40 KWp Santiago

40, 60, 80 kWp Solar PV Santiago City Hall

August 2014

2 Private and Confidential

Copyright Notice

The Copyright of this work and of various elements of this work is vested in the Authors and the document is issued in confidence for the purpose only for which it is supplied. It must not be reproduced in whole or in part for any other purpose, except under an agreement or with the consent in writing from the copyright owners and then only on the condition that this notice is included in any such reproduction. No information as to the contents or subject matter of this document or any part thereof arising directly or indirectly there from shall be given orally or in writing or communicated in any manner whatsoever to any third party being an individual firm or company or any employee thereof without the prior

consent in writing of the copyright owners. This is a draft document. As it is a work in progress it may be incomplete, contain preliminary conclusions and may change. You must not rely on, disclose or refer to it in any document. We accept no duty of care or liability to you or any third party for any loss suffered in connection with the

use of this document.

© Copyright ERA Energy Renewables Asia Inc. 2011, 2012, 2013, 2014


Company Profile

Energy Renewables Asia is a Philippine based corporation, duly registered with the Securities and Exchange Commission as a Renewable Energy Power Developer, engineering, procurement and construction company. ERA is committed to developing a diversified and cost effective renewable infrastructure development and retail energy business in the Philippines. ERA is a collaborative corporation with proven renewable companies established in Australia and Germany, powerful procurement and project financing arrangements with product manufacturers in China, Japan and Germany; and selected business stakeholders local to the Philippines. ERA has established on over 40 years industry experience in deregulating energy markets and power generation project development. The ERA executive, management and engineering team is formed by directors, shareholders and executives of some of Australia's and Germany's most innovative renewable pioneering companies which together have implemented over 300 MW of renewable projects over the past 4 years alone. Its industry and technical positions are supported by executives and management with a local understanding of the local legal, regulatory, accounting, and tax framework in the Philippines. Through our corporate relationships we have also developed a strong network of renewable infrastructure technical service and suppliers encompassing Solar Photovoltaic, energy storage, wind power, biomass, demand side management and efficiency technologies. ERA is fully supported by its Australian partners with operations across Australia, Myanmar and India and has an experienced team devoted to delivering renewable energy projects across residential, commercial and sub utility sectors. We bring investments, technology, experience and proven performance to the Philippines, ensuring that any renewable energy developments will be designed, engineered and constructed to the highest standards as determined by the Philippine, German and Australian CEC (Clean Energy Council).


Table of Contents

Company Profile ..................................................................................................................... 3

Introduction ........................................................................................................................... 5

Project Summary .................................................................................................................... 6 Cash Flow Projection ............................................................................................................................................................. 7 40 kWp ............................................................................................................................................................................................ 7 60 kWp ............................................................................................................................................................................................ 8 80 kWp ............................................................................................................................................................................................ 9

Project Design ........................................................................................................................................................................... 10 Factor Performance ............................................................................................................................................................... 10

Appendix A ............................................................................................................................ 11 Operations and Maintenance (O&M) .......................................................................................................................... 12 Annual O&M Expense ........................................................................................................................................................ 15 Renewable Energy Project Incentives ......................................................................................................................... 15 Project Methodology ............................................................................................................................................................ 15

Appendix B ............................................................................................................................ 31 In-‐House Financing ................................................................................................................................................................. 32 30% Down Payment ............................................................................................................................................................... 32 20% Down Payment ............................................................................................................................................................... 33 10% Down Payment ............................................................................................................................................................... 34 0% Down Payment .................................................................................................................................................................. 35


Introduction ERA, Energy Renewables Asia, Inc., is proposing this 40 kWp solar system to help supply Santiago City Hall’s (CLIENT) initial energy needs. The site needs an estimated 40 kWp system, focusing on the optimum output south-facing side of the site. This proposal will showcase this system size along with 60 kWp and 80 kWp. The proposal will generate its financial findings based on an average rate of PHP 10 /kWh by its public utility. Other factors including inflation, degradation, and the like, present projections, which are on a worst-case basis. The installation of a solar photovoltaic system is a more than viable alternative; financially and especially environmentally, to the current energy situation of the company. This preliminary proposal presents the financial, technical and engineering aspects of the project. Project Timeline Action By Duration ETC Finalise commercial and technical approach with client

