The Philippine Energy Transition
1Sara Jane Ahmed, Energy Finance AnalystMarch 2019The Philippine Energy TransitionBuilding a Robust Power Market to AttractInvestment, Reduce Prices, Improve Efficiencyand ReliabilityThe Business CasePhilippine electricity prices are the highest in South East Asia at roughly US 0.20per kilowatt-hour (kWh) or Php 10 per kWh. Excessive reliance on imported coaland diesel is one of the main reasons the Philippines has the highest electricityprices in the Association of Southeast Asian Nations (ASEAN) region. The lowuptake of renewables is surprising given that solar, wind, run-of-river hydro,geothermal and biogas are viable domestic generation options. This is especiallytrue when paired with storage for ancillary services such as frequency regulationproviding both enhanced and firm frequency responses, spinning reserves andvoltage support. These can be combined to create the type of cost effective andsecure energy system that an island nation like the Philippines needs.Corporates are making strides to divest from coal in favor of renewables. In 2018,Philippine companies, such as the Ayala Corporation subsidiary AC Energy, are setto sell US 1 billion worth of coal assets. According to AC Energy, the sale aims tobalance its renewable and thermal portfolios and raise capital to support regionalexpansion targeting 5 GW of geothermal, solar and wind projects in Vietnam,Indonesia, and the Philippines by 2025. AC Energy has invested in: an 81MW NorthLuzon wind farm in Pagudpud and a 52MW Northwind Power wind farm in BanguiBay, as well as the MonteSol, IslaSol and SacaSol solar projects. AC Renewables hasalso invested in Vietnam's Nin Thuan, Khanh Hoa and Dak Lak solar parks, and inIndonesia's Sidrap wind farm and Salak and Darajat geothermal plants.Ayala Corporation is not the only player to follow this global trend of fossil fueldivestment and renewable capacity investment. Companies in India, China,Malaysia, and most recently, Vietnam, are increasingly moving towardscancellations and delays involving new coal plants. And Ayala Corporation is not theonly player to be following this trend in the Philippines. The Manila ElectricCompany, more popularly known as Meralco, shares this foresighted strategy andadded a carve-out provision, better known as “curtailment,” to all their new coalpower purchase agreements including the 1200MW Atimonan coal plant. Meralcorealizes it wants to protect ratepayers from the high risk of stranded assets byshifting the cost of bad decision-making to the coal power providers and theirinvestors. Despite leadership from the more successful corporations in the powersector, others, including the San Miguel Corporation, are still locked into legacystrategies and are increasing their coal exposure. San Miguel is doing this throughits power arm, SMC Global Power Holdings Corp., which planned to construct a 300megawatt (MW) coal plant in Negros Occidental. However, this is now cancelledbecause of leadership from the Governor of the Province of Negros Occidental who
The Philippine Energy Transitiondeclared the area as coal-free and supportive of renewable energy.1 This gives SMCGlobal Power the opportunity to instead build a renewable energy portfolio tocomplement its current storage/batteries pipeline of 240MW for ancillary servicesto the grid in Luzon.2Although coal risk remains underpriced in South East Asia, there is increasinginvestor appetite in capital markets for renewable energy projects. Most recently,AC Energy issued the first ever US dollar climate bond in South East Asia valued atUS 410 million on the Singapore Stock Exchange to finance renewable energyprojects in the Asia-Pacific region including the Philippines, Vietnam, and Indonesia.AC Energy initially launched an offering of US 225 million for a 5-year tranche andclosed at 300 million due to oversubscription. It also issued a US 110 million10-year tranche.3It is difficult to understand why, despite the systematic deflationary nature ofrenewable energy prices globally and capital market support, emerging markets likethe Philippines continue to lag behind global trends and are locking in long-termexposure to import coal, diesel and liquefied natural gas (LNG) import