.R. Locklin EIF Group
727 15th St., NW – 11th floor, Washington, DC 20005 USA
Tel: +1 (202) 783-4419 / Fax: +1 (202) 371-5116
[email protected]
Off-Grid Projects & Development Projects < 7MW:
Attn: Phil LaRocco Energy House Capital Corp. (see E+Co)
383 Franklin Street, Bloomfield, NJ 07003
Tel: +1 (973) 680-9100 / Fax: +1 (973) 680-8066
[email protected]
www.ifc.org/enviro/EPU/Renewable/REEF/reef.htm
Appendix 11 - 28
7
(PPIAF)
Public-Private Infrastructure Advisory Facility
SOURCE OF FUNDS
ADB, Canada, Germany, France, Italy, Japan, Norway, Netherlands, Sweden, Switzerland, UK,
USA, UNDP, World Bank
Technical assistance
GEOGRAPHIC FOCUS
COMMENTS
PPIAF pursues its mission through two main mechanisms:
- channeling technical assistance to governments in developing countries on strategies and
measures to tap the full potential of private involvement in infrastructure
- Identifying, disseminating, and promoting best practices on matters related to private
involvement in infrastructure in developing countries.
PPIAF can finance a range of country-specific and multi-country advisory and related activities in
the following areas:
- Framing infrastructure development strategies to take full advantage of the potential for private
involvement.
- Building consensus for appropriate policy, regulatory, and institutional reforms.
- Designing and implementing specific policy, regulatory, and institutional reforms.
- Supporting the design and implementation of pioneering projects and transactions.
- Building government capacity in the design and execution of private infrastructure
arrangements and in the regulation of private service providers.
CONTACTS
Regional Coordination Office-Eastern/Southern Asia c/o World Bank Liaison Office
10 Shenton Way, #15-08 MAS Building Singapore 079117
Tel: 65 6225 0829 Fax: 65 6324 4615
Appendix 11 - 29
8
Société d’INfrastructures Collectives (SINCO)
SOURCE OF FUNDS
All types
Collective infrastructure
GEOGRAPHIC FOCUS
Mali and Burkina Faso
COMMENTS
SINCO is an established cooperative company that aims at providing communities with
infrastructure, such as electricity local networks, or water and telecom infrastructures.
It has adopted a newly introduced legal framework in france named SCIC (Sociétés
Coopératives d'Intérêt Collectif) that permits to bring together public and private actors that
usually don’t have formal links, such as service providers and consumers.have not was created
in France in 1999, one of these cooperatives, SINCO, operating in the rural electrification field in
Senegal and Mali, shall be interviewed to gain from its experience.
In the field of rural electrification, its strategy is to build local networks aiming at attracting the
public electricity operator in the mid term.
CONTACT
Pierre Saclier
Ouagadougou - 565 Avenue de Loudun
PO Box: 11 BP 452 CMS OUAGADOUGOU
Tel: (226) 30 14 79 / 63 34 00
Appendix 11 - 30
9
Inter American Development Bank
SOURCE OF FUNDS
IADB member countries and capital markets
GEOGRAPHIC FOCUS
Central and South America
COMMENTS
The Bank will actively promote energy development in the region by means of loans and
technical cooperation for technically, socio-economically, and financially feasible projects aimed
at:
• developing alternative sources of energy, especially from renewable resources,
• reducing and/or replacing the utilization of hydrocarbons in the production of energy,
• promoting the efficient use of energy,
• creating and/or strengthening the institutional and technological base of the energy sector.
CONTACT
Daniel Sheppard, Project Specialist
1300 New York Avenue, NW / Washington, DC 20577 USA
Tel: +1 (202) 623-2708
[email protected]
Appendix 11 - 31
10
Triodos Renewable Energy for Development Fund
SOURCE OF FUNDS
Cordaid, Dutch Ministry of Foreign Affairs, Hivos Foundation, Joyce Mertz-Gilmore Foundation,
Rockefeller Brothers Fund, Rockefeller Foundation, Swiss State Secretariat of Economic Affairs,
Stichting Triodos Fonds, World Bank
Solar (photovoltaic and thermal) systems, Small-scale wind turbines, Biomass, Small-scale
hydro projects, Hybrid projects
GEOGRAPHIC FOCUS
COMMENTS
Triodos Bank is a social bank lending only to organisations and businesses with social and
environmental objectives.
Triodos Renewable Energy for Development Fund is a source of finance and business
development support to private sector enterprises, financial institutions and organisations that
facilitate the introduction of and widespread access to off grid renewable energy services to
underserved people in developing countries.
CONTACT
Triodos Bank NV
Utrechtseweg 60, 3700 AB Zeist, The Netherlands
Tel: +31 30 693 65 00 / Fax: +31 30 693 65 55
Appendix 12 - 1
APPENDIX 12
PERSONS CONTACTED IN THE COURSE OF REEP ACTIVITIES
Appendix 12 - 2
FIJI
Name
Position
Address
Contact
Director
Barefoot Power Pty. Ltd.
8/20 Pine St.
West Hobart
Tasmania 7000, Australia
Tel. [613] 6231 0251
Fax. [613] 6231 0591
Mr. Tevita Banuve
(since replaced)
Ministry of Finance and
National Planning
Ra Lalabalavu House
Victoria Pde
PO Box 2212
Suva, Fiji
Tel. [679] 331-3411
Fax. [679] 330 0834
Mr. .Tukana Bavoro
Managing Director
Fiji Development Bank
360 Victoria Parade
Suva, Fiji
Tel.: [679] 331 4866
Mr. John Bennett
Local oil
producer/businessman
Itu'muta
Rotuma, Fiji
Mr. Harry Andrews
H.E. Ambassador Eugène
Berg
Ambassador of France
Mr. Shlendra Prasad
Bilash
Economic & Aid
Researcher
Ms. Shivangini Chand
Bishwa
Project Engineer
Mr. Biulailai Biutiviti
Price Control Officer
Ms. Carolyn Blacklock
Manager, Rural
Banking,
Mr. Ray Bower
General Manager
Dominion House
Thomson street
Private Mail Bag
Suva, Fiji
Embassy of Japan
GPO Box 13045
Suva, Fiji
2 Marlow St.
Suva, Fiji
Prices and Incomes Board
(PIB)
PO Box 1312
Suva, Fiji
ANZ Banking
Corporation
ANZ building, 25
Victoria Parade
Advanced Power Systems,
Fiji, Ltd.
PO Box 10376
Nadi Airport, Fiji
Tel. [679] 331 22 33
Fax. [679] 330 18 94
Tel. [679] 330 4633
Tel. [679] 331 3333
Tel. [679] 330 9266
Fax. [679] 330 9271
Tel. [679] 321 3702
Tel. [679] 672 1160
Lecturer in Chemistry
USP
Chemistry Room 002
Laucala Bay Campus
Suva, Fiji
Tel. [679] 331 3900
Mr. Simon Boxer
Director
PacifcFree Energy Ltd.
PO Box 3520, Lami
Suva, Fiji
Tel. [679] 336 1849
fax [679] 336 1849
Mobile [679] 922-3817
Mr. Ross Brodie
Managing Director
Hydro Development Ltd.
PO Box 3258
Lami, Fiji
Tel. [679] 330 1882
Fax. [679] 330 0866
Dr. Vincent Bowry
Appendix 12 - 3
Name
Position
FIJI (Continued)
Address
Contact
Appliance labelling &
efficiency standards
resident consultant
[AusAID/AGO)
c/o Intiyaz KhanEnergy
Efficiency
OfficerDepartment of
Energy79 Ratu Mara
RoadGPO Box
2493Samabula, Fiji
Tel. [679]448 6006Fax. [679] 448
6301Email: [email protected]
Mr. Sekope Bula
Coconut Technical
Specialist
Coconut Industry
Development Authority
(CIDA)
1st Floor Garden City
Raiwai
PO Box 5160
Suva, Fiji
Tel. [679] 327 5030
Fax. [679] 327 5035
Email:
[email protected]
Mr. David Campbell
Managing Director
Ms. Nalini Chand
Graduate Engineer
Mr. Alvin Chandra
Environment / GEF /
Energy
Associate
Mr. David Brunoro,
Ms.Yogita Chandra
Mr. Gordon Chang
CocoFresh (Fiji) Ltd
PO Box 122
Savusavu, Fiji
2 Marlow St.
Suva, Fiji
UNDP Fiji
Tower Level 6
Reserve Bank Bldg.
Pratt Street
Suva, Fiji
Tel. [679] 331 2386
Tel. [679] 331 2500
Fax. [679] 330-1718
PIEPSAP Project
Officer
PIEPSAP-SOPAC
Mead Road
Nabua
Private Mail Bag
Suva, Fiji
Tel. [679] 338 1377
Fax. [679] 337 0040
Deputy Executive
Director
Private Bag
Naibati House
Goodenough St.
Suva, Fiji
Tel. [679] 330 6022
Fax. 330 2038
Tropik Wood Industries
Ltd.
Private Mail bag
Lautoka, Fiji
Fiji Chamber of
Commerce & Industry
178 Lakeba St.
Samabula, Fiji
Office: [679] 666 1388
Mr. Alec Chang
CEO
Mr. Humphrey Chang
V/President
Mr. Chris Cheatham
Consultant
10 Allardyce Road
Suva, Fiji
Tel. [679] 330 4524
Fax. [679] 330 4524
Manager
Telesource (Fiji) Ltd.
25 Gorrie St.
GPO Box 17289
Suva, Fiji
Tel. [679] 331 3750
Fax. [679] 331 3003
Mr. Kord Christianson
Tel. [679] 338 5788
Appendix 12 - 4
Name
Position
FIJI (Continued)
Address
Contact
Fiji Representative,
Tinytech Oil Mills,
India
PO Box 11098
Laucala Beach Estate
Suva, Fiji
Tel. [679] 359-3272
Mobile: [679] 999-6550
Mr. Bruce Clay
Managing Director
Clay EngineeringLot 2
Wailada
SubdivisionLamiP.O. Box
2395Government
BuildingsSuva
Tel. [679] 336 3880Fax. [679] 336
Mr. Jan Cloin
Renewable Energy
Adviser
SOPAC
Mead Road
Private Bag
Suva
Tel. [679} 338-1377
Ms. Marylyn Cornelius
Assistant Resident
Representative (GEF)
Mr. Sitiveni
Daunakamakama
Senior Lecturer,
Electricity
Mr. Sunil de Silva
Chief Financial Officer
Mr. Ian Chute
UNDP, Suva
Central Bank Building
Private Bag
Suva, Fiji
Fiji Institute of
Technology
Ratu Mara Road
Samabula, Fiji
2 Marlow St.
Suva, Fiji
Tel. 331 2500
Tel. [679] 338 1044
Tel. [679] 331 1818
Instructor
Centre for Appropriate
Technology and
Development
Nadave
Private Bag
Nausori, Fiji
Tel. [679] 347 7699
Fax. [679] 347 9776
Manager EU-REP-5
IT Power
level 2
Garden City
Raiwai
Suva, Fiji
Tel. [679] 327 5047
Fax. [679] 327 5046
Mobile. [679] 990 4154
Email:
[email protected]
Minister for Works &
Energy
Ministry of Works &
Energy, Nasilivata House
Ratu Mara Road
Samabula
Suva, Fiji
Tel. [679] 338 4111
Mr. Peni Drodrolagi
Director
Organic Pacific ltd.
PO Box 12813
Suva, Fiji
Ms. Koin Etuati
Climate/Energy
Campaigner
Greenpeace
Victoria Pde.