Client 4 weeks TBA

Finalise financing and contract documentation and procurement arrangements

ERA 6 weeks TBA

Registration of project with DOE (For R.A. 9513 incentives)

DOE 1 month TBA

Procurement, transport customs and components to site

ERA 6 weeks TBA

Installation and commissioning

ERA 20 weeks TBA


Project Summary ERA Partner/Client CLIENT Location Santiago City Hall Panel Capacity 40 kWp Type Grid-tied Project Cost PHP 3,908,781.82 VAT PHP 469,053.82 O&M Expense (per annum) PHP 78,175.64 Project Life 25 Years Project IRR 20.84% Energy Output 67,396.81 kWh Panel Capacity 60 kWp Project Cost PHP 5,714,721.82 VAT PHP 685,766.62 O&M Expense (per annum) PHP 114,294.44 Project IRR 21.35% Energy Output 101,095.22 kWh Panel Capacity 80 kWp Project Cost PHP 7,619,629.09 VAT PHP 914,355.49 O&M Expense (per annum) PHP 152,392.58 Project IRR 21.35% Energy Output 134,793.63 kWh The proposal will take on the System-Supply-Installation (SSI) approach – assuming an outright purchase of the system to be made by CLIENT from their own balance sheet. A bank loan projection and In-House Financing (IHF) options are then discussed in Appendix B. The following sections will look at the return-on-investments of these different project sizes and their corresponding calculations.


Cash Flow Projection The revenue structure specifies the energy rate and annual rate increase escalation factor that is used to calculate the cost avoidance cash flow value of the system. The value proposition to the customer is to achieve energy savings through a Power Supply Agreement (PSA) at a rate more economical than current energy costs levied by the local energy distributor. The following table reflects estimated current consumption levels and costs together with projected solar generation and energy cost avoidance to produce a forecast of the costs remaining, which will be invoiced from the public utility, based on a 40, 60, 80 kWp solar system.

40 kWp

0 (3,908,781.82),,,,,,,,,,,1 67,396.81,,,,,,,,,, 10.00, 673,968.13,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 673,968.13,,,,,,,,,, (3,234,813.69),,,,,,,,,,,2 66,722.85,,,,,,,,,, 10.30, 687,245.30,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 687,245.30,,,,,,,,,, (2,547,568.38),,,,,,,,,,,3 66,055.62,,,,,,,,,, 10.61, 700,784.04,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 700,784.04,,,,,,,,,, (1,846,784.35),,,,,,,,,,,4 65,395.06,,,,,,,,,, 10.93, 714,589.48,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 714,589.48,,,,,,,,,, (1,132,194.86),,,,,,,,,,,5 64,741.11,,,,,,,,,, 11.26, 728,666.90,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 728,666.90,,,,,,,,,, (403,527.97),,,,,,,,,,,,,6 64,093.70,,,,,,,,,, 11.59, 743,021.63,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 743,021.63,,,,,,,,,, 339,493.67,,,,,,,,,,,,,,7 63,452.76,,,,,,,,,, 11.94, 757,659.16,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 757,659.16,,,,,,,,,, 1,097,152.82,,,,,,,,,,,,8 62,818.23,,,,,,,,,, 12.30, 772,585.04,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 772,585.04,,,,,,,,,, 1,869,737.87,,,,,,,,,,,,9 62,190.05,,,,,,,,,, 12.67, 787,804.97,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 787,804.97,,,,,,,,,, 2,657,542.84,,,,,,,,,,,,10 61,568.15,,,,,,,,,, 13.05, 803,324.73,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 803,324.73,,,,,,,,,, 3,460,867.57,,,,,,,,,,,,11 60,952.47,,,,,,,,,, 13.44, 819,150.22,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 819,150.22,,,,,,,,,, 4,280,017.79,,,,,,,,,,,,12 60,342.95,,,,,,,,,, 13.84, 835,287.48,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 835,287.48,,,,,,,,,, 5,115,305.28,,,,,,,,,,,,13 59,739.52,,,,,,,,,, 14.26, 851,742.65,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 851,742.65,,,,,,,,,, 5,967,047.92,,,,,,,,,,,,14 59,142.12,,,,,,,,,, 14.69, 868,521.98,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 868,521.98,,,,,,,,,, 6,835,569.90,,,,,,,,,,,,15 58,550.70,,,,,,,,,, 15.13, 885,631.86,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 885,631.86,,,,,,,,,, 7,721,201.76,,,,,,,,,,,,16 57,965.19,,,,,,,,,, 15.58, 903,078.81,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 903,078.81,,,,,,,,,, 8,624,280.57,,,,,,,,,,,,17 57,385.54,,,,,,,,,, 16.05, 920,869.46,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 920,869.46,,,,,,,,,, 9,545,150.03,,,,,,,,,,,,18 56,811.68,,,,,,,,,, 16.53, 939,010.59,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 939,010.59,,,,,,,,,, 10,484,160.62,,,,,,,,,,19 56,243.57,,,,,,,,,, 17.02, 957,509.10,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 957,509.10,,,,,,,,,, 11,441,669.72,,,,,,,,,,20 55,681.13,,,,,,,,,, 17.54, 976,372.03,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 976,372.03,,,,,,,,,, 12,418,041.75,,,,,,,,,,21 55,124.32,,,,,,,,,, 18.06, 995,606.56,,,,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 995,606.56,,,,,,,,,, 13,413,648.30,,,,,,,,,,22 54,573.08,,,,,,,,,, 18.60, 1,015,220.01,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,015,220.01,,,,,,,, 14,428,868.31,,,,,,,,,,23 54,027.35,,,,,,,,,, 19.16, 1,035,219.84,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,035,219.84,,,,,,,, 15,464,088.15,,,,,,,,,,24 53,487.07,,,,,,,,,, 19.74, 1,055,613.67,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,055,613.67,,,,,,,, 16,519,701.82,,,,,,,,,,25 52,952.20,,,,,,,,,, 20.33, 1,076,409.26,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,076,409.26,,,,,,,, 17,596,111.08,,,,,,,,,,