terminals.According to the Department of Energy (DoE), between 2018 and 2019, thePhilippines may expect 5,688 MW of new capacity at least 63% of which will beprovided by coal-fired power plants.4 If renewables are not lagging based oneconomics and financials, it is clear that they are losing due to a lack oftransparency, cost incentives, and Power Purchase Agreements (PPAs), known inthe Philippines as Power Supply Agreements (PSAs) that continue to protect fossilfuel interests.The Philippines faces a critical policy problem. Outdated market structures arecompromising the country’s ability to innovate and discouraging adoption of thecleaner and cheaper technologies that it badly needs. The current marketdysfunction is hindering rather than helping the transition to more sustainable andaffordable domestic solutions. The Philippines government can inject more diversityand more energy security into the electricity system—while helping lower costs toconsumers— by taking the following steps: Removing the Diesel Fuel Subsidy by the Department of Finance, Removing the Automatic Pass-Through by the Energy Regulatory Commission, Issuing Stranded Asset Risk Warnings across the financial value chain by theCentral Bank of the Philippines and the Securities and Exchange Commission,andExecutive Order No. 19-02, Series of 2019. An Order Declaring the Province of Negros Occidentalas a Source of Clean and Renewable Energy and a Coal-Free Province. 6 March 2019.2 ctric power/luzon indicative jan 2019.pdf3 Renewables Now. UPDATE- AC Energy's oversubscribed green bond sale hits USD 410m.February 5, 2019.4 Republic of the Philippines Department of Energy. Coal-Fired Plants Are 63% of Projects inPipeline.12
The Philippine Energy Transition Overhauling procurement practices by introducing Least-Cost Mechanismauctions by the utilities and the Energy Regulatory Commission.The Policy Changes:Remove the Diesel Fuel SubsidyVia Department of FinanceThe country’s electricity challenges are an outgrowth of its geography: thePhilippines consists of more than 7,000 islands, many of which are small and havetraditionally relied on generators fuelled by imported diesel. The true cost ofgeneration by diesel ranges from Php 10 per kWh (US 0.20) to Php 165 per kWh(US 3.30),5 while approved subsidized rates range from Php 4.8 per kWh (US 0.09)to Php 5.6 per kWh (US 0.11).6 In 2017, the projected budget for diesel fuel alone tosmall islands supplied by the Small Power Utilities Group (SPUG) under the NationalPower Corporation (NPC) and other power providers (known as new powerprovider/NPP), was Php 10.32 billion (US 206.4 million).7The table below provides an overview of NPC SPUG price differentials between thetrue cost of diesel and the approved subsidized rate, with consumers paying thedifference. These islands frequently experience rolling blackouts and unplannedpower outages because of grid instability, inadequate generation capacity, andunaffordable rates. In many cases, limited market size makes 24/7 serviceimpossible to justify with some operating only between 8 and 16 hours per day. Buteven worse, this unreliable service is heavily subsidized through what is known asthe Universal Charge for Missionary Electrification (UCME) with a planned cost ofPhp 14.66 billion (US 293.2 million)8 in 2019. The total amount expected to be paidby SPUG consumers is Php 6.67 billion (US 133.4 million) while the expectedamount paid for by consumers outside SPUG areas in 2019 will be Php 7.99 billion(US 158 million). In other words, consumers – residential, commercial or industrial– in the Philippines main grids and other small island grids, are being forced tosubsidize failing electricity systems.National Power Corporation Corporate Affairs Group. True Cost Generation Rate, P/k/Wh. As ofDecember 2017.6 National Power Corporation. NPC-SPUG Electricity Rates. Small Power Utilities Group ExistingEffective Rates. February 2019.7 IEEFA, Sara Jane Ahmed. Electricity-Sector Opportunity in the Philippines. May 2017.8 Republic of the Philippines Energy Regulatory Commission. ERC Case No. 2018-076RC. August2018.53