Suva, Fiji
Mr. Peni Delai
Mr. Anthony Derrick
Hon Col. Savenaca
Draunidalo
Tel. [679] 992-0504 (mobile)
Fax. [679] 330 5693
Email:
[email protected]
Tel.[679] 331 2861
Fax. [679] 331 2784
Email:
[email protected]
Appendix 12 - 5
Name
Position
FIJI (Continued)
Address
Contact
Senior Training Officer
(Electronics/Electrical)
Training & Productivity
Authority of Fiji (TPAF)
Lot 1 Beaumont Rd
Narere
PO Box 6890
Nasinu, Fiji
Tel. [679] 339 2000 ext 260
Mr. Roderic Evers
Pacific Regional
Entrepreneurship
Specialist
UNDP FijiPacific
Subregional Centre2nd
Floor, YWCA
BuildingRatu Sukuna
ParkPrivate Mail
BagSuva, Fiji
Tel. [679] 330 0399
Fax. [679] 330 1976
Mr. Rod Evers
Sustainable
Livelihoods
Programme
Mr. Paul Fairbairn
Programme Manager,
Community Lifelines
Programme
Dr. John Faitaki
Chairman
Mr. Jimione Fereti
Scientific Officer
Mr. Tulemaaga Fereti
Filipe
Petroleum and
Environment
Consultant
Ms. Sharyne Fong
Asst. General Manager
Support Services
Justin Fuller
General Manager
Operations
Mr. Wade Evans
Mr. Thomas GloerfeltTarp
Head
Dr. Hugh Govan
Sustainable
Livelihoods
Programme, UNDP
Mr. Goeff Green
Director
UNDP
YWCA building, 2nd
level, Sukuna Park
Suva, Fiji
SOPAC
Mead Road
Suva, Fiji
Rotuma Investment Ltd.,
Fiji
199 Ratu Sukuna Road
Suva, Fiji
(DOE)
Ratu Mara Road
Samabula
GPO Box 2493
Suva, Fiji
3a Stirling Place
Lami, Fiji
Colonial National Bank
1st. Flr. Parade Bldg.
67-69 Victoria Pde.
Suva, Fiji
Tropik Wood Industries,
Drasa
Private Mail Bag
Lautoka, Fiji
Project Administration
Unit –ADB South Pacific
Subregional Office
Level 5 Ra Marama Bldg.
91 Gordon St.
Suva, Fiji
YWCA building, 2nd
level, Sukuna Park
Suva, Fiji
Green Consultancy ltd.
PO Box 300
Suva. Fiji
Tel. [679] 331 2250
Tel. [679]338 1377
Fax. [679] 337 0040
Tel.[679] 330 4958
Fax.[679] 331 4669
Tel. [679] 338 6006
Fax. [679] 338 6301
Tel. [679] 321 4169
Fax. [679] 330 4122
Tel. [679] 666 1388
Fax. [679] 1561
Tel. [679] 331 8101
Fax. [679] 331 8074
Web: www.adb.org/spso
Tel. 331 2250
Tel. [679] 330 8849
Mobile: [679] 929 9260
Appendix 12 - 6
Name
Mr. Rafiq Hamid
Position
FIJI (Continued)
Address
Transport Pool
Mechanical Section
Walu Bay
Suva, Fiji
Regional Secretariat,
Foundation for the
Peoples of the South
Pacific International
6 Des Vouex Road
Private
Fiji Broadcasting Corp..
PO Box 334
Suva, Fiji
ADB
Subregional Office
91 Gordon St.
Suva, Fiji
Contact
Tel. [679] 330 2211
Mr. Rex Haroi
Executive Director
Mr. Malcolm Harrison
Businessman
Mr. Francis Herman
CEO
Dr Sophia Ho
Principal Country
Programs Specialist
Mr. Rex Horoi
Executive Director
Foundation for the
Peoples of the South
Pacific International6 Des
Voux RoadSuva, Fiji
Tel. [679] 331 2250
Fax. [679] 331 2298Email:
[email protected]
Managing Director
Natural Power Ltd
(subsidiary of
Asia Pacific Resources,
Ltd.)
Savusavu, Fiji
Email:
[email protected]
Ms. Sirpa Jarvenpaa
Regional Director
ADB
Subregional Office
91 Gordon St.
Suva, Fiji
Tel. [679] 331 8101
Mr. Peter Johnston
REEP consultant
111 Prince's Road
Samabula, Fiji
Tel. [679] 337 0861
General Manager
Management and
Technology
TPAF
PO Box 6890
Nasinu, Fiji
Tel. 339-2000 x 305
Fax.339 8973
Acting Senior Energy
Analyst (Renewables)
(DOE)
Ratu Mara Road
Samabula
GPO Box 2493
Suva, Fiji
Tel. [679] 338 6006
Fax. [679] 338 6301
Coconut Development
Specialist
Coconut Industry
(CIDA)
1st Floor Garden City
Raiwai
PO Box 5160
Suva, Fiji
Tel. [679] 327 5030
Fax. [679] 327 5035
Email:
[email protected]
Mr. Matthew Huggan
Mr. Jogesh Karan
Mr. Paula Katirewa
Mr. Tevita Kete
Tel. [679] 331 2250
Tel. [679] 992 1294
Tel. [679] 331 4333
Fax. [679] 330 2643
Tel. [679] 33 8101
Appendix 12 - 7
Name
Position
FIJI (Continued)
Address
Mr. Intiyaz Khan
Senior Energy Analyst
(Energy Efficiency)
Mr. Matai Korosaya
Business Banking
Dr. Sander Kroes
Technical Manager
Ms. T. Kubo
AID Coordinator
Hon. Ratu Jone Yavala
Kubuabola
Minister of Finance
Mr. Davendra Kumaran
Deputy Secretary
Mr. Paula Kunabuli
Acting Commissioner
Eastern
Ms Ranjana lal
Training OfficerEnvironmental
Management
79 Ratu Mara Road
GPO Box 2493
Samabula, Fiji
Colonial Bank
Private Mail Bag
Suva, Fiji
Fiji Sugar Corporation
Weatern House
Private Mail Bag
Lautoka, Fiji
Japanese Embassy
Floor 2 Dominion House
Suva, Fiji
National Planning
Ra Lalabalavu House
Victoria Pde
PO Box 2212
Suva, Fiji
Ministry of Works &
Samabula
Suva, Fiji
Ministry of Regional
DevelopmentOffice of the
Commissioner Eastern
61 Carnavon St.
Suva, Fiji
Trade and Productivity
Authority of Fiji (TPAF)
Lot 1 Beaumont Rd
Narere
PO Box 6890
Nasinu, Fiji
Contact
Tel. [679]448 6006
Fax. [679] 448 6301
Tel. [679] 321 4600
Fax. [679] 321 4497
Tel. [679] 666 2655
FAX. [679] 666 4685
Tel. [679] 330 4633
Tel. [679] 330 7011
Tel. [679] 338 4111
Email:
[email protected]
Tel. [679] 331-8299
Fax. [679] 331 8290
Tel. [679] 339 2000 ext 289
Area Manager (North)
Shell Oil, Fiji
Rona Street
Walu Bay
PO Box 168
Suva, Fiji
Tel.[679] 322 9209
Mr. Waqa Lepolo
Transport Pool
Mechanical Section
Walu Bay
Suva, Fiji
Tel. [679] 330 2211
Mr. Jeff Lieu
Sustainable
Livelihoods
Programme, UNDP
YWCA building, 2nd
level, Sukuna Park
Suva, Fiji
Tel. 331 2250
Mr. Railala Ligabalavu
Legal Officer
Mr. Mataiasi Lomaloma
Deputy Secretary
Mr. Daniel Lal
Ministry of Health
PO Box 2223
Suva, Fiji
Ministry of Fijian Affairs
PO Box 2100
Suva, Fiji
Tel. [679] 322 1445
Tel. [679] 331 3400
Appendix 12 - 8
Name
Mr. Moses Lum
Position
FIJI (Continued)
Address
Senior Electrical
Engineer
Mr. Asala Makabuna
Coconut Development
Officer
Gagaj Ljimo Managreve
Chairman
Dr. Safu Manueli
Superintendent/Medical
Officer
Mr. Carl Mar
Manager, Property
Investments
Mr. Josiah Mar
Chairman of the Board
Mr. Robert Mario
General Manager
Mr. Rupeni Mario
Energy Adviser
Mr. Josua Mataika
Deputy Director
Mereoni Mataika
Project Technician –
Coral Gardens
Initiative Project
Mr. Anare Matakiviti
PIEPSAP Energy
Adviser
Ratu Suliano Matanitobua
Assistant Minister For
Fijian Affairs
Mr. Nemani Mati
Chief Asst Sec
(Economic Services)
Mechanical Section
Walu Bay
Suva, Fiji
Coconut Industry
(CIDA)
1st. Floor
Garden City
Raiwai, Suva
Rotuma Island Council
Rotuma, Fiji
Rotuma Hospital
Rotuma, Fiji
Fiji National Provident
Fund (FNPF)
Bldg. 2 Level 3
Provident Plaza
Suva, Fiji
2 Marlow St.
Suva, Fiji
Sisters AirCool, Fiji
Lot 5 Bulei Rd
Laucala Beach Estates
Suva, Fiji
SOPACMead RoadSuva,
Fiji
Fiji Institute of
Technology
Ratu Mara Road
Samabula, Fiji
Partners In Community
Development Fiji (PCDF)
8 Dennison Road
Suva, FIJI
PIEPSAP-SOPAC
Mead Road
Nabua
Private Mail Bag
Suva, Fiji
Ministry for Fijian Affairs
PO Box 2100
Suva, Fiji
Prime Minister's Office
Box 2353
Suva, Fiji
Contact
Tel. [679] 330 2211
Tel. [679] 330 0503
Email:
[email protected]
N/A
N/A
Tel. [679] 330 7811
Tel. [679] 331-1133
Tel. [679] 339 6935
Fax. [679] 334 0895
Tel. [679] 338 1377Email:
[email protected]
Tel. [679] 338 1044
Tel. [679] 330 0392
Fax. [679] 3304315
Tel. [679] 338 1377
Fax. [679] 337 0040
Tel. [679] 331 5969
Fax. [679] 3312 530
Tel. [679] 321 1454
Fax. [679] 331 5751
Appendix 12 - 9
Name
Position
FIJI (Continued)
Address
Mr. Ross McDonald
Managing Director
Credit Corporation
(Fiji) Ltd & Chair, Fiji
Sugar Corporation
Mr. Ross McDonald
Chairman
Mr. Andrew McGregor
Team Economist
Mr. Jitendra Mehta
Managing Director
Mr. Joe Montu
Technical Officer
Mr. Jared Morris
Import Management
Advisor
Mr. Jared Morris
Petroleum Import
Management Adviser
Mr. Rokoseru Nabalarua
CEO
Ms. Sainimile Nabou
Manager, Planning
Mr. A. Naidu
Deputy CEO
Ms. Vandana Naidu
Senior Environmental
Officer
Mr. Paceli Nakavulevu
Rural Electrification
Unit
Ms. Sala Nakeke
Human Resources
Development
Ms. Ane Naulivou
Executive Secretary
Credit House
Gordon Street
GPO Box 14070
Suva, Fiji
Fiji Sugar Corporation Ltd
3rd floor, Western House
Lautoka, Fiji
ADB Rural and Outer
Islands Project (TA 4589FJ)
Poly Products, Ltd.
P.O Box 5171, Raiwaqa
Suva, Fiji Islands
Mechanical Section
Walu Bay
Suva, Fiji
Pacific Islands Forum
Secretariat
Private Mail Bag
Suva, Fiji
Pacific Islands Forum
Secretariat
Ratu Sukuna Road
Suva, FIJI
2 Marlow St.
Suva, Fiji
Valelevu, Nasinu
PO Box 6677
Nasinu, Fiji
Office of the Prime
MinisterBox 2353Suva,
Fiji
Department of
Environment
PO Box 2131
Suva, Fiji
Private Bag
79 Ratu Mara Road
Samabula, Fiji
Fiji Broadcasting Ltd.
69 Gladstone Road
PO Box 334
Suva, Fiji
Prices and Incomes Board
(PIB)
PO Box 1312
Suva, Fiji
Contact
Tel. [679] 330 5744
Fax: [679] 330 5747
Email:
[email protected]
Tel. [679] 666 2655
Tel. [679] 3385 544
Fax. [679] 3370 052
Tel. [679] 330 2211
Ph. [679] 331 2600
Tel. [679] 331-2600
Tel. [679] 332 4301
Fax. [679] 321 1882
Tel. [679] 339 2166
Fax. [679] 339 5474
Tel. [679] 321 1201
Tel. [679] 331 1699
Fax. [679] 331 2879
Tel. [679] 338 6006
Tel. [679] 331 433
Fax. [679] 330-4518
Tel. [679] 330 9266
Appendix 12 - 10
Name
Position
FIJI (Continued)
Address
Contact
Instructor
Technology and
Development
Nadave
Private Bag
Nausori, Fiji
Tel. [679] 347 7699
Fax. [679] 347 9776
Executive Director
Private Bag
Naibati House
Goodenough St.