Year Total)Revenue Total)Expenses Project)Cash)FlowCumulative)Cash)

FlowSolar)Generation Rate


60 kWp

0 (5,714,721.82),,,,,,,,,,,1 101,095.22,,,,,,,,, 10.00, 1,010,952.20,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,010,952.20,,,,,,,, (4,703,769.62),,,,,,,,,,,2 100,084.27,,,,,,,,, 10.30, 1,030,867.96,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,030,867.96,,,,,,,, (3,672,901.66),,,,,,,,,,,3 99,083.42,,,,,,,,,, 10.61, 1,051,176.06,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,051,176.06,,,,,,,, (2,621,725.61),,,,,,,,,,,4 98,092.59,,,,,,,,,, 10.93, 1,071,884.22,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,071,884.22,,,,,,,, (1,549,841.39),,,,,,,,,,,5 97,111.66,,,,,,,,,, 11.26, 1,093,000.34,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,093,000.34,,,,,,,, (456,841.04),,,,,,,,,,,,,6 96,140.55,,,,,,,,,, 11.59, 1,114,532.45,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,114,532.45,,,,,,,, 657,691.41,,,,,,,,,,,,,,7 95,179.14,,,,,,,,,, 11.94, 1,136,488.74,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,136,488.74,,,,,,,, 1,794,180.15,,,,,,,,,,,,8 94,227.35,,,,,,,,,, 12.30, 1,158,877.57,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,158,877.57,,,,,,,, 2,953,057.71,,,,,,,,,,,,9 93,285.08,,,,,,,,,, 12.67, 1,181,707.45,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,181,707.45,,,,,,,, 4,134,765.17,,,,,,,,,,,,10 92,352.23,,,,,,,,,, 13.05, 1,204,987.09,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,204,987.09,,,,,,,, 5,339,752.26,,,,,,,,,,,,11 91,428.70,,,,,,,,,, 13.44, 1,228,725.34,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,228,725.34,,,,,,,, 6,568,477.60,,,,,,,,,,,,12 90,514.42,,,,,,,,,, 13.84, 1,252,931.23,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,252,931.23,,,,,,,, 7,821,408.82,,,,,,,,,,,,13 89,609.27,,,,,,,,,, 14.26, 1,277,613.97,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,277,613.97,,,,,,,, 9,099,022.79,,,,,,,,,,,,14 88,713.18,,,,,,,,,, 14.69, 1,302,782.97,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,302,782.97,,,,,,,, 10,401,805.76,,,,,,,,,,15 87,826.05,,,,,,,,,, 15.13, 1,328,447.79,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,328,447.79,,,,,,,, 11,730,253.55,,,,,,,,,,16 86,947.79,,,,,,,,,, 15.58, 1,354,618.21,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,354,618.21,,,,,,,, 13,084,871.77,,,,,,,,,,17 86,078.31,,,,,,,,,, 16.05, 1,381,304.19,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,381,304.19,,,,,,,, 14,466,175.96,,,,,,,,,,18 85,217.53,,,,,,,,,, 16.53, 1,408,515.88,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,408,515.88,,,,,,,, 15,874,691.84,,,,,,,,,,19 84,365.35,,,,,,,,,, 17.02, 1,436,263.65,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,436,263.65,,,,,,,, 17,310,955.49,,,,,,,,,,20 83,521.70,,,,,,,,,, 17.54, 1,464,558.04,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,464,558.04,,,,,,,, 18,775,513.53,,,,,,,,,,21 82,686.48,,,,,,,,,, 18.06, 1,493,409.83,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,493,409.83,,,,,,,, 20,268,923.36,,,,,,,,,,22 81,859.62,,,,,,,,,, 18.60, 1,522,830.01,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,522,830.01,,,,,,,, 21,791,753.37,,,,,,,,,,23 81,041.02,,,,,,,,,, 19.16, 1,552,829.76,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,552,829.76,,,,,,,, 23,344,583.13,,,,,,,,,,24 80,230.61,,,,,,,,,, 19.74, 1,583,420.51,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,583,420.51,,,,,,,, 24,928,003.64,,,,,,,,,,25 79,428.30,,,,,,,,,, 20.33, 1,614,613.89,,,,,, .,,,,,,,,,,,,,,,,,,,,,,,,,,,,, 1,614,613.89,,,,,,,, 26,542,617.53,,,,,,,,,,