The Philippine Energy Transition4Table 1: True Cost of Diesel and Subsidy (Snapshot) 9Difference(Php perkWh) paidfor bySubsidiesfromConsumersOperating HoursNPC SPUG AreaPlant/Power BargeTrue Cost ofDiesel (Php perkWh)ExistingSubsidizedApprovedGenerationRate (SAGR)(Php per kWh)MasbateBurias Mini Grid103.095.1297.978MasbateMasbate Pres MiniGrid165.525.12160.406-8RomblonSibuyan DPP25.565.6419.9224BantayanDoong DPP30.466.2624.2024Tawi-TawiTandubanak DPP25.535.1220.4112Other VisayasPanay Mini Grid127.375.64121.738Other VisayasAlmagro DPP,Western Samar38.285.6432.648Other VisayasSan Vicente DPP,Northern Samar44.095.6438.4516Other MindanaoSacol DPP,Zamboanga36.714.8031.9116Other MindanaoHikdop DPP, Surigaodel Norte32.814.8028.0116At a time when renewable energy enhances affordability, neither the governmentnor consumers should be footing the bill for diesel subsidies. In fact, the governmenthas access to a viable pathway to transition because these financially burdenedsmall island grids represent a largely overlooked opportunity for investors inrenewable energy and storage that can readily replace imported diesel generation inlocations spread across the Philippines. The business case for such investment isstrong. Local deployment of renewables would lead to the dismantling of outdatedand unnecessary infrastructure and outmoded forms of electricity generation thatrely on diesel imports. Upgrading small island power systems through the uptake ofrenewables will advance the spread of secure, more affordable, and cleaner power.9Refer to Appendix 1 for Expanded Table.
The Philippine Energy TransitionThe key to implementing this transition would be a phased program of replacingdiesel by hybridizing existing plants with renewable energy through a variety ofstrategies:I. Fuel Displacement Model - On grids where peak demand is now fully met bydiesel plants, and where the average cost of renewable energy is less than thevariable costs of diesel generation (which consists mostly of fuel and lubes),electricity produced by run-of-river hydro, biomass, solar, and wind is nowpositioned to compete economically and to progressively displace imported dieselfired generation by way of hybridization initiatives. Viable renewable-generationprices today indicate that diesel dependence can be reduced as the grid takes onincreasing renewables. The economics of transition through hybridization arecompelling. The main tool that can enable this transition is a technology-neutralprocurement process for new power where technologies will compete on a perkilowatt hour (kWh) price basis via auctions. Hybridization can enable a reductionin total price per kWh for consumers.II. Meeting Incremental Capacity - An incremental capacity approach bringsadditional electricity-generation capacity at a lower cost than the fuel-displacementmodel, at a quicker pace, and with a greater degree of stability. Adding solar andwind capacity incrementally to the electricity-generation mix across the manyislands of the Philippines makes economic sense, because renewables now offerlower average energy costs compared to diesel generation. Enticing investment tomeet incremental capacity can occur via auctions. But this strategy also suggests agreater renewable-energy-to-imported-diesel capacity ratio than that of the fueldisplacement model. Some island grids may reach 100% renewable energy eitherwhen diesel contracts expire, or even sooner, as cost thresholds are crossed.Moreover, continual improvements in the commercial viability of battery storageand access to affordable financing structures will accelerate the uptake ofrenewables.The current system subsidizes both diesel fuel cost and the capacity payments ofdiesel generation, making it too expensive, having surpassed a certain costeffectiveness threshold. These thresholds are highlighted above through the FuelDisplacement Model, where average cost of renewables is less than the variable costof diesel, and Meeting Incremental Capacity (new capacity), where the average costof renewables is lower than the total cost of diesel generation. The above thresholdshighlight a case without much change to the current system. However, there comesa point where subsidies no longer make sense and it is time for the Philippinegovernment to allow the markets to work by removing subsidies that are no longerneeded, given techno-economic improvements. The next threshold, Fuel RenewableEnergy, highlights the most cost-effective strategy for the system via the removal ofunnecessary diesel subsidies while enabling a competitive environment forinvestment in more affordable generation.III. Fuel Renewable Energy - When average cost of renewable energy technologiesplus residual (inertial) capital recovery cost from extant thermal contracts are lessthan the true cost of generation from NPPs with diesel generation, all thermalgeneration will be displaced. How quickly this develops depends on how the Energy5