Suva, Fiji
Tel. [679] 330 6022
Fax. [679] 330 2038
Fiji Manager
Ian MaCallan Engineering
Consultants
340 Waimanu Road
Suva, Fiji
Tel. [679] 331 3388
Fax. [679] 330 2903
Director
Irwin Alsop Consulting
Engineers
19 Domain Road
Suva, Fiji
Tel. [679] 330 2619
Adviser, Infrastructure
and Energy
European Commission
4th Floor Development
Bank Centre, Suva
Suva, Fiji
Phone: [679] 331 3633
Fax. [679] 330 0370
Mr. Xavier Pinsolle
Attaché
European Commission
4th Floor Development
Bank Centre, Suva
Suva, Fiji
Phone: [679] 331 3633
Fax. [679] 330 0370
Mr. Robert Pole
Fiji Institute of
Engineers
Ian MaCallan Engineering
Consultants
340 Waimanu Road
Suva, Fiji
Tel. [679] 331 3388
Mr. Amit Prakash
Building Services
Manager
Sinclair Knight Merz
Engineering
Waimanu Road
Suva, Fiji
Tel. [679] 331 5770
Mr. Krishna Prasad
Acting Chief Economic
Planning Officer
(Sectoral/Regional)
PlanningRo Lalabalavu
HouseVictoria Parade, PO
Box 2212Government
BuildingsSuva, Fiji
Tel. [679] 331-3411
Officer
Prime Minister's Office
PO Box 2353
Suva, Fiji
Tel. [679] 321 1699
Fax. [678] 331 5751
Mr. Inosi Navoto
Mr. Tony Neil
Mr. Robin Palmer
Mr George Peterson
Mr. Horst Pilger
Mr. Rakesh Prasad
Appendix 12 - 11
Name
Position
FIJI (Continued)
Address
Ratu Mara Road
Samabula
GPO Box 2493
Suva, Fiji
Office of the Prime
Minister, Government
Buildings, Suva
Planning
Ro Lalabalavu House
Victoria Parade, PO Box
2212
Suva, Fiji
Ms. Susana Pulini
Scientific Officer
Hon. Laisenia Qarase
Prime Minister of Fiji
Mr. Mosese Qasenivalu
Senior Economic
Planning Officer
(Sectoral/Regional)
Ms. Rachel
Three Sisters Fuel
Distribution
Rotuma, Fiji
Mr. Krishn Raj
Managing Director
RES, Ltd.
PO Box 5045
Labasa, Fiji
Mr. Luke Ratuvuki
Ms. Asenaca Ravuvu
Development Services
Unit Team Leader
Mr. Raj Reddy
Operations
Hon. Ms. Marieta
Rigamoto, MP (Rotuma)
Minister of
Communications and
Media Relations
Mr. Ken Roberts
Chairman of the Board
Ministry of Agriculture,
Sugar & Land
Resettlement
Private Mail Bag
Raiwaqa, Fiji
UNDP Fiji
Tower Level 6
Reserve Bank Bldg.
Pratt Street
Suva, Fiji
2 Marlow St.
Suva, Fiji
Ministry of
Communications and
Media Relations
PO Box 2225
Suva, Fiji
Coconut Industry
(CIDA)
1st Floor Gunu House
25 Gladstone Rd
Suva, Fiji
Contact
Tel. [679] 338 6006
Fax. [679] 338 6301
Tel. [679] 321 1201
Tel. 331-3411
Tel. [679] 881 2618
Fax. [679] 881 5018
Mobile: [679] 996 2032
Tel. [679] 331 2500
Fax. [679] 330-1718
Tel. [679] 322 4113
Phone: [679]321-1700
Tel. [679] 330 0503
Mr. Ken A. J. Roberts
Chief Executive
Fiji Employers' Federation
PO Box 75
Suva, Fiji
Tel. [679] 331 3188
Fax. [679] 330 2183
Dr Jimmy Rodgers
Senior Deputy Director
General
Secretariat for the Pacific
Community (SPC)Private
mail bagSuva, Fiji
Tel. [679] 337 0733 Ext 308
Fax. (679) 337 0021
Appendix 12 - 12
Name
Position
Mr. Samuela Rokocakau
Head of Electrical
Engineering
Mr. Jope Rokotuibau
Training / Workshop
Manager
Mr Maurice Ruggiero
Managing Director
Mr. Tony Sansom
Managing Director
Ms. Makereta Saturaga
Acting Director
FIJI (Continued)
Address
Fiji Institute of
Technology (FIT)
PO Box 3722
Samabula, Fiji
Technology and
Development (CATD)
Private Bag
Nausori, Fiji
Tritech Consulting
152 Ragg Ave.
Suva, Fiji
Sansom Design
Architecture
17 Naimawi St
Lami, Fiji
79 Ratu Mara Road
Private Bag
Samabula, Fiji
(DOE)
Ratu Mara Road
Samabula
GPO Box 2493
Suva, Fiji
ADB South Pacific
Subregional Office
Level 5, Ra Marama
Building
91 Gordon St.
Suva, Fiji
Department of
Environment
PO Box 2131
Suva, FIJI
Valelevu, Nasinu
PO Box 6677
Nasinu, Fiji
Contact
Tel. [679] 338 1044
Tel.[679] 347 7699
Tel. [679] 332 3503
Tel. [679] 359 0025
Mobile: [679] 992 2120
Tel. [679]338 6006
Tel. [679] 338 6006
Fax. [679] 338 6301
Email:
[email protected]
Ms. Makareta Sauturaga
Acting Director
Ms. Tina Seniloli
Assist Project Analyst
Mr. Isoda Shinichi
JICA Expert (EIA)
Mr. Abraham Simpson
CEO
Ms. Suilana Siwatibau
Community
Development Adviser
Rakesh Solanki
Engineer
Mr. Ron Steenbergen
General Manager,
Major Projects and
Strategy
2 Marlow St.
Suva, Fiji
Tel. [679] 322 3484
Mr. Eremasi Tamanisau
Senior Lecturer,
Electronics
Fiji Institute of
Technology
Ratu Mara Road
Samabula, Fiji
Tel. [679] 338 1044
7 Naulauvatu Road
Samabula
PO Box 5074
Samabula, Fiji
FEA
2 Marlow St.
Suva, Fiji
Tel. [679] 331 8101
Fax. [679] 923 2947
Tel. [679] 333 1169
Tel. [679] 339 2166
Fax. [679] 339 5474
Tel.[679] 338 4074
Tel. [679] 999 2412
Appendix 12 - 13
Name
Position
FIJI (Continued)
Address
Cultural Adviser
Rotuma Island Council
Rotuma, Fiji
Mr. John Teaiwa
CEO
Coconut Industry
Development
Authority1st. FloorGarden
CityRaiwaiSuva, Fiji
Mr. Fakmanoa Tigarea
Technical Officer
Mr. Ravuni Uluilakeba
General Manager
Marketing / Innovation
Mr. Max Underhill
Director
Gagaj Taimanau Taukave
Mr. Jone Usamate
Director General
Mr. William Valentine
Copra Purchasing
Officer
Mr. Peni Valevale
Director
Department of Agriculture
Rotuma, Fiji
2 Marlow St.
Suva
Maxumise Ltd
Level 4, FNPF Place
343 Victoria Parade
PO Box 12499
Suva, Fiji
TPAF
Lot 1 Beaumont Rd
Narere
PO Box 6890
Nasinu, Fiji
Punja & Sons
Laucala Beach Estates
Nasinu, Fiji
Solar & Alternative
Energy Supplies
Lot 9, Kalabo Industrial
Estate
Nasinu, Fiji
Ms. 'Emeline Veikoso
Project Energy Officer
SOPAC
Mead Road
Nabua
Private Mail Bag
Suva, Fiji
Ms. Ruth Verevukivuki
Programme Portfolio
Manager
UNDP
Reserve Bank Building
Private Bag
Suva, Fiji
Mr. Jovesa Vocea
District Officer,
Rotuma
Rotuma, Fiji
Mr. Anasa Vocea
CEO
Mr. Josefa Vosanibola
Manager, Traffic
Management Services
Ministry of Works &
Samabula, Suva
Valelevu, Nasinu
PO Box 6677
Nasinu, Fiji
Contact
Tel. [679] 330 0503Email:
[email protected]
Tel. [679] 322 4101
Tel. [679] 330 3137
Fax. [679] 330 5510
Tel. [679] 339 2000
Fax. [679] 224 0184
Tel. [679] 327 5030
Email:
[email protected]
Tel. [679] 339 8006
Tel. [679] 338 1377
Fax. [679] 337 0040
Email: '[email protected]
Tel. [679] 331 2500
Fax. [679] 330 1718
Tel. [679] 338 4111
Tel. [679] 339 2166
Fax. [679] 339 8925
Appendix 12 - 14
Name
Position
FIJI (Continued)
Address
National Biofuel
Development Committee,
Fiji
PO Box 2454
Suva
Fiji Chamber of
Commerce & Industry
178 Lakeba St.
Samabula, Fiji
Environment Fiji Ltd.
259 Prince's Road
Tamavua, Fiji
Contact
Mr. Charles Walker
Chairman and
consultant to the Office
of the Prime Minister
Mr. Taito Waradi
President
Dr. Dick Watling
Managing Director
Mr. Christopher J.
Wensley
Senior Project
Implementation
Specialist
ADB Pacific Subregional
OfficeLevel 5, Ra
Marama Building91
Gordon St.Private Mail
Bag-SPSOSuva, Fiji
Tel. [679] 331-8101Fax. [679] 3318074Email: [email protected]
Treasurer, CEO
Fiji Manufacturer's
Association
49 Gladstone Rd.
Box 2308
Suva, Fiji
Tel. [679] 331 8811
Mr. Desmond Whiteside
Mr. Pita Wise
Chief Planning Officer
Mr. Gary Wiiseman
Team Leader
Mr Warren Yee
Partner / Managing
Director
Mr. Gerhard Zieroth
PIEPSAP Manager
National Planning
Ra Lalabalavu House
Victoria Pde
PO Box 2212
Suva, Fiji
UNDP Pacific
Subregional Centre
2nd Floor, YWCA
Building
Ratu Sukuna Park
Private Mail Bag
Suva, Fiji
Irwin Alsop Consulting
Engineers
19 Domain Road
Suva, Fiji
PIEPSAP-SOPAC
Mead Road
Nabua
Private Mail Bag
Suva, Fiji
Tel. [679] 321 1274
Tel. [679] 999 7899
Tel. [679] 338 3189
Tel. [679] 331-3411
Fax. [679] 330 0834
Tel. [679] 330 0399
Fax. [679] 330 1976
Tel. [679] 330 2619
Tel. [679] 338 1377
Fax. [679] 337 0040
Appendix 12 - 15
SAMOA
Name
Position
Address
Contact
Sam I. A. Aiono
Managing Director
Samatic Co. Samoa Ltd.
PO Box 9386
Apia, Samoa
Tel. [685] 26213
Fax. [685] 25908
Mr. Nonumalo
Akereisalesa
Head of School
(technology)
Samoa Polytechnic
PO Box 861
Apia, Samoa
Tel. [685] 21428
Fax. [685] 25489
Mr. Patila Malua Amosa
Head of Science
Department
Samoa
PO Box 1622National
University of Samoa
Apia, Samoa
Tel (685) 20072 ext 112
Fax. (685) 20938/21440
Mr. Mulipola Ausetatio
Assistant CEO,
Meteorology Division
Apia Observatory
POBox 3020
Apia, Samoa
Mr. Steve Baker
General Manager
Westpac Bank Samoa
PO Box 1860
Apia, Samoa
Manager, Research &
Statistics
Central Bank of
SamoaCentral Bank
BuildingBeach
RoadPrivate BagApia,
Samoa
Mr. Iosefo Bourne
Mr. Marc Burns
Manager
Mr. Atanoa Crichton
Television operations
Mr. Iosefatu Eti
section
Mr. Solomone Fifita
Chief Technical
Adviser
Mr. Frank Fong
Forestry Officer
Mr. Junji Ishizuka
Resident
Representative
ANZ Bank (Samoa) Ltd.