80 kWp

0 (7,619,629.09)+++++++++++1 134,793.63+++++++++ 10.00+ 1,347,936.26++++++ .+++++++++++++++++++++++++++++ 1,347,936.26++++++++ (6,271,692.83)+++++++++++2 133,445.69+++++++++ 10.30+ 1,374,490.61++++++ .+++++++++++++++++++++++++++++ 1,374,490.61++++++++ (4,897,202.22)+++++++++++3 132,111.23+++++++++ 10.61+ 1,401,568.07++++++ .+++++++++++++++++++++++++++++ 1,401,568.07++++++++ (3,495,634.14)+++++++++++4 130,790.12+++++++++ 10.93+ 1,429,178.96++++++ .+++++++++++++++++++++++++++++ 1,429,178.96++++++++ (2,066,455.18)+++++++++++5 129,482.22+++++++++ 11.26+ 1,457,333.79++++++ .+++++++++++++++++++++++++++++ 1,457,333.79++++++++ (609,121.39)+++++++++++++6 128,187.40+++++++++ 11.59+ 1,486,043.27++++++ .+++++++++++++++++++++++++++++ 1,486,043.27++++++++ 876,921.88++++++++++++++7 126,905.52+++++++++ 11.94+ 1,515,318.32++++++ .+++++++++++++++++++++++++++++ 1,515,318.32++++++++ 2,392,240.19++++++++++++8 125,636.47+++++++++ 12.30+ 1,545,170.09++++++ .+++++++++++++++++++++++++++++ 1,545,170.09++++++++ 3,937,410.28++++++++++++9 124,380.10+++++++++ 12.67+ 1,575,609.94++++++ .+++++++++++++++++++++++++++++ 1,575,609.94++++++++ 5,513,020.22++++++++++++10 123,136.30+++++++++ 13.05+ 1,606,649.46++++++ .+++++++++++++++++++++++++++++ 1,606,649.46++++++++ 7,119,669.68++++++++++++11 121,904.94+++++++++ 13.44+ 1,638,300.45++++++ .+++++++++++++++++++++++++++++ 1,638,300.45++++++++ 8,757,970.13++++++++++++12 120,685.89+++++++++ 13.84+ 1,670,574.97++++++ .+++++++++++++++++++++++++++++ 1,670,574.97++++++++ 10,428,545.10++++++++++13 119,479.03+++++++++ 14.26+ 1,703,485.30++++++ .+++++++++++++++++++++++++++++ 1,703,485.30++++++++ 12,132,030.39++++++++++14 118,284.24+++++++++ 14.69+ 1,737,043.96++++++ .+++++++++++++++++++++++++++++ 1,737,043.96++++++++ 13,869,074.35++++++++++15 117,101.40+++++++++ 15.13+ 1,771,263.72++++++ .+++++++++++++++++++++++++++++ 1,771,263.72++++++++ 15,640,338.07++++++++++16 115,930.38+++++++++ 15.58+ 1,806,157.62++++++ .+++++++++++++++++++++++++++++ 1,806,157.62++++++++ 17,446,495.69++++++++++17 114,771.08+++++++++ 16.05+ 1,841,738.92++++++ .+++++++++++++++++++++++++++++ 1,841,738.92++++++++ 19,288,234.61++++++++++18 113,623.37+++++++++ 16.53+ 1,878,021.18++++++ .+++++++++++++++++++++++++++++ 1,878,021.18++++++++ 21,166,255.79++++++++++19 112,487.14+++++++++ 17.02+ 1,915,018.20++++++ .