The Philippine Energy TransitionRegulatory Commission (ERC) and the Department of Energy (DoE) can assure theNPPs of cost recovery. In any case, ratepayers will still be burdened by paying morethan the average cost of comparable technologies.An added policy problem that needs to be addressed is the financial condition ofsome electric cooperatives. A number of them are heavily indebted due to inefficientcollections, mismanagement, or high transmission and distribution losses. To ensurea low-cost power system for consumers where affordability leads to greaterelectrification, the Philippine government would be smart to remove the dieselsubsidies and forgive the debt of cooperatives that switch to renewables, improveefficiency and management, and reduce transmission and distribution losses.Investment Opportunity - A full transition to renewable energy among smallisland grids is possible in the short term without financial support from the nationalgovernment. Such a transition, driven mainly by natural economic forces, could spurprivate investment of at least US 1 billion in 5 years from groups like Meralco, AyalaCorp, and other international power sector investors, with financing from capitalmarkets. Furthermore, the transition would lead to a significant reduction in crosssubsidies from ratepayers in the mainland grids through the aforementioned UCME.Remove the Automatic Pass-Through of Fossil FuelVia Energy Regulatory CommissionThe Philippines is still betting big on coal with 4,785 MW of coal projects committedin 2019 alone.10 But in the face of rapidly declining costs and technological advancesin renewable energy and storage, reliance on coal makes increasingly little sense.Like its diesel problem, the Philippines’ growing dependence on imported coal canbe tied directly to government-approved contracts, namely the Power SupplyAgreements, that perpetuate market distortions.For example, the power supply agreement (PSA) of the Panay Energy DevelopmentCorporation, a Meralco power supplier, dictates a delivered rate of Php3.96(US 0.08) per kWh. But because the company is allowed to pass on fuel costs andforeign exchange fluctuations directly to consumers, the actual generation rate forAugust 2017 was 37% higher, at Php5.41 (US 0.11) per kWh. This PSA, like othersapproved by the ERC, unfairly penalizes consumers who have no bargaining power.As the system is currently structured, ratepayers absorb all the risk while utilitiesand power generators remain insulated from ongoing market changes and, as aresult, have no incentive to transition away from coal or hedge against pricevariations and currency risks.Removing the ability for generators to automatically pass-through fuel and foreignexchange fluctuations would help level the playing field among competing energyproviders. This change has been suggested by both the DoE and ERC and they havePrivate Sector Initiated Power Projects (Luzon) Committed. As of 31 December 2018; PrivateSector Initiated Power Projects (Visayas) Committed. As of 31 December 2018; Private SectorInitiated Power Projects (Mindanao) Committed. As of 31 December 2018.106