Main Office
Matafele
Apia, Samoa
Samoa Broadcasting
Corporation
PO Box 1868
Apia, Samoa
Apia Observatory
POBox 3020
Apia, Samoa
Pacific Islands Renewable
Energy Project
SPREP
PO Box 240
Apia, Samoa
Forests, Fisheries and
Meteorology
Private Bag
Apia, Samoa
JICA
PO Box 1625
Apia, Samoa
Tel. [685] 21711/2/3/4
Email:
[email protected]
Tel. [685] 20000
Fax. [685] 22848
Email:
[email protected]
Tel. [685] 34100Fax. [685]
Tel. [685] 22422
Fax. [685] 24595
Tel. [685] 22641
Fax. [685] 24789
Tel. [85] 21711/2/3/4
Email:
[email protected]
Tel. [685] 21929
Fax. [685] 20231
Tel. [685] 22561
Tel. [685] 22572
Fax..[685] 22194Email:
[email protected]
Appendix 12 - 16
SAMOA (Continued)
Name
Position
Address
Contact
Mr. Thomas Jensen
Sustainable Energy
Adviser
UNDP/UNESCO
Private Bag
Apia
Tel. [685] 23670
Fax. [685] 23555
Email. [email protected]
Mr. Marco Kappenberger
President, Rotary Club
PO Box 247
Apia, Samoa
Tel. [685] 42014
Fax. [685] 42055
Energy Coordinator
Economic Policy and
Planning Division
Ministry of Finance
Apia, Samoa
Tel. [685] 34333/34341
Fax. [685]21312/24779
Email: sili'a Kilepoa-Ualesi
Mr. Poloma Komti
Officer
Prime Minister's
Department
Private Mail Bag
Apia
Tel. [685] 63222
Iulai Lavea-Deputy CEOMOF
Deputy CEO-Ministry
of Finance
Ministry of Finance,
Private Mail Bag, Apia
Lusia Sefo Leau-Deputy
CEO-MOF
Deputy CEO-Ministry
of Finance
Ms. Sili'a Kilepoa-Ualesi
Mr. Sami Lemalu
Assistant CEO-Forestry
Mr. Perive Tanuvasa Lene
CEO Samoa
Polytechnic
Mr. Andrew Ah Liki
Managing Director
Mr. Fuimaono Falefa Lima
General Manager
Angus MacDonald
Graduate Engineer
Alexanda (Lecki)
MacDonald
Managing Director
Fiu Mata'ese Elisara-Laulu
Executive
Director/President of
Sungo
Forestry, Fisheries and
Meteorology
Private Bag
Apia, Samoa
Samoa Polytechnic
PO Box 861
Apia, Samoa
Bluebird Lumber
PO Box 1612
Apia, Samoa
Development Bank of
Samoa
Private Bag
Apia
PO Box 576
Macdonald’s Building
Apia
MacDonald Distributors
MacDonald Building
Savalalo
Apia, Samoa
O Le Siosiomaga Society,
Inc.
PO Box 2282
2nd floor Welsley Arcade,
Matalele
Apia, Samoa
Tel. [685] 34333/34344
Fax. [685] 21312/24779
Tel. [685] 34333/34336
Fax. [685] 21312/24779
Tel. [685] 22561
Fax. [685] 29707
Tel. [685] 21428
Fax. [685] 25489
Tel. [685] 76777
Fax. [685] 20643
Tel. [685] 22861
Fax. [685] 23888
Tel. [685] 22022
Fax. [685] 23754
Tel. [685] 20957
Fax. [685] 23754
Tel. 25697
Fax..21993
Appendix 12 - 17
SAMOA (Continued)
Name
Position
Address
Contact
Mr. Mauiliu Magele
Mauiliu
Vice Chancellor &
President
Samoa University
Vaivase, Apia
Tel. [685] 21428
Fax. [685] 25489
Paul Meredith - Assistant
CEO - Economic Policy
and Planning Division,
MOF
Assistant CEOMinistry of Finance
Tel. [685] 34333/34324
Fax. [685] 21312/24779
Dr. Jacinta Moreau
Senior Lecturer Chemistry Faculty of
Science
Samoa PO Box 1622
Apia, Samoa
Tel (685) 20072 ext 140
Fax. (685) 20938/21440
Mr. Bola Nacanieli
Petroleum Expert
Mr. Masifanae Ngau-Chun
Head of Hydrology
section
Mr. Ierome Paletasala
Research Officer
Ms. Hinauri Patana
Financial Secretary
Papali'I Grant Percival
President
Tel. [685] 54239
Tel. [685] 21711/2/3/4
Email:
[email protected]
Tel. [685] 34325
Fax. [685] 21312
Email:
[email protected]
Tel. [685] 34309
Fax. [685] 21312
Tel. [685] 24177
Fax. [685] 23380
Mr. Afoa Ray Pereira
Head of Customs
Private
Apia Observatory
POBox 3020
Apia, Samoa
Ministry of Finance
Central Bank Building
Private Bag
Apia, Samoa
Treasury Department
Apia
Samoa Association of
Manufacturers and
Exporters
Ministry of Revenue
(Customs and Tax)
PO Box 44
Apia, Samoa
Hinauri Petana (CEOMOF)
CEO-Ministry of
Finance
National Bank of Samoa,
Ltd.
Beach Road, Matafele
Apia
Don Bosco Technical
School
Apia, Samoa
Tel. [685] 21561
Fax. [685] 23209
Tel. [685] 34333/34332
Fax. [685] 21312/24779
Tel. [685] 23077
Fax. [685] 23085
Email:
[email protected]
Mr. Bruce Philips
Manager
Mr. Timo Pio
Plumbing Instructor
Leiataua Isikuki Punivalu
Managing Director
Isikuki Punivalu
Associates, Ltd.PO Box
3686Apia, Samoa
Tel. [685]20842
Fax..[685]20843
Mr. Aukusitino Rasch
Manager Research &
Development
Development Bank of
Samoa
Private Bag
Apia, Samoa
Tel. [685] 22861
Fax. [685] 23888
Talalelei Tevita Ripley
Samoa consultant for
PREGA
Private
Mr. James A. (Jim)
Robinson
Registered Engineer
PO Box 6578
Apia, Samoa
Tel. [679[ 24637,
Fax. [679] 21768
Tel. [685] 32307
Fax. [685] 24179
Tel. [685] 21634
Fax. [685] 21701
Appendix 12 - 18
SAMOA (Continued)
Name
Position
Mr. Stephen Rogers
Head of Office
Mr. Nonumalo A. Salesa
Head of School
Papali'I Tom Scanlan
General Manager
Foniova Sealiitu Sesega
General Manager
Mr. Mau Simanu
Head, Electrical
Division
Ms. Margaret Soon
Officer
Mr. Eric Stanley
Private
Tu'u'u Luafatasaga Dr.
Ietitaia Setu Taule'alo
CEO
Mr. Namulauulu Tavita
Head of Plumbing
Technology
Mr. Greg Taylor
Managing Director
Mr. Ieti Tifaga
Project Manager
Mr. Thomas Tinai
Partner
Mr. Taule'a'e'ausumai
Aumalaga Tiotio
Engineering Manager
Fr. Mosese Vitolio Tui
Principal
Mr. Epa Tuioti
co-managing director
Address
Delegation of the
European Commission for
the Pacific Office in
Samoa
PO Box 3023
Apia, Samoa
Samoa Polytechnic
Institute
PO Box 861
Apia, Samoa
Central Bank of Samoa
Private Bag
Apia, Samoa
Samoa Trust Estates
Corporation (STEC)
PO Box 1849
Apia. Samoa
Samoa University
Apia, Samoa
Taylor Electrical Ltd.
Apia, Samoa
PO Box 510
Apia, Samoa
Ministry of Natural
Resources and
Environment
Beach Road
Private Bag
Apia, Samoa
Samoa Polytechnic
Institute
Private Bag
Apia, Samoa
Taylor Electrical Ltd.
Apia, Samoa
ESP-Ministry of
Education
Private Bag
Apia, Samoa
Tinai, Gordon and
Associates
Architects and Engineers
Apia, Samoa
EPC
P.O. Box 2011
Apia, Samoa
Don Bosco Technical
School
Apia, Samoa
KVA Consult, Ltd.PO
Box 1882
Apia, Samoa
Contact
Tel. [685] 20070
Fax. [685] 24682
Tel. [685] 21428
Fax. [685] 25489
Tel. [685] 34100
Fax. [685] 23149
Tel [685] 22077 / 21515
Fax. [685] 21947
Tel. [685] 21299
Tel. [685] 30963
Fax. [685] 23176
Tek. [679] 21428
Fax. [679] 25489
Tel. [685] 21299
Tel. [685] 28085
Fax. [685] 28082
[email protected]
Tel. [685] 22906
Fax. [685] 22913
Tel. [685] 22261
Fax. [685] 23748
Tel. [685] 24637
Fax. [685] 21768
Tel. [685] 25345/21207
Fax. [685] 22087
Appendix 12 - 19
SAMOA (Continued)
Name
Position
Siueva Vaaelua
Accountant
Dr. Nigel Walmsley
Water Resources
Specialist
Muaausa Joseph Walter
General Manager
John Worall
Managing Director
Ms. Violet Wulf
Principal Climate
Change Officer
Mr. Seti Ah Young
Director
Address
Ministry of Works,
Transport & Infrastructure
Private Bag
Apia, Samoa
Technical Assistant to the
National Authorising
Officer
Top Floor, ABM (Peter
Ah Him's) Bldg.
P.O. Box 1289
Apia, Samoa
EPC
P.O. Box 2011
Apia. Samoa
John Worrall Pty., Ltd.
PO Box 2068
Apia (Vaoala Village),
Samoa
Ministry of Natural
Resources & Environment
Beach Road
Private Bag
Apia, Samoa
Alternative Energy (NZ)
Ltd.
Apia, Samoa
Contact
Tel. [685]21611
Fax. [685] 23504
Tel. [685] 26659
Fax. [685] 26659
Tel. [685] 22261
Fax. [685] 23748
Tel. [685] 22520
Fax. [685]-20659
Tel. [685]23701/02
Fax. [685] 25856
[email protected]
Tel. [685] 21091
OTHER COUNTRIES
Name
Position
Engr. Robert C. Ables
Biodiesel Program
Officer
Dr. Peter Adams
Executive Director
Mr. Terubentau Akura
General Manager
Mr. Heinz Böhnke
Director
Address
Philippine Coconut
Authority
Product Development
Department
5/F R&D Bldg.