+++++++++++++++++++++++++++++ 1,915,018.20++++++++ 23,081,273.98++++++++++20 111,362.26+++++++++ 17.54+ 1,952,744.05++++++ .+++++++++++++++++++++++++++++ 1,952,744.05++++++++ 25,034,018.04++++++++++21 110,248.64+++++++++ 18.06+ 1,991,213.11++++++ .+++++++++++++++++++++++++++++ 1,991,213.11++++++++ 27,025,231.15++++++++++22 109,146.16+++++++++ 18.60+ 2,030,440.01++++++ .+++++++++++++++++++++++++++++ 2,030,440.01++++++++ 29,055,671.16++++++++++23 108,054.69+++++++++ 19.16+ 2,070,439.68++++++ .+++++++++++++++++++++++++++++ 2,070,439.68++++++++ 31,126,110.84++++++++++24 106,974.15+++++++++ 19.74+ 2,111,227.34++++++ .+++++++++++++++++++++++++++++ 2,111,227.34++++++++ 33,237,338.18++++++++++25 105,904.41+++++++++ 20.33+ 2,152,818.52++++++ .+++++++++++++++++++++++++++++ 2,152,818.52++++++++ 35,390,156.70++++++++++




Project Design

Factor Performance With the CLIENT property occupying a substantial amount of land in Isabela, space is not a problem for the amount of energy we are expecting to produce. For a system of 80 kWp, we are to install 308 (260 watt) panels in an area of 653 sqm at a 1.3x spacing factor – eliminating the probability of one panel shading another panel. With this, we see the annual energy output is at a derated 134,794 kWh. The Derating Factor Adjustment used is 81.67% to account for generation losses provided by our suppliers. The roof is estimated to be around 800 sqm. The maximum proposed of 80 kWp will fit, allowing for the smaller systems to fit as well.

Rated&Output Height Length Spacing&Factor260&w 1,650&mm 990&mm 1.3&x

Number&Panels Area&(Sqm) Energy&/KW&P.A. Daily&Energy Annual&Energy Total&Energy308&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&& 653&&&&&&&&&&&& 2.06&KWh &MWh 165&MWh 4,126&MWh

Derate&Factors Modifier Annual&Adj

&&&&PV&module&nameplate&DC&rating 97.00% 4,951&&&&&&&&&&&&&&&&&&&Inverter&and&Transformer 98.00% 3,301&&&&&&&&&&&&&&&&&&&Mismatch 98.00% 3,301&&&&&&&&&&&&&&&&&&&Diodes&and&connections 98.00% 3,301&&&&&&&&&&&&&&&&&&&DC&wiring 97.00% 4,951&&&&&&&&&&&&&&&&&&&AC&wiring 97.00% 4,951&&&&&&&&&&&&&&&&&&&Soiling 99.00% 1,650&&&&&&&&&&&&&&&&&&&System&availability 98.00% 3,301&&&&&&&&&&&&&&&&&&&Shading 98.00% 3,301&&&&&&&&&&&&&&&&&&&Sun\tracking 100.00% \&&&&&&&&&&&&&&&&&&&Derate&Factor&Adjustment 81.67% 30,246&&&&&&&&&&&&&&&Estimated&Generation&(KWh) 1,684.92&&&&&&&&&& 134,794&&&&&&&&&&&&&