The Philippine Energy Transitionbacked competitive bidding for fixed price delivery. If this were to be the case, thePanay Energy Development Corporation PSA with Meralco would be locked at thePSA price of Php3.96 per kWh, not Php5.41 per kWh, which was the generation ratefor August 2017.Stranded Asset Risk Warning Across the Financial ValueChainVia the Central Bank and Securities and Exchange CommissionWhile the concept of stranded costs may seem obscure to some, in truth, it isstraightforward: Costs become stranded when a company is unable to chargeenough for its product to recover its investment and production costs. In thePhilippines coal generation sector, this means utilities and other producers willneed to be able to recover the cost of building 4,785 MW of coal projects committedin 2019 alone,11 amounting to a potential stranded risk of US 9.5 billion, with abroader pipeline of 10,423 MW amounting to US 20.9 billion of stranded risk.Given the sharp and sustained declines in renewable energy costs over the past fewyears, as well as projections for continued declines in the years ahead, the country’scoal backers should no longer assume they can recover these costs, and insteaddiversify their power holdings.Meralco, for example, is underwriting an 85MW solar power supply deal for Php2.99 per kWh. Geothermal runs from Php3.5 to Php4.5 per kWh. Run-of-river hydrocosts range from Php3 to Php6.5 per kWh, and removing the permitting red tape,which currently takes about five years for project approval, could drive that priceeven lower. These prices, coupled with the recent success and sharp price reductionin offshore wind, point to continued renewable energy cost deflation and raiseserious questions about the economics of new coal generation.Stranded costs are already being crystalized in Mindanao, even without retailcompetition enabled by the presence of a wholesale electricity spot market. Asurplus of coal-fired generation on the island has pushed utilization rates downcompared to developers’ initial expectations, leading to Php 3 billion (US 60million) in unrecovered or stranded costs from 2014-2016.12While generators and developers ultimately may back away from coal, the market’scurrent structure, pushing most of the risk to consumers, needs to change to ensurethat this transition takes place sooner, rather than later.Meralco, for example, is at the forefront of protecting consumers and industry fromstranded assets via its carve-out clause in the PSAs, known as “curtailment clauses.”A carve-out clause can reduce the amount of power a utility must buy from a powerPrivate Sector Initiated Power Projects (Luzon) Committed. As of 31 December 2018; PrivateSector Initiated Power Projects (Visayas) Committed. As of 31 December 2018; Private SectorInitiated Power Projects (Mindanao) Committed. As of 31 December 2018.12 IEEFA, Sara Jane Ahmed & ICSC, Jose Logarta Jr. Carving out Coal in the Philippines: StrandedCoal Plant Assets and the Energy Transition. October 2017.117
The Philippine Energy Transitiongenerator and exempt distribution utilities from the consequences of coal plantoverbuilding and high coal costs. This could protect captive Philippine industry andother ratepayers from having to foot the bill for generator costs when othercompanies, under the country’s retail competition and open access program, turn tocheaper suppliers. Stranded asset risk is thus shifted to the coal power providersand their investors.Though Meralco claims that all its new coal contracts have it, the carve-out clauseneeds to become the mandatory policy of the ERC to protect all consumers andindustry from stranded asset risk. Without this, the market is burdened by the typeof moral hazard that came with over-selling of mortgage products in the run-up tothe global financial crisis. Too many developers believe they will be able to pass onthe risk of their flawed technology and fuel decisions because the regulatorystructure insulates them from market risk.This regulatory problem is aggravated in the Philippines because banks do notincorporate stranded-asset risk in project finance underwriting, either bynegligence or by design, and continue to support policies that transfer risks to theindustry and consumers instead. It is time for the government to equitablyredistribute such risk.Overhaul of Procurement Practices– Least-CostMechanisms (Auctions)Via Distribution Utilities and Energy Regulatory CommissionEnforcement of transparent auctions would put an end to self-negotiated generationrates and be a significant step toward open competition for the procurement of thelowest-cost option for power production. Procurement also must be conducted on atechnology-neutral basis. In the case of coal and diesel, future PSAs could