Elliptical Road
Quezon City 1101
Philippines
NZAid
New Zealand Int'l Aid &
Development
Private Bag
18901 Wellington, New
Zealand
Solar Energy Company
PO Box 493
Betio
Tarawa, Kiribati
Technosol
Yachthafenstraße 17
D-21635 Jork, Germany
Contact
Tel. [632] 928 1085
Fax. [632] 426 7726
Tel. [64] 439 8027
Tel. [686] 2058
Fax. [686] 26210
Tel. [49 4[162 942 707
Fax. [49 4[162 942 708
Mobile: [494] 179- 22 68 693
Appendix 12 - 20
OTHER COUNTRIES (Continued)
Name
Position
Mr. Jason Chau
Sales Representative
Mr. Roger Collier
Team Leader
Mr. Patrice Courty
Senior Consultant Rural Energy
Development
Mr. Felix Gooneratne
Director
Dr. Hubert Hildebrand
Senior Manager
Civil & Hydraulics
Mr. Jean-Paul Huraut
Technical Director
Mr. Steve Kromer
Efficiency Valuation
Organizartion
Ms. Perla Manipol
President
Address
Method Machine
MalaysiaLtd.Suite 26.3,
Level 26Menara IMCNo
8, Jalan Sultan
Ismail50250 Kuala
Lumpur, Malaysia
ADB Rural and Outer
Islands Project (TA 4589FJ)
183, Ave de Montpelier
34 270 Claret, France
International Institute for
Energy Conservation
Asia Regional Office
UBC II Bldg. Suite 1208
591 Sukhumvit Rd
Bangkok, Thailand
FICHTNER GmbH
PO Box 101454
70013 Stuttgart
Germany
Contact
Tel. [603]-2039 04763Fax. [603]2031-8359
Web: coconutmachine.com
Tel. [33] 467 559 645
Tel. [66 2] 662 3460-5
Fax. [66 2] 261 8615
Email: Email: [email protected]
Tel. [49] 711 8995 311
Fax. [49] 711 8995 459
SOGREAH
BP 172 Grenoble
Cedex 9 France
Tel [33] 4 76 33 41 08
Fax. [33] 4 76 33 40 94
USA
Tel. [510] 288 0285
Mobile. [510] 847 8535
Email:
[email protected]
Sustainable Rural
Enterprise
Aklan State University
Banga, Aklan
Philippines
Economic and Energy
Analysis Pty. Ltd
Suite 49 Level 3
330 Wattle St.
Ultimo NSW 2007
Australia
Lavin Centrifuge
AML Industries, Inc. USA
3500 Davisville Rd.
Hatboro, PA, USA
Tel. [66] 36-256-6811
Fax. [66] 36-268-4765
Tel. [612] 9280 0515
Fax. [612] 9280 0844
Email:
[email protected]
Warwick Richards
.Managing Director
Mr. Robert Rocha
International Sales
Mr. 'Ofa Sefana
Ha'apai PV Project
Manager
Energy Planning Unit
Pangai
Ha'apai, Tonga
Tel. [676] 60510
Fax. [676] 60200
Mr. Manuel Soriano
Regional Coordinator Climate Change
UNDP / GEF Regional
Service Unit
Bangkok, Thailand
Tel. [66 2] 288 3032
Tel. [1-215] 674-2424
Fax.. [1-215] 674-3252
Appendix 12 - 21
OTHER COUNTRIES (Continued)
Name
Position
Mr. Jérôme Sudres
Directeur
Mr. Gilles Vaitilingom
Biofuels and Biomass
Energy
Dr. Jerome Weingart
Proprietor
Address
Vergnet Pacific
24 rue de l’Alma
98800 Noumea
New Caledonia
Centre for Research in
Agriculture for
International Development
(CIRAD)
Forestry Department
TA 10/16.
73, rue J.F.Breton
34398 Montpellier
Cedex 5, France
Consultancy Services for
Sustainable Development
4001 North 9th St.
Suite 1108
Arlington, VA, 22203
USA
Contact
Tel. [687] 283 283
Fax. [687] 283 283
Tel. [334] 67 61 57 62
Fax. [334] 67 61 65 15
Tel. [1-703]524 8372
Appendix 13 - 1
APPENDIX 13
TERMS OF REFERENCE FOR THE RENEWABLE ENERGY AND ENERGY
EFFICIENCY PROGRAM
Appendix 13 - 2
ASIAN DEVELOPMENT BANK
TAR: OTH 36259
TECHNICAL ASSISTANCE
(Financed by the Danish Cooperation Fund for Renewable Energy and
Energy Efficiency in Rural Areas)
FOR THE
RENEWABLE ENERGY AND ENERGY EFFICIENCY PROGRAM
FOR THE PACIFIC
April 2003
Appendix 13 - 3
ABBREVIATIONS
ADB
CDM
GEF
ITE
NTE
PDMC
PEPP
PICCAP
PIREP
PREFACE
–
–
–
–
–
–
–
–
–
–
PREGA
–
TA
TOR
–
–
Asian Development Bank
Clean Development Mechanism
Global Environment Facility
international technical expert
national technical expert
Pacific developing member country
Pacific Energy Policy and Plan
Pacific Islands Climate Change Assistance Program
Pacific Islands Renewable Energy Project
Pacific Rural Renewable Energy France-Australia Common
Endeavour
Promotion of Renewable Energy, Energy Efficiency, and
Greenhouse Gas Abatement Projects
technical assistance
terms of reference
NOTE
In this report, "$" refers to US dollars.
This report was prepared by D. Ponzi.
Appendix 13 - 4
I.
INTRODUCTION
1.
The Pacific islands region has a high degree of ecosystem and species diversity and is
very vulnerable to a wide range of natural and environmental disasters. The region also has a
high degree of economic and cultural dependence on the natural environment with an
extraordinary diversity of cultures and languages, traditional practices, and customs centered on
the marine and coastal environment. The Pacific islands, except for Papua New Guinea, are
among the world’s smallest and most remote states, and generally have isolated populations
living in very low concentrations.
2.
Only a few Pacific island communities have access to modern energy sources, and
those with access rely heavily on imported fossil fuels. An estimated 70% of the people in
Pacific developing member countries (PDMCs) have no access to electricity.1 For those with
access to electricity and transportation, imported petroleum products account for approximately
80% of primary commercial energy consumption. Half the imported petroleum products are
consumed by the transport sector and 40% is used in diesel-fired power generation units.
Renewable energy, mostly mini-hydro, contributes less than 10% of commercial energy use.
3.
A fact-finding mission to Fiji Islands and Samoa was undertaken in May 2002. The
mission met with senior government officials, representatives of bilateral and multilateral
agencies, and senior staff of major regional agencies, 2 to discuss the regional technical
assistance for the Renewable Energy and Energy Efficiency Program for the Pacific. 3 The TA
framework is presented in Appendix 1.
II.
ISSUES
4.
Access to modern forms of energy is an essential prerequisite for economic
development and poverty reduction as well as a key determinant of the quality of life and the
level of social development. While few data are available on the welfare impacts of different
kinds of interventions in the energy sector, development practitioners agree on the links
between energy and poverty reduction. The priority for the poor is the satisfaction of their basic
human needs, such as food; employment; and access to health, education, housing, water, and
sanitation. To meet these needs, access to modern, reliable, and affordable forms of energy is
crucial. Therefore, one of the main challenges for a developing country is to increase energy
availability in a cost-effective way.
5.
The cost of providing energy is very high because consumers are dispersed and
domestic markets are small. Despite the high cost, however, consumption of energy is
expected to increase as PDMCs develop and modernize. In some of the less developed
countries, such as Kiribati, Papua New Guinea, Solomon Islands, Timor-Leste, Tuvalu and
Vanuatu, it is imperative, in order to improve access to basic services, to increase availability of
modern energy supply. The outer island communities are the most disadvantaged because of
their remote and isolated locations. The cost of conventional energy in these countries is 3-4
times that in PDMC capital cities, and is higher than in neighboring industrialized countries such
as Australia and New Zealand. Because the level of energy consumption depends on the
1
2
3
th
Forum Secretariat. 2001. Communiqué of the 30 Pacific Islands Forum, Nauru. ForSec: Suva, Fiji Islands.
Regional bodies consulted include South Pacific Regional Environment Programme (SPREP), South Pacific Applied
Geosciences Commission (SOPAC), Secretariat of the Pacific Community (SPC), Forum Secretariat, University of
the South Pacific (USP), World Meteorological Organization (WMO).
The TA is included in the 2003 regional TA program and the TA first appeared in ADB Business Opportunities
(Internet edition) on 13 June 2002.
Appendix 13 - 5
available energy services and their affordability, energy supply costs are critical for poverty
alleviation.
6.
In almost all PDMCs, renewable energy sources in the form of hydropower, wind, solar,
biofuel, geothermal, ocean thermal, and wave/tidal energy hold high potential for contributing to
sustainable development. This is particularly true in the remote rural areas, as renewable
energy will reduce the dependence on fossil fuel for power generation and transportation.
Greater use of renewable energy use, coupled with improved energy efficiency, offer PDMCs a
major avenue toward meeting their energy requirements. In addition, as most of the islands are
well endowed with a good renewable resource base, renewable energy technologies are
potentially highly competitive with conventional energy, especially when environmental
externalities are factored into the analysis.
7.
Through the past 3 decades, many funding agencies have provided substantial technical
and financial support to renewable energy and energy efficiency projects in the Pacific region,
but in a rather fragmented and discontinuous way. Most initiatives were implemented as topdown, supply-driven demonstration/pilot projects, with the environmental benefits usually
representing the main, and often the only, justification. While the establishment of appropriate
institutional arrangements as well as a suitable enabling policy and private sector environment
was identified as an important priority area, most of the projects had poorly designed nonpriority project components. Additional reasons for project failures are (i) unrealistic and often
too ambitious project goals and objectives; (ii) immediate objectives and outputs too far-fetched
and generalized; (iii) project activities and objectives often incompatible with existing policies,
socioeconomic structures, and sociocultural traditions; (iv) lack of appreciation of local
capacities and opportunities, as well as proper analysis of constraints and limiting factors with
respect to the local private sector, household level participation, and local public and private
institutions; (v) grant-funded supply of project equipment with resulting low sense of ownership;
and (vi) insufficient support to improve policy frameworks at the country level.
8.
The many remaining issues include: (i) insufficient understanding and awareness of the
potentials of renewable energy and energy efficiency resources; (ii) inadequate institutional
capacities and technical expertise to plan, manage, and maintain renewable energy and energy
efficiency programs; (iii) the absence of a clear market-based policy, legislation, and regulatory
framework; (iv) a lack of confidence in renewable energy and energy efficiency technologies by
the main stakeholders due to the very limited success of technology demonstration programs;
(v) limited policy commitment and financial support to the sector; and (vi) over-reliance on
external aid-funded projects.
9.
The main programs currently under implementation incorporate some of the lessons
learned from past projects. Among these are two recent initiatives, the Pacific energy policy and
plan (PEPP) developed by the Committee of Regional Organizations of the Pacific (CROP)4 and
the Pacific Islands Renewable Energy Project (PIREP) supported by the United Nations
Development Programme (UNDP) and Global Environmental Facility (GEF). PIREP5 builds on
work undertaken under the Pacific Island Climate Change Assistance Program (PICCAP) and
aims at supporting regional and national interventions that remove barriers to renewable energy
development and facilitate promotion, use, and commercialization of renewable technologies
4
5
The CROP Energy Working Group comprises Pacific Islands Forum Secretariat (FORSEC), Pacific Power
Association (PPA), Secretariat of the Pacific Community (SPC), South Pacific Applied Geoscience Commission
(SOPAC) South Pacific Community (SPC), University of the South Pacific (USP) and the United Nations
Development Programme.
PIREP covers 14 countries and has a duration of 18 months with a budget of US$840,000. Implementation started
in August 2002.
Appendix 13 - 6
through the establishment of a suitable enabling environment. The South Pacific Applied
Geoscience Commission (SOPAC) also implements a number of energy and renewable energy
programs in: (i) energy resource assessment (wind, biomass, ocean-based resources, and
geothermal); (ii) energy conservation, efficiency, and demand-side management; and (iii)
energy and environment education through a new postgraduate course in wind energy at the
University of South Pacific (USP). Another ongoing program is the Pacific Rural Renewable
Energy France-Australia Common Endeavour (PREFACE). 6 Its goal is to increase utilization of
Renewable Energy sources, in particular solar photovoltaic and wind energy, through the
development of country-level sustainable financial and management arrangements. Finally,
since 2001, the Asian Development Bank (ADB) with cofinancing from the Government of the
Netherlands, is implementing in the Asia-Pacific region a TA for promoting renewable energy,
energy efficiency, and greenhouse gas abatement projects.7 The TA supports renewable energy
and energy efficiency development through among others, removal of policy and institutional
barriers; preparation of renewable energy and energy efficiency country strategies, programs
and work plans; generation of a pipeline of investment projects for consideration for financing;
and development of financial schemes.
10.
This TA will build on the results of PIREP, PREFACE, the ADB TA (footnote 7), and
other projects in the region by supporting the establishment in two PDMCs of an appropriate
environment for the development of a demand-driven and private-sector-based energy market.
The TA, by focusing on removing barriers and allowing fair competition in only two PDMCs, will
use a systematic, medium-term and in-depth assistance approach, in which the use of
renewable energy and energy efficiency will be a major pillar. In this way, the TA will address
most of the current constraints to development of renewable energy and energy efficiency,
(para. 8) and will support the ultimate goal of significantly increasing PDMCs’ rural community
access to commercially viable energy services.
III.
A.
THE TECHNICAL ASSISTANCE
Purpose and Output
11.