Cumulative&Annual&Degradation 1.00% 1,348&&&&&&&&&&&&&&&&

82,520&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&82,520&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&

Design&and&PerformanceFactors

756,153&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&3,369,840.66&&&&&&&&&&&&&&&&&&&&&&&&&&&

33,698.41&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&

Project&Energy&Adj&(KWh)

123,780&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&82,520&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&82,520&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&82,520&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&

\&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&

Solar&Radiation5.65&KWh/m2/Day

123,780&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&123,780&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&41,260&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&&


Appendix A Operations and Maintenance (O&M) .......................................................................................................................... 12 Annual O&M Expense ........................................................................................................................................................ 15 Renewable Energy Project Incentives ......................................................................................................................... 15 Project Methodology ............................................................................................................................................................ 15


Operations and Maintenance (O&M)

ERA strives to ensure an effective PV installation, for an expected lifetime to be 25 years or more, so safe and proper maintenance is an integral part of successful and reliable operation. Safety, maximizing return on investment (ROI) and system production, system uptime are the key O&M objective. For example, inverters that are offline can have a dramatic negative impact on the ROI of a PV system. Inverter failure rates are important to ROI, but equally or even more important than how often an inverter goes offline is how quickly it can be placed back into service. Diagnosing and correcting power production deficiencies is also important to maximizing availability of system components and ROI. ERA has developed a detailed and robust methodology based on the numerous system installations it has completed and operated in Australia and South East Asia. ERA, through its Makati office will continually monitor system performance remotely and will provide its team and the client up to the minute system performance and operational data. Following is an outline of the ERA O&M Operations and Procedures guide. A draft is provided as part of the System Supply and Installation Agreement and refined during the commissioning phase to ensure reporting procedures are relevant to the needs of the project.

ROUTINE SCHEDULED PREVENTIVE MAINTENANCE • General Site Annual Inspection • Detailed Visual Inspection • Inverter Inspection • Tracker Inspection • Manufacturer-Specific Data Acquisition System Inspection

GENERAL ISOLATION PROCEDURES • Energized Components • Inverter Pad Equipment • Transformer Isolation

FAILURE RESPONSE • Emergency Shutdown • Isolation Procedure—Inverter Pad Equipment • Isolation Procedure—Field Combiner Box • Isolation Procedure—Modules and String Wiring


INVERTER TROUBLESHOOTING AND SERVICING • Inverter Troubleshooting • Inverter Service Procedures

DIAGNOSING AND TESTING FOR LOW POWER PRODUCTION • Diagnostic Testing • Infrared (IR) Image Procedure • Megohmmeter Testing • Fuse Checks • DC System Voc Checks • DC System Imp Checks • Grounding System Integrity Checks • DAS Check • Ground Fault Troubleshooting • Array Washing Procedure • Vegetation Management • System Warranties

The System Portal The system portal is designed to display the most relevant information of a photovoltaic system at a glance. However, it is possible to refine the data and go into detail with a click.


Summary of the Real Time Monitor functions: • “General Properties”: Information about the owner, the system and the hardware • “Yield table”: Information about the current energy yield of the system (day,

month, year) • Photo or webcam image of the site • Monitoring chart of the previous day (the interactive monitoring tool is started

with a click) • Monitoring chart of the current month • Monitoring chart of the current year • Weather information • Module performance overview of the previous day (depending on the monitoring

solution) • Logo of the solar installer or technical service contact

Automatic Failure Detection and System Notification ERA utilises an intelligent Failure Detection Engine, the whole photovoltaic system can be monitored for proper functioning. Not only inverter problems are detected, but also cabling errors and performance issues. These are common failures frequently occurring during day-to-day operations of a PV system. Through the commissioning phase ERA will work with client sight operations to determine a system even communication protocol. Only important and desirable warning messages are to be reported. Smart Monitor features uniquely clear error messages. ERA prefers to limit meaningless warnings – Each message explains each failure in respect of its cause and location and provides a checklist to tackle the problem. Smart Control features the first automatic failure detection engine going considerably beyond a simple threshold-driven detection approach. Thereby, Smart Control enables the detection of gradual failures as well as partial loss of performance.