beawarded based on how much a power producer is willing to step back from thetraditional automatic cost pass-through model and shoulder more fuel-price risk.For example, many such deals in India now have power generators agreeing to limitfuel-price passthroughs to 30% instead of 100%. In some cases, power generatorproposals are also being presented now with fuel hedge contracts, which reduceexposure to fuel cost volatility. Such contracts are already widely used by airlines,cruise lines and trucking companies, and can certainly be tapped by the electricpower industry.An appropriate auction mechanism could be developed in the Philippines with thefollowing mechanics in mind:1. The distribution utility issues a call for technology-neutral tenders to install acertain amount of electricity. Ceiling prices should not be disclosed to projectdevelopers that want to participate to ensure greater competition. Streamlinedadministrative procedures, with communication and transparency providedequally to all project developers, are essential.8
The Philippine Energy Transition2. Participating project developers submit a price per unit of electricity at whichthey will build the project. Utilities can use one of two ways to entertainsubmissions:a) Project developers simultaneously submit their price at which the electricitywould be sold under a PPA. A third-party manager, or the utility, ranks andawards projects until the sum of the quantities that they offer covers thevolume of energy being requested. This option has the benefit of simplicity,is easy to implement, fosters competition and avoids collusion. Post tenderaward disclosure of all final submissions also would improve transparency.b) In the initial round, the third-party manager or the utility offers a price, anddevelopers submit the amount of power they would be willing to provide atthat price. The third-party manager or the utility progressively lowers theoffered price in successive rounds until the quantity submitted matches thequantity to be procured. This option is more difficult to implement butallows for fast price discovery as well as greater transparency.3. Each offer is screened by the utility for viability (including proof of financial andtechnical capability, secured land, environmental license, grid connection, etc.)and subsequently selected based on price, starting with the least-cost project,until the utility reaches its megawatt-hour (MWh) limit for that round. Eachoffer is subject to strong compliance rules (including penalties, submissionbonds, project completion guarantees, etc.) that reduce the risk of undersubmissions, project delays, and project failure.4. Capacity remaining at the end of each round is added to the next round.5. Winning submissions are given a standard contract from the utility, which canthen go through an expedited regulatory review process.6. The regulatory body evaluates the contract based on the auction price and othercriteria the regulator deems relevant.ConclusionThe existing system has failed to protect electricity ratepayers. However, with theimplementation of the above recommendations, the reduction of moral hazard,correction of market distortions, and levelling of the playing field, more affordablepower provision will be able to advance the electrification goals of the country andmake energy more affordable for both consumers and industry.9
The Philippine Energy TransitionReferences Stranded Assets and Coal Risk: -out-Coal-in-thePhilippines IEEFAICSC ONLINE 12Oct2017.pdf Small Island Grids Transition: city-Sector-Opportunity-in-thePhilippines May-2017.pdf Rooftop Solar: http://ieefa.org/wpcontent/uploads/2018/08/IEEFA Unlocking-Rooftop-Solar-in-thePhilippines August-2018.pdf Least Cost Mechanism/Auctions: st-Cost-Mechanism March-2018.pdf Coal Tax: 20171.pdf Restructuring the Philippine Electricity Sector: -Sector-Nov-2017.pdf10