The purpose of the TA is to help create an environment that will enable the development
of a market-based rural energy sector, in which mature renewable energy and energy efficiency
applications play a key and increasing role. This process will involve the development of the
required policy, legal, and institutional framework. The TA will also facilitate mobilization of
external financing by building a pipeline of potential renewable energy and energy efficiency
projects for funding/cofinancing by ADB, GEF, and/or other sources.
12.
The outputs in the two selected PDMCs will include (i) review of, consultations on, and
dissemination of lessons from past renewable energy and energy efficiency assistance in the
Pacific; (ii) an action plan for the adoption of appropriate policies, institutional arrangements,
legal/regulatory measures, and financial schemes including venture capital, as well as private
sector and household-level incentive mechanisms for promoting commercially viable renewable
energy and energy efficiency services; (iii) a training needs analysis and training curricula for
private and public sector key players in the two PDMCs; (iv) a pipeline of projects for funding by
ADB, GEF, and/or other relevant financing sources; and (v) based on outcomes and progress
made in the two selected countries, final consultations and dissemination of lessons learned
6
7
PREFACE, a program implemented by SPC and started in 2000 is jointly funded by France and Australia, and has
a 3-year duration with a budget of A$3 million.
ADB. 2001. Promotion of Renewable Energy, Energy Efficiency, and Greenhouse Gas Abatement Projects
(PREGA). Manila. (Samoa is the only PDMC participating in the PREGA project.)
Appendix 13 - 7
from the TA to other PDMCs with a focus on establishing policy frameworks, building capacity,
and replicating/disseminating good practices.
B.
Methodology and Key Activities
13.
Through the provision of technical support to the national implementing agency and a
high level TA steering committee in each of the two participating PDMCs, the TA will introduce
an effective approach for creating a policy environment enabling a demand-driven private sector
market for rural energy services. In relation to this, the TA will develop local capabilities in the
necessary policy, institutional, and legal/regulatory reforms. To avoid overlapping activities and
replication of past mistakes, the TA will conduct, during inception, a comprehensive stocktaking
of prior and ongoing related to renewable energy and energy efficiency initiatives in the region,
as well as closely coordinate, during the implementation period, with other ongoing programs.
During inception, the TA will establish solid links with existing country-level committees, working
groups, and country teams, such as PICCAP country team, PIREP country teams, etc.
Moreover, to ensure continuity and momentum of progress, the TA will generate a pipeline of
rural energy projects based on renewable energy and energy efficiency, for possible financing
by ADB, GEF, and/or other sources, even before termination of the TA. To ensure full
commitment and TA success, the selected PDMC governments will prepare and issue a
Cabinet-approved development policy letter on renewable energy and energy efficiency before
activities start at the country level. This document will demonstrate the relevant governments’
willingness and commitment to (i) give high priority to the TA and take ownership of its approach
and methodology, (ii) designate a national implementation agency to coordinate TA activities,
(iii) constitute a high-level TA steering committee with representation from all relevant
stakeholders, and (iv) provide counterpart staff and other inputs in kind.
14.
The TA activities are those required to achieve TA outputs as given in paragraph 12,
plus, development of appropriate institutional arrangements, necessary regulatory and legal
framework, and a system of financing schemes targeted at both private sector and household
end-users. Details of key activities are given in Appendix 2.
C.
Cost and Financing
15.
The total cost of the TA is estimated at $750,000. ADB will administer an amount of
$600,000 to be financed on a grant basis from the Danish Cooperation Fund for Renewable
Energy and Energy Efficiency in Rural Areas. The two participating PDMCs will provide
$150,000 equivalent as counterpart financing. Detailed cost estimates and financing
arrangements are presented in Appendix 3.
D.
Implementation Arrangements
16.
The TA will be executed by ADB over an estimated 24-month period, to commence in
June 2003 and be completed by May 2005. ADB’s Pacific Department will be responsible for
overall coordination of TA implementation, and the ADB’s Renewable Energy, Energy Efficiency
and Climate Change (REACH) Committee will provide advisory guidance. A National
implementing agency will implement TA activities in each participating PDMC.
17.
The TA will be implemented in two phases.
18.
The inception phase (4 months) will include: (i) review of past and ongoing initiatives
related to Renewable Energy and Energy Efficiency in the region (PIREP, PREFACE, PREGA,
etc); (ii) development of selection criteria, selection of the two participating PDMCs, and
Appendix 13 - 8
preparation and Cabinet endorsement of a development policy letter on renewable energy and
energy efficiency; (iii) preparation of a pipeline of renewable energy and energy efficiency
projects for funding/cofinancing by ADB/GEF/CDM, and/or other sources, to follow up on the
outcomes of this TA; (iv) in each participating PDMC, support for the identification of the
national implementing agency, the establishment of the TA steering committee, and the
selection of the national technical expert (NTE); and (v) preparation of and agree on detailed TA
implementation plans and work programs. Each PDMC selected to participate in the TA will
have confirmed in writing to ADB that it does not object to its participation in the TA, including to
its participation to the financing of the TA as described in paragraph 15.
19.
The main implementation phase (20 months) will include: (i) implementation of all key
activities listed in paragraph 14 and Appendix 2; (ii) proactive participation in related national
and regional workshops to disseminate information pertinent to renewable energy and energy
efficiency, exchange of good practices and analytical work results, and collaboration on specific
activities; (iii) facilitation of continued financing for renewable energy and energy efficiency
projects after TA completion; and (iv) by the end of TA implementation, dissemination of lessons
learned via a regional workshop and a non technical publication.
20.
TA implementation will be assisted by a team of international (17 person-months) and
domestic consultants (36 person-months), recruited through a consulting firm. The consultants
will include (i) one international technical expert, (the Team Leader) with expertise in renewable
energy and energy efficiency energy policy in small island countries, (ii) two short-term
international technical experts, with expertise in developing financing models and designing and
introducing technical norms and certification schemes, and (iii) two national technical experts
(NTEs), 18 person-months per PDMC (36 person-months total), with experience in rural,
renewable energy and energy efficiency energy projects. The two NTEs will be recruited after
selection of the two participating PDMCs, and subject to ADB’s approval. Staff from the national
implementing agencies will also support TA implementation. In addition, one assistant project
manager (12 person-months), with expertise in energy, environment, and managing and
coordinating ADB TA projects will be recruited by ADB in the Philippines, to assist in overall
project management and implementation. All consultants will be engaged in accordance with
ADB’s Guidelines on the Use of Consultants and other arrangements satisfactory to ADB for the
engagement of domestic consultants. Outline terms of reference for the consultants as well as
reporting requirements are presented in Appendix 4. Given the innovative approach,
methodology, and Terms of Reference, required for effective TA implementation, the consulting
firm will be selected through the full technical proposal and the quality- and cost-based selection
methods.
IV.
THE PRESIDENT'S DECISION
21.
The President, acting under the authority delegated by the Board, has approved ADB
administering technical assistance in an amount not exceeding the equivalent of $600,000 to be
financed on a grant basis by the Danish Cooperation Fund for Renewable Energy and Energy
Efficiency in Rural Areas for the Renewable Energy and Energy Efficiency Program for the
Pacific, and hereby reports this action to the Board.
Appendix 13 - 9
TECHNICAL ASSISTANCE FRAMEWORK
Design Summary
Performance
Indicators/Targets
Goals
By year 2017, i.e. about 10
years after attainment of
Purpose:
1. Rural populations in the
Pacific Developing Member
Countries (PDMCs) have
access to commercially
viable energy services
using mature renewable
energy and energy
efficiency applications.
a. At least 50% of rural
and outer islands
population in two PDMCs
have access to affordable
modern forms of energy.
b. Significantly increased
number and enhanced
productivity of small and
medium enterprises in rural
communities.
c. Increased energy
consumption by rural
population does not
correspondingly increase
PDMC’s dependency on
imported energy.
Purpose
By May 2007, i.e. within 2
years of successful delivery
of all outputs
1. Create an environment
conducive for a demanddriven and private sector
based market for rural
energy services in two
PDMCs with Renewable
Energy and Energy
Efficiency playing a major
role.
(i) Appropriate policies and
strategies, institutional
arrangements, and a
regulatory and legal
framework for creating a
demand driven, private
sector-based market place
for rural energy services
are in place; and
Monitoring
Mechanisms
•
Records on energy
use in rural areas
•
National economic and
private sector
development reports
•
Records of
government’s imports
of energy
•
Asian Development
Bank (ADB) project
post-evaluation report
and Country Strategy
and Program Update
inputs
•
Policy documents from
relevant ministries.
•
Evidence that
appropriate institutions
are formally
established.
•
Evidence that
regulatory and legal
framework models
have been developed
and adopted.
•
Evaluation reports
from training sessions.
•
Asian Development
Bank (ADB) Technical
Assistance (TA)
completion report
•
ADB Review mission
•
Progress in inception
activities.
(ii) sufficient institutional
and organizational capacity
exists at all relevant levels.
Outputs
By end of TA (2005)
1. A comprehensive
stocktaking and lessons
learned review in the
(i) Stocktaking report
completed and included in
the inception report.
Assumptions and
Risks
•
PDMCs are willing to
initiate the necessary
supporting policy and
institutional reform
programs.
•
Political commitment
to allow private sector
to play a major role in
provision of rural
energy services.
•
All major renewable
energy and energy
efficiency stakeholders
Appendix 13 - 10
Design Summary
Performance
Indicators/Targets
renewable energy and
energy efficiency sector.
2. Policy measures
conducive for
commercialization and
privatization of delivery of
rural energy services are
developed. Adoption of
action plan for the
establishment of the
proposed policy framework.
3. Appropriate
institutional arrangements
developed. Adoption of
related action plan.
(ii) A “Renewable Energy
Development Policy Letter”
is issued before end of
inception phase.
(iii) Target PDMC
governments have adopted
an action plan for the
establishment of
appropriate and conducive
policies and strategies.
Monitoring
Mechanisms
•
Quality and coverage
of the inception report.
•
Development policy
commitment letter
•
TA progress reports
and ADB review
mission reports
•
Policy decisions by
target PDMC
governments.
•
Evidence that specific
institutions, agencies,
and associations have
been established.
(iv) Identification of a
national implementation
agency and establishment
of TA steering committee
in each participating
PDMC.
Assumptions and
Risks
and institutional
players share and
learn main lessons
from the stocktaking
exercise.
•
Private sector
perceives the project
as beneficial and
profitable.
•
Clients will pay for
modern energy
services.
•
Cooperation of local
industries
•
Minimal bureaucratic
hindrances and
delays.
•
Sufficient political will.
(v) Appropriate institutional
arrangements are
developed in public and
private sectors.
(vi) Adequate industry
associations are
established.
4. Regulatory and legal
framework prepared and
possibly adopted. An action
plan prepared for adoption.
5. A detailed concept and
modalities for initiation of
appropriate financing
schemes have been
prepared.
(vii) Regulatory and legal
frameworks and related
action plan have been
developed and adopted.
•
Tangible regulatory
and legal framework
models are developed.
(viii) Financing schemes
prepared and agreed
among all key
stakeholders.
•
Concept papers for
financing mechanisms.
•
Training Needs
Analysis, curricula and
training evaluation
reports completed.
(ix) Memorandum of
Understanding on
modalities of financing
mechanisms between
Appendix 13 - 11
Design Summary
Performance
Indicators/Targets
Monitoring
Mechanisms
Assumptions and
Risks
energy efficiency
industries, and local
financial institutions.
6. Training needs
assessment, curricula, and
facilitation of training
conducted.
7. Prepare a pipeline of
projects for energy services
based on renewable
energy and energy
efficiency in the two
targeted PDMCs.
•
Training Needs
Analysis, curricula and
training evaluation
prepared.
(x) Projects outline for at
least two major renewable
energy and energy
efficiency based rural
energy projects in each
target PDMC, including
preparation of concept
papers and Project
Development FinancingBlock B proposals.
8. Dissemination of
lessons learned.
(xi) Proactive participation
in regional workshops and
seminars.
(xii) Workshop session at
end of TA period.
