barriers to developing small scale hydropower in the philippines a presentation for the climate...
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Barriers toBarriers toDeveloping Small Scale Developing Small Scale
Hydropower in the Hydropower in the PhilippinesPhilippines
A Presentation for the
Climate Change Information Center
Dec. 10, 2002
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Barriers to Developing Small-Scale Hydropower in the Philippines
Summary• Introduction to HEDCOR• Mini-hydropower development in the
Philippines• Barriers to developing mini-hydropower
in the Philippines
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About Hedcor
HedcorHydro Electric Development Corporation
• Is an affiliate of Aboitiz Equity Ventures• Owns and/or operates 14 mini-hydro plants• Total generating capacity of about 39 MWs• Generating about 150 GWhrs annually
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About Hedcor
HedcorO&M contractor of 70 MW
Bakun AC hydro plant• 1st and only BOT hydro project
in the Phils.
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About Hedcor
Hedcor• Mini Hydropower
Development
(design, construction,
maintenance & rehabilitation)
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About Hedcor
Hedcor• Fabrication & Machining• Watershed Management• Liaisoning
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About Hedcor
Hedcor’s vision:
We lead in the promotion
and development of clean energy.
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Small-Scale Hydropower Developmentin the Philippines
3 laws & a code that affected the development of mini-hydropower:•R.A. 7156 - Mini-hydroelectric Power Incentives Act• R.A. 9136 – Electric Power Industry Reform Act• R.A. 6957 B.O.T. Law•National Grid Code
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Mini-hydroelectric Power Incentives Act
R.A.7156
Mini-hydroelectric Power Incentives Act
defines mini-hydro as:
100 kws < MINI < 10 MWs
Micro-hydro < 100 KWs
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Mini-hydroelectric Power Incentives Act
Republic Act 7156• Grants incentives to mini-hydro developers (tax
free importation of eqpt.)
• Obligates NPC to buy generation at avoided cost• Vat-exempt status for mini-hydro• Special Privilege Tax of 2%• Enacted September 1991
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Electric Power Industry Reform Act
REPUBLIC ACT 9136
• The Power bill was suppose to bring transparency.
• Deregulation, privatization & competition were to lower cost to “true cost of power”
• Instead we have higher subsidies
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Electric Power Industry Reform Act
REPUBLIC ACT 9136• SEC. 2. (h): To promote the utilization of indigenous and
new and renewable energy sources in power generation in order to reduce dependence on imported energy.
• SEC. 37. (e) (i): Encourage private sector investments in the electricity sector and promote development of indigenous and renewable energy sources.
• No specific IRRs
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Build Operate Transfer Act
REPUBLIC ACT 6957 & 7718• Provided a framework of risk sharing between
the private developer and GOVERNMENT• Developers could negotiate BOT contracts w/
LGU’s, government agencies and GOCC’s• Typically, a developer bids for a contract,
constructs and operates the project for 25 yrs, and then turns the project over
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National Grid Code
The Code that all power plants comply with:• SCADA requirements• Tele-protection requirements• Communication requirements
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Challenges in Developing Hydropower
• Most mini-hydro schemes are in remote areas
and therefore usually in coop franchises• Electric coops have small loads and poor load
factors• Run-of-river hydro schemes cannot maintain
firm capacity whole year round
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Challenges in Developing Hydropower
• Most mini-hydro schemes are in remote areas
and therefore usually in coop franchises• Only a handful of electric coops are bankable
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Challenges in Developing Hydropower
• High cost of wheeling power:– Transmission rate: P0.3076– Sub-transmission rate: P0.0362
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Challenges in Developing Hydropower
• The wheeling fee is based on the monthly
peak demand.
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Challenges in Developing Hydropower
• The customer’s demand charges will only be
reduced if the generator is able to generate at a firm level for the entire billing period
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Challenges in Developing Hydropower
Long term loans at developmental rates are
not available.
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Challenges in Financing Mini-hydropower
• Development banks receive foreign loans at
developmental rates to help promote the development of mini-hydropower
• And lend to developers at near commercial rates
• Full collateral requirements
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Challenges in Financing Mini-hydropower
• Commercial banks are unfamiliar with
hydropower projects• Uncomfortable taking hydrological risks• Required parent company guarantee• More expensive than rates extended by
development banks
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Challenges in Financing Mini-hydropower
When we started (JEXIM):
• 15.5% per annum (+ GRT)• 8 yr term – 21 equal quarterly payments• 3 yr grace period on principal• fully secured by parent company
– NO project financing available
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Challenges in Financing Mini-hydropower
Probable commercial banking terms today:• banks are not very excited to lend to power projects • 90-day T-bills + 2.0% spread or about 12.0% (exclusive of GRT)
– must be fully secured + parent guarantee
– 70/30 debt equity requirement
– Project finance using local currency not available
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Challenges in Developing Mini-hydropower
Suggested measures to promote the development of mini-hydropower:• Create a market
– require utilities to purchase X% of their consumption from NRE’s
– public awareness campaign on clean energy
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Challenges in Developing Mini-hydropower
Suggested measures to promote the development of mini-hydropower:• eliminate or reduce the wheeling fees for NRE’s• charge wheeling fees based on average monthly use (i.e. kwhrs/hrs x rate)
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Challenges in Developing Mini-hydropower
Suggested measures to promote the development of mini-hydropower:• DOE/DENR to initiate steps to augment the revenue of mini-hydropower developers
– possibly through CDM
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Challenges in Developing Mini-hydropower
Suggested measures to promote the development of mini-hydropower:• exempt mini-hydropower plants from technical requirements imposed on bigger plants (i.e. spinning reserve, back-up reserve, SCADA, reactive power capability, system frequency limits, etc.)
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PotentialMini-hydropower Sites Identified
LUZON CAPACITY
Wangal 1.0 MW
Irisan 1 1.6 MW
Irisan 360 1.0 MW
Talecbed 0.5 MW
Gambang 2.0 MW
Irisan 2 1.6 MW
Abdao 1.2 MW
Eddet 1 2.8 MW
Anneng 0.8 MW
Eddet 3 3.0 MW
Kagaling 2.0 MW
Lomboy 1.5 MW
Tuba 2 1.0 MW
Total 20 MW
LUZON CAPACITY
Bineng 4 3.0 MW
Ampusongan
2.0 MW
Omico 1 0.9 MW
Suyoc 1.5 MW
Omico 3 1.5 MW
Upper Ampohaw
1.0 MW
Upper Labay
0.75 MW
Irisan 4 0.75 MW
Lower Ampohaw
1.6 MW
Adaoay 1.5 MW
Ampohaw B 1.2 MW
Tuba 3 1.0 MW
John Hay 1.2 MW
Total 17.9 MW
VISAYAS AND
MINDANAO
CAPACITY
Pamplona 0.55 MW
Cambagang 2.5 MW
Tandik 8.0 MW
Camanlangan
5.2 MW
Sibulan 1, 2, 3
27.6 MW
Tamugan 5.4 MW
Cateel 5.0 MW
Total 54.25 MW
TOTAL POTENTIAL
100.15 MWS
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www.hedcor.com