The Philippine Energy Transition11Appendix 1True Cost of Diesel and Subsidy (Expanded)True Cost ofDiesel (Php perkWh)ExistingSubsidizedApprovedGenerationRate (SAGR)(Php per kWh)Difference(Php perkWh) paidforSubsidies byConsumersOperating HoursNPC SPUG AreaPlant/Power BargeMindoro AreaOccidental MindoroSan Jose Grid12.895.647.2424Mindoro AreaOccidental MindoroMapsa Grid9.605.643.9624Mindoro AreaLubang DPP13.525.647.8824Mindoro AreaCabra DPP38.475.6432.828MarinduqueMarinduque Grid10.415.644.7724MarinduqueMarinduque MiniGrid44.665.6439.028MainlandPalawanEl Nido DPP11.005.645.3624MainlandPalawanTaytay DPP10.715.645.0724MainlandPalawanSan Vicente DPP15.215.649.5724MainlandPalawanRizal DPP13.255.647.6124CatanduanesCatanduanes Grid10.835.645.1924CatanduanesPalumbanes DPP45.655.6440.018MasbateTicao DPP12.905.127.7824MasbateSan Pascual DPP17.895.1212.7816MasbateMasbate Mini Grid41.685.1236.568MasbateBurias Mini Grid103.095.1297.978
The Philippine Energy Transition12MasbateMasbate Pres MiniGrid165.525.12160.406-8RomblonRomblon Grid14.455.648.8124RomblonSibuyan DPP25.565.6419.9224RomblonBanton DPP26.365.6420.7216RomblonSan Jose DPP15.845.6410.2016RomblonCorcuera DPP21.695.6416.0516RomblonConcepcion DPP25.005.6419.3616BantayanDoong DPP30.466.2624.2024BantayanGuintarcan DPP28.966.2622.7116CamotesCamotes Grid15.756.269.4924Tawi-TawiTawi-Tawi (Mainland)Grid14.085.128.9624Tawi-TawiBalimbing DPP23.415.1218.3016Tawi-TawiTandubas DPP29.185.1224.068Tawi-TawiSibutu DPP19.375.1214.2616Tawi-TawiSitangkai DPP21.765.1216.6516Tawi-TawiWest Simunul DPP22.315.1217.1914Tawi-TawiLanguyan DPP47.955.1242.838Tawi-TawiMapun DPP21.265.1216.1416Tawi-TawiTandubanak DPP25.535.1220.4112BasilanBasilan Grid14.905.129.7924SuluJolo DPP11.145.126.0224SuluPangutaran DPP66.975.1261.858SuluSiasi DPP16.465.1211.3424Other VisayasPilar DPP, Cebu18.325.6412.6824Other VisayasGigantes DPP, Iloilo22.315.6416.6724
The Philippine Energy Transition13Other VisayasCaluya DPP, Antique22.825.6417.1824Other VisayasPanay Mini Grid127.375.64121.738Other VisayasBohol 1 Mini Grid42.175.6436.538 & 24Other VisayasBohol 2 Mini Grid50.665.6445.028Other VisayasMaripipi DPP, Biliran25.295.6419.6524Other VisayasLimasawa DPP,Southern Leyte24.905.6419.2624Other VisayasZumarraga DPP,Western Samar21.665.6416.0224Other VisayasTagapul-An DPP,Western Samar40.575.6434.938Other VisayasAlmagro DPP,Western Samar38.285.6432.648Other VisayasSto. Niño DPP,Western Samar29.595.6423.958Other VisayasCamandag DPP,Western Samar61.785.6456.148Other VisayasAlmagro Mini Grid101.305.6495.668Other VisayasSto Nino Mini Grid33.995.6428.358Other VisayasCatbolagan Mini Grid79.235.6473.598Other VisayasSan Antonio DPP,Nothern Samar24.845.6419.2024Other VisayasCapul DPP, NorthernSamar24.015.6418.3724Other VisayasSan Vicente DPP,Northern Samar44.095.6438.4516Other VisayasBiri DPP, NorthernSamar25.855.6420.2116Other VisayasBatag DPP, NorthernSamar71.565.6465.928Other MindanaoSacol DPP,Zamboanga36.714.8031.9116
The Philippine Energy Transition14Other MindanaoDinagat Grid13.524.808.7124Other MindanaoHikdop DPP, Surigaodel Norte32.814.8028.0116Other MindanaoKalamansig DPP,Sultan Kudarat10.944.806.1424Other MindanaoSen. Ninoy AquinoDPP, Sultan Kudarat12.674.807.8716Other MindanaoPalimbang DPP,Sultan Kudarat20.784.8015.9816Other MindanaoBalut DPP, DavaoOccidental23.934.8019.1316Other MindanaoTalicud DPP, Davaodel Norte17.424.8012.6216
Appendix 2Below is an overview of committed private sector initiated projects in Luzon, Visayas, and Mindanao, as of December2018.13Committed Coal Projects with Target Commercial Operation by 2019Name ofProjectLimay PowerPlant ProjectPhase lidatedPowerCorporationAES MasinlocPowerPartners Co.,Inc.Main ContractorAwarded EPC toFormosa HeavyIndustries (FHI)POSCO Engineering andConstruction Co. Ltd,Korea (Offshore ‐EngineeringProcurement);Ventanas PhilippinesConstruction Inc.(Onshore ConstructionMain ataanZambales150OfftakeSanBuenaventuraPower Ltd. Co.(SBPL)BarangayCagsiay 1,Mauban,Quezon500RPEI Coal‐Fired PowerPlantRedondoPeninsulaEnergy, Inc / 52% owned byMeralcoPowerGenCorp. TargetCommercialOperationUnit 4 ‐February2019Php 49.45billionUnit 3 ‐ January2019March 2019Php 37.88billionOctober 2018December2019Php 50billion / US 1.2 billionUnit 1 – October2018 Unit 2
Power Corporation (NPC) and other power providers (known as new power provider/NPP), was Php 10.32 billion (US 206.4 million).7 The table below provides an overview of NPC SPUG price differentials between the true cost of diesel and the approved subsidized rate, with consumers paying the difference.
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