Activities
(Times are indicated as
months from project start
date)
1. Preparation of
stocktaking review.
a. Start: M1 (Inception)
Complete: M3
Responsibility: NIA
2. Policy strategies and
incentives:
a. Prepare and issue
development policy
commitment letter.
b. Start: M5
Complete: M12
Responsibility: NIA/TA
Steering Committee
b. Develop and describe
objectives and modalities
c. Start: M1
Complete: M24
•
Project concept papers
and Project
Development
Financing-Block B
Proposals prepared.
•
Workshop proceedings
and presentations.
•
Continuity of process
toward financing/
cofinancing by ADB/
Global Environment
Facility/Clean
Development
Mechanisms of
pipeline projects.
•
Project management
progress reports.
•
ADB project/TA
postevaluation reports.
•
ADB TA completion
report.
•
ADB review missions.
•
ADB quarterly project
performance reports.
•
TA inception report.
•
TA consultants
progress reports.
•
TA interim report.
•
Close supervision of
ADB staff.
•
Target PDMC
governments give
genuine priority to the
projects rationale; take
ownership over its
approach and
methodology; and
cooperate actively in
its implementation by
allocating the
necessary human,
organizational, and
financial resources.
Appendix 13 - 12
Design Summary
Performance
Indicators/Targets
Monitoring
Mechanisms
of new policy interventions.
Responsibility: TA
•
TA consultants final
report.
c. Direct assistance to the
policy/strategy
development process.
d. Start: M5
Complete: M8
Responsibility: NIA
•
ADB mission reviews.
d. Definition, formation and
initiation of working groups
to substantiate and
implement the various
elements in the overall
national policy/strategy.
e. Start: M8
Complete: M12
Responsibility: TA
To be determined during
inception
e. Ensure conformity of
policy measures with
eligibility criteria’s of
energy efficiency and
climate change funding
mechanisms
(ADB/GEF/CDM and
others).
f. Start: M4
Complete: M6
Responsibility: NIA (TA)
inception
g. Start: M5
Complete: M20
Responsibility: NIC
inception
a. Identify and organize
relevant local industries in
a branch organization.
a. Start: To be determined
(TBD) during inception
Complete: TBD during
inception
Responsibility:
inception
b. Establish or reform
essential public and semipublic institutions to pilot
and provide technical and
financial support to the
emergence and
sustainable operation of a
commercial market for rural
energy services.
b. Start: TBD during
inception
inception
Responsibility: TBD during
inception
inception
a. Develop technical norms
and standards for
equipment and systems.
a. Start: M4
Complete: M6
Responsibility:
inception
b. Develop codes of
practice for installation,
operation, maintenance,
and servicing of equipment.
b. Start: TBD DI
Complete: TBD DI
Responsibility: TBD DI
•
ADB quarterly project
performance reports.
•
•
TA consultants’
progress reports.
Assumptions and
Risks
•
Private sector
industries perceive the
opportunity in the
market and are willing
and have the capacity
to engage.
•
Local financial
institutions perceive
the business aspects
and engage
proactively in the
development of
•
Target PDMC
governments give
genuine priority to the
projects’ rationale,
take ownership over its
approach and
methodology, and
allocating the
necessary human,
organizational and
3. Establishment of an
appropriate institutional
framework:
4. Regulatory framework
establishment:
c. Develop certification
scheme for practitioners,
for individuals (technicians,
engineers, planners, etc)
c. Start: TBD during
inception
Appendix 13 - 13
Design Summary
and for industries
(suppliers).
d. Prepare legal norms for
the institutional linkages
(sales and service
contracts, loan
agreements, etc), in order
to instill confidence
between the various
stakeholders and investors.
Performance
Indicators/Targets
inception
inception
d. Start: TBD during
inception
inception
inception
Monitoring
Mechanisms
Assumptions and
Risks
•
TA interim report.
•
Close supervision by
ADB staff.
•
TA consultants final
report.
•
b. Conceptualize
sustainable financing
mechanism for private
sector, that are based on
normal commercial
business relations between
private ventures and
financial institutions.
c. Conceptualize microcredit schemes for endusers.
d. Discuss and agree
financing concepts with
financial sector.
6. Capacity building:
a. Training needs
Private sector
opportunity in the
to engage.
•
Local financial
the business
opportunities and
engage proactively in
the development of
•
Target PDMC
governments give high
priority to the rationale,
take ownership over its
approach and
methodology, and
allocating the
necessary human,
organizational and
inception
5. Financing schemes
development:
a. Assess the financial
barriers facing the private
industry and the end users
of energy services
•
during inception
Complete: To be
determined during
inception
Responsibility: To be
determined during
inception
inception
b. Start: To be determined
during inception
Complete: To be
determined during
inception
determined during
inception
inception
c. Start: To be determined
during inception
Complete: To be
determined during
inception
determined during
inception
inception
d. Start: To be determined
during inception
Complete: To be
determined during
inception
determined during
inception
inception
Appendix 13 - 14
Design Summary
assessment in private and
public sectors.
b. Develop curricula
Performance
Indicators/Targets
7.Prepare a pipeline of
ADB/GEF renewable
energy and energy
efficiency initiatives for
ADB/GEF funding:
during inception
Complete: To be
determined during
inception
during inception
Complete: To be
determined during
inception
determined during
inception
c. Prepare Project
Development FinancingBlock B proposal for each
project.
•
ADB quarterly Project
Performance Reports.
•
•
TA consultants’
progress reports.
•
TA interim report.
•
Close supervision of
ADB staff.
•
TA consultants’ final
report.
•
determined during
inception
a. Identify and outline
appropriate projects
b. Prepare project Concept
Papers in close
consultations with Global
Environmental Facility
Focal Points and energy
projects country teams in
each target PDMC
during inception
Complete: To be
determined during
inception
determined during
inception
c. Start: M22
Complete: M24
Responsibility:
inception
inception
inception
8. Disseminate activities
a. Synchronize activities
with impending
ADB/GEF/CDM project
Assumptions and
Risks
a. Start: M1
Complete: M4
Responsibility: TA
during inception
Complete: To be
determined during
inception
Responsibility:
c. Identify and contract
appropriate training
institutions and trainers.
Monitoring
Mechanisms
during inception
Complete: To be
determined during
inception
•
Private sector
opportunity in the
to engage.
•
Local financial
the business aspects
and engage
proactively in the
development of
Appendix 13 - 15
Design Summary
b. Participate in workshops
and seminars
c. Workshop session at
end of project.
Performance
Indicators/Targets
Monitoring
Mechanisms
Assumptions and
Risks
inception
determined during
inception
during inception
Complete: To be
determined during
inception
determined during
inception
during inception
Complete: To be
determined during
inception
determined during
inception
inception
inception
Inputs
•
$600,000
•
•
$150,000
•
International
Consultants
•
Domestic Consultants
•
•
ADB (Danish
Cooperation Fund for
Renewable Energy
and Energy Efficiency
in Rural Areas
•
Consultants progress
reports
•
Timely disbursements,
and PDMC support
•
Competent
consultants with
demonstrated ability
hired
Inception report
Midterm report
Interim report
•
Participating PDMCs
Final Report
•
17 person-months
TA review missions
Assistant TA manager
•
36 person-months
ADB Staff (TA project
manager)
•
12 person-months
•
4 person-months
Appendix 13 - 16
TECHNICAL ASSISTANCE KEY ACTIVITIES
The Technical Assistance (TA) will implement the following activities:
(i)
The TA will prepare, discuss, and disseminate lessons from the past through a
stocktaking review of past renewable energy and energy efficiency assistance in
the Pacific.
(ii)
The TA will develop and prepare an action plan for the adoption of an appropriate
policy framework, including a system of incentives promoting commercialization
and privatization of renewable energy and energy efficiency services. Toward
this goal, the TA will (a) during the inception phase, assist the participating
Pacific developing member countries (PDMCs) to prepare and issue a
development policy letter on renewable energy and energy efficiency; (b) develop
and identify objectives and modalities of new policy interventions; (c) provide
direct assistance to the policy/strategy development process, as requested and
required by the countries; (d) facilitate definition, formation, and initiation of
working groups responsible to substantiate and implement the new policy
directions; and (e) ensure conformity of policy measures with eligibility criteria of
renewable energy and energy efficiency and climate change funding/cofinancing
sources, such as, Asian Development Bank (ADB), Clean Development
Mechanism (CDM), Global Environmental Facility (GEF), and others.
(iii)
The TA will develop and prepare an action plan for the establishment of
appropriate institutional arrangements by (a) facilitating, establishing, or
reforming essential public and semi-public institutions to pilot and provide
technical and financial support to the emergence and sustainable operation of a
commercial market for renewable energy and energy efficiency services; and (b)
identifying and organizing relevant local renewable energy and energy efficiency
services and manufacturing industries in a central organization/network, which
will represent the private sector. The industries association will, among other
things, share with government agencies the responsibility for developing
institutional, regulatory, and legal frameworks and mechanisms.
(iv)
The TA will develop and prepare an action plan for the adoption of the necessary
regulatory and legal framework by supporting (a) development of technical norms
and standards for equipment and systems; (b) development of codes of practice
for installation, operation, maintenance, and servicing of equipment and services;
(c) development of certification schemes for practitioners that are individuals
(technicians, engineers, planners, etc) or industries (suppliers); and (e)
preparation of legal models/formats covering the supply-demand institutional
linkages (sales and service contracts, loan agreements, etc).
(v)
The TA will develop a system of financing schemes targeted at the private sector
and household end-users by (a) assessing financial barriers constraining
investment decisions and facing the private sector and end-users of energy
services; (b) establishing sustainable financing mechanisms for the private
sector, based on standard commercial business practices between private
ventures and financial institutions; (c) developing microcredit schemes for endusers; and (d) consulting and reaching consensus on all proposed financing
aspects with the finance and banking sector.
Appendix 13 - 17
(vi)
The TA will support capacity building and training development through: (a)
preparation of the training needs analysis of the key private and public sector
stakeholders; (b) curriculum development; and (c) identification of appropriate
training institutions and trainers.
(vii)
The TA will prepare a pipeline of renewable energy and energy efficiency
projects to be potentially funded by ADB/GEF/CDM or other funding sources, by
(a) identifying and outlining, during inception, an appropriate pipeline of projects;
(b) preparing project profiles/concept papers in close consultation with ADB staff
as well as with ADB country program officers and GEF/CDM focal points in each
target PDMC; and (c) preparing GEF block B grant applications and/or other
required initial project preparation documents to follow-up on other funding
sources opportunities.
(viii)
The TA will consolidate and disseminate lessons learned by (a) working in
parallel and sharing approaches with ongoing renewable energy and energy
efficiency and other rural energy TA programs and projects, (b) proactively
participating in relevant workshops and seminars during the TA implementation
period, (c) organizing and holding a final TA workshop session to share TA
results and lessons with other PDMCs, and (d) preparing and distributing an ADB
publication with all major lessons from TA implementation including a projects
pipeline for future funding.
Appendix 13 - 18
COST ESTIMATES AND FINANCING PLAN
($)
Item
A. Asian Development Banka
1. Consultants
a. Remuneration and Per Diem
i. International Consultants
ii. Domestic Consultants
b. International and Local Travel
2. Reports, Communications, and Publications
3. Regional Seminars and Workshops
4. Contingencies
Subtotal (A)
B. PDMC Financingb
1. Remuneration and per diem of counterpart staff
2. Administrative Support
Subtotal (B)
Total
Total
Cost
320,000
132,000
30,000
8,000
30,000
80,000
600,000
90,000
60,000
150,000
750,000
PDMC = Pacific developing member country
a
Financing by the Danish Cooperation Fund for Renewable Energy and Energy Efficiency in Rural Areas
b
Each of the two participating PDMCs financing 50% of the amounts indicated.
Source: Asian Development Bank estimates.
Appendix 13 - 19
OUTLINE TERMS OF REFERENCE FOR CONSULTANTS
A.
Scope of Work
1.
The Technical Assistance will be implemented by six consultants: one international
consultant (team leader); one domestic consultant locally recruited in the Philippines (assistant
project manager); two domestic consultants (one national technical expert [NTE] in each
participating Pacific developing member country [PDMC]); and two short-term international
consultants (financial expert and norms and standards expert). The TA is divided in two phases:
inception and implementation. Key TA activities are described in Appendix 2.
2.
The international consultants will be responsible for all the outputs included in the Terms
of Reference (TOR), and in the key activities listed in Appendix 2. They will coordinate
preparation and finalize (i) the inception report (including detailed TOR, activities, revised TA
framework, TA reports outlines, and work plan) by the end of week 4; (i) the midterm report
(including the stock taking report) by the end of month 8; (iii) the second midterm report by end
of month 16; and (iii) the final report by the end of month 23. Report outlines will be discussed
and agreed upon with the Asian Development Bank (ADB) TA project specialist at TA
implementation start-up. Outlines of the midterm reports and the final report will be agreed upon
during inception.
3.
During the inception phase, the TA will primarily focus on five activities: (i) stocktaking of
prior and ongoing initiatives related to renewable energy and energy efficiency in the region
(Pacific Islands Renewable Energy Project, Pacific Rural Renewable Energy France-Australia
Common Endeavor, etc); (ii) develop selection criteria and select the two target PDMCs; (iii)
assist the selected PDMCs to develop and issue a development policy letter on renewable
energy and energy efficiency; (iv) in close coordination with the existing country level energy
projects team (e.g. PIREP energy country team), establish an effective project implementation
structure within the national implementing agency in each PDMC and develop detailed project
implementation plans and arrangements; (v) recruit the 2 NTEs for the two participating PDMCs,
and (vi) identify and prepare an initial pipeline of appropriate renewable energy and energy
efficiency projects for funding by ADB, Global Environmental Facility (GEF), Clean Development
Mechanism (CDM) and other funding sources. The inception phase will last for 4 months. In
relation to technology choices, a holistic approach should be adopted while avoiding any bias
toward solar photovoltaic, wind, biomass, grid extension, or any other particular technology. The
applicable type of technology to meet this goal should be chosen freely from site to site, based
on a lifetime least-cost analysis that weighs all relevant technologies against each other, and
with due consideration for major issues such as sustainable operation and maintenance
mechanisms, existing and planned infrastructure; financing schemes and subsidies; and
economic, environmental, and social impacts at both local, national, and global level.
4.
The implementation phase (20 months) will include all the TA activities remaining to
realize the necessary set of policies and workable delivery mechanisms for providing
commercially viable rural energy services. Further, in preparing the projects pipeline for funding
by ADB/GEF/CDM and other sources, the TA will, within the first few months of the
implementation phase, produce concept papers and Project Development Financing-Block B
proposals for such projects. The succeeding ADB/GEF/CDM funded projects are to tentatively
commence 3-4 months prior to termination of the TA, which will allow a period of parallel
operation, with synchronization and handing-over of lessons learned. Sustainability of project
outputs is further secured via a workshop by the end of the TA period.
Appendix 13 - 20
5.
TA implementation will be assisted by a team of international (17 person-months) and
domestic (36 person-months) consultants, recruited through a consulting firm, and consisting of
(i) one international technical expert (ITE), team leader, with expertise in renewable energy and
energy efficiency policy in small island countries, institutional arrangements, regulatory and
legal frameworks, and private sector participation; (ii) two short-term ITEs, with expertise in
developing financing models and designing and introducing technical norms and certification
schemes; and (iii) two NTEs, (18 person-months per PDMC, 36 person-months total), with
experience in rural energy, renewable energy and energy efficiency projects and
comprehensive knowledge of relevant national policies, institutional arrangements, and private
sector aspects. The two NTEs will be recruited after selection of the two participating PDMCs,
and subject to ADB’s approval. Staff from the implementing agencies will also support TA
implementation. In addition, one assistant project manager (12 person-months), with expertise
in energy, environment, and managing and coordinating ADB TA projects will be recruited by
ADB in the Philippines to assist in overall TA management and coordination of TA
implementation. All consultants will be engaged in accordance with ADB’s Guidelines on the
Use of Consultants and other arrangements satisfactory to ADB for the engagement of domestic
consultants. Given the level of innovativeness required for effective TA implementation, with
respect to approach, methodology and TORs, the consulting firm selection process will follow
the full technical proposal and the quality- and cost-based selection methods.
B.
Terms of Reference
1.
International Consultants (17 person-months)
a.
6.
Renewable Energy and Energy Efficiency Economist and Policy
Specialist (Team Leader)
The specialist will do the following:
(i)
(ii)
(iii)
Manage and coordinate overall TA implementation by preparing and completing
TA reports as required (inception, midterm, interim, and final); developing a
structure of work for the two phases of the TA, including work plans, timelines,
and detailed cost estimates; briefing stakeholders on the TA implementation
(ADB, development partners such as United Nations Development Programme
(UNDP) and GEF, and regional organizations such as the Council of Regional
Organizations of the Pacific-Energy Work Group (CROP-EWG); South Pacific
Regional Environment Programme (SPREP); and South Pacific Applied
Geosciences Commission (SOPAC) consulting and working with the national
implementing agency and the TA steering committee in the two target PDMCs.
Review and analyze previous and ongoing Renewable Energy and Energy
Efficiency activities to take stock of progress achieved and lessons learned
regarding technology use, program replication, and sustainability of inputs and
outputs; and identify market, policy, financial, and technical barriers to renewable
energy and energy efficiency technologies, especially taking into account the
Pacific Islands Renewable Energy Project (PIREP) and its initial progress.
Based on the results of the review, develop specific requirements and criteria for
selecting target PDMCs for this TA, and consult with country-level energy
agencies, other energy projects country teams and national GEF focal points on
the TA approach. Based on the consultations, validate inputs and finally propose
two participating countries to be selected for implementation of the TA.
Appendix 13 - 21
(iv)
(v)
(vi)
(vii)
(viii)
(ix)
(x)
(xi)
(xii)
Identify and select an NTE in each participating PDMC and comprehensively
introduce them to the TA and their specific roles and responsibilities. Develop
detailed implementation plans and arrangements.
Together with the NTEs, assist the two participating PDMCs to develop and issue
a development policy letter on renewable energy and energy efficiency
manifesting the countries’ commitments to (i) give genuine priority to the TA’s
rationale and take ownership over its approach and methodology, (ii) designate
an appropriate national implementation agency to coordinate TA activities, (iii)
constitute a TA steering committee with representation from all relevant
stakeholders, and (iv) provide counterpart contributions.
Directly and through the NTE, introduce the national implementation agency and
the TA steering committee in the selected PDMCs to a conceptual approach to
the creation of an environment enabling a market for rural energy services that is
demand-driven and based on the private sector, and guide the PDMCs, through
the development and implementation of an appropriate action plan in the process
of adapting the approach to local socioeconomic and cultural conditions.
Directly and through the NTE, enhance local capability within the national
implementing agency and the TA steering committee in developing and
implementing the action plans for the necessary policy reforms, institutional
measures, and regulatory legal frameworks.
Prepare a needs assessment and detailed TOR for the short-term ITE on
Prepare a needs assessment and detailed TOR for the short-term ITE on
development of technical standards and certification schemes.
In close consultations with national GEF focal points, Pacific Islands Climate
Change Assistance Program (PICCAP) country teams, and other energy projects
country teams, identify project opportunities, outline and prepare concept papers
and Project Development Financing-Block B proposals, and help prepare
(including initial financial and economic analysis) an appropriate pipeline of
renewable energy and energy efficiency projects for financing/cofinancing by
ADB/GEF/CDM and other funding sources.
Coordinate a final workshop to present, discuss, and disseminate lessons and
good practices from TA implementation.
Other tasks as developed and agreed during inception.
b.
7.
Renewable Energy and Energy Efficiency Financing Schemes
Specialist
(i)
(ii)
(iii)
In the target PDMCs, prepare an overview of the financial sector’s relevance to
the energy market and identify commercial banks with relevant experience and/or
potential to participate in (a) microfinancing schemes for end-users (rural and
outer islands banks with wide spread network of branches), and (b) a financing
scheme for private sector small and medium enterprises.
Review and analyze experience from previous and ongoing similar financing
schemes, including progress achieved and lessons learned from addressing
market, policy, and financial barriers.
Together with the NTE, conduct qualitative and quantitative analyses of (a) the
financial capability and willingness to pay for energy services by the targeted
rural populations (end users); and (b) the financial capability and readiness to
Appendix 13 - 22
(iv)
(v)
(vi)
(vii)
(viii)
(ix)
invest in expansion of business and business areas by local renewable energy
and energy efficiency industries.
Develop a microfinancing scheme for end users, based on normal commercial
lending principles. If special incentives are deemed necessary, they will be
designed as narrowly targeted and time-limited cross-subsidies, and must have a
clear phase-out plan.
Develop a financing scheme for small and medium enterprises engaged in
supplying rural energy services. The scheme will be targeted to hardware
suppliers of renewable energy and energy efficiency technology, and to
operators of energy service companies in build, own and operate (BOO)
concession-like arrangements.
Develop and implement with an appropriate fund manager the concept of a credit
guarantee fund to mitigate some of the perceived commercial and technical risks
that the involved financial institutions are facing (risk sharing).
Oversee and guide the preparation of draft specimens for agreements between
the parties of the two or more financing schemes (borrowers, banks, fund
managers, national implementing agencies, TA steering committees, etc.).
Prepare comprehensive documentation on the financing models (possibly also in
the form of a training manual).
c.
8.
(i)
(viii)
Prepare an overview of international, national, and regional renewable energy
and energy efficiency technology standardization initiatives.
Guide a broad-based technical committee (chaired by the national bureau of
standards or similar organization) in developing and adopting appropriate
technical standards for equipment and systems for renewable energy and energy
efficiency.
Introduce certification schemes for practitioners in renewable energy and energy
efficiency equipment, system and service delivery.
Introduce the concept of mandatory warranty on supplied renewable energy and
energy efficiency equipment and systems, including reassignment of
manufacturers warranty from importers/suppliers to end-users.
Provide guidance in preparing codes of practices for installation, daily operation
and maintenance, and periodical servicing of equipment and systems based on
renewable energy and energy efficiency.
Introduce the concept of ethical standards in the industries association, to help
instill confidence in end-users and raise overall industry performance.
Compile an overview of the developed technical standards, codes of practices,
and certification schemes.
2.
Domestic Consultants
(ii)
(iii)
(iv)
(v)
(vi)
(vii)
a.
9.
Renewable Energy and Energy Efficiency Technical Standards
Specialist
Assistant TA Manager
The assistant TA manager will do the following:
Appendix 13 - 23
(i)
(ii)
(iii)
(iv)
(v)
(vi)
Assist the ADB staff (TA manager) and the consultants team leader with their
duties, and the preparation, compilation, and editing of the TA inception,
midterm, and final reports.
Review and analyze previous and ongoing activities related to renewable energy
and energy efficiency to take stock of progress and lessons learned regarding
technology use, program replication, and the sustainability of the systems
installed. Identify any remaining gaps. Identify market, policy, financial, and
technical barriers to energy efficiency penetration, taking into account types of
technologies used, including hybrid systems.
Assist the ADB Staff (TA manager) and the consultants team leader as the
contact person for the TA of the national implementing agency and the TA
steering committee in the participating PDMCs.
Ensure conformity of project implementation with regulations and common
practices for similar ADB TA projects.
Help prepare and implement the final workshop.
b.
10.
Two National RE and EE Technical Experts
The experts will do the following:
(i)
(ii)
(iii)
(iv)
(v)
(vi)
(vii)
(viii)
(ix)
Assist the team leader to identify and outline appropriate projects for the
succeeding ADB/GEF/CDM funded initiatives.
Together with the team leader, assist the PDMCs to develop and issue a
development policy letter on renewable energy and energy efficiency.
Identify private sector industries for activities related to renewable energy and
energy efficiency.
Oversee the establishment of an effective national implementing agency to
coordinate and implement TA activities.
Oversee and assist the national implementing agency to establish a TA steering
committee with representation of all relevant stakeholders.
Proactively assist the national implementing agency and TA steering committee
in general planning and undertaking of their responsibilities under the TA.
Provide an interface between key stakeholders, beneficiaries, government,
departments of energy, etc., having a renewable energy mandate and energy
working groups, Pacific Islands Climate Change Assistance Program country
teams, energy projects country teams, and others to facilitate coordination of TA
implementation.
Help prepare and implement the final workshop and its dissemination activities.

Renewable Energy and Energy Efficiency Programme (REEP)

Transcription

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