Failure Detection characteristics • Continuous analysis of parameters of the whole PV system • Analysis of UI- characteristic curves at regular intervals for all modules • Automatic notification in case of a failure, with detailed information about the

location, about most probable cause of the failure and potential solutions.” • Health-Check-Report“ (on a daily, weekly or monthly basis) • E-Mail or SMS-Notification • Generation of module „fingerprints“ in order to detect slow degradation defects


Annual O&M Expense In the IHF schemes found in Appendix B, the lender will require CLIENT to have an annual maintenance and upkeep agreement with ERA for the system to continuously perform at its peak and ensure payback of the system is achieved – as an after sales agreement. The annual Operations & Upkeep fee amounts to 2% of the contract price. This is inclusive of 24/7 panel monitoring: analyst services, technical assistance, engineering services, and whatever else is needed to generate the best results from the installation.

Renewable Energy Project Incentives

Pursuant to Section 33 of Republic Act No. 9513, otherwise known as The Renewable Energy Act of 2008, the Department of Energy, issued new rules and regulations in relation to entitlement of the following incentives for RE projects:

1. Special Realty Tax Rates on Equipment and Machinery 2. Net Operating Loss Carry-Over (NOLCO) 3. Accelerated Depreciation – 10 Years

ERA is very well conversant in the processes and procedures for engaging the Department of Energy (DOE), Board of Investments (BOI) and the Energy Regulatory Commission (ERC). The project will be registered by ERA as an RE-Development project. The process of registration will take up to 3 months, accordingly ERA recommends commencing the registration process as soon as possible.

Project Methodology

Following in an extract from ERA’s project design and planning methodology. ERA will determine components, materials and suppliers only after a detailed project assessment and the determination of site location and network connection requirements. The outline, which follows, will hopefully provide The Client a firm understanding of the issues and considerations that are necessary. Where The Client and local authorities require, ERA is committed to ensuring that all project elements confirm to local standards and regulations. 1. PHOTOVOLTAIC MODULES

1.1. GENERAL

The general philosophy behind the design of the system will be to maximise energy output within the space available but always at reasonable cost. Our design philosophy is to use the best products for a given site and application. Our extensive


experience has taught us that each site has unique elements that in some cases favour particular technologies. When considering a particular photovoltaic solar product, the key factors that go into our decision matrix include: • Area Availability • Energy Yield • Climatic Conditions • Module Degradation • Embodied Energy • End of Life Recycling • Performance Tolerance • Product Bankability • Cost

1.2. SCOPE

• Sizing of the PV array to provide the specified capacity. • Layout of the PV arrays and external inverter enclosures to the site plan. • Liaison with the Electrical Key person for ERA for the installation works to

provide connection capability at local distribution boards with suitable load demands

• Liaison with the Electrical Key person for ERA to provide capability for grid export when PV output exceeds the site demand.

• Supply and install modelled quantity of PV panels including framing and support.

• Install PV modules at nominated tilt angle and as agreed with the structural engineer.

• Supply and Installation of DC power cabling reticulation and safety devices from module arrays to inverter/s.

• Supply and install inverters in externally rated IP rated cabinet or externally in shaded cool location as appropriate to their performance requirements and terminate AC cabling from the main switchboard (by coordination with electrical key person for ERA)

• Supply and install safety and ancillary equipment • ERA venders shall supply relevant size, weight and other structural element

data applicable to the PV to the architect and/or structural engineer for co-ordination

• Structural performance of panels and mounting systems shall be to cyclone wind region ‘D’ area to AS1170.2 (Wind Code) and Impact Resistance to AS1170.2 Cl 2.5.7. ERA venders shall engage a structural engineer to certify that the PV systems may be soundly supported on any roofing. Where applicable,


provide structural documented advice on the weight bearing capacity, lateral load capacity and capacity for resistance to uplift of the roof. Ensure that the solar panel installation does not compromise the structural capacity of any roofs.

1.3. APPROVED MANUFACTURER The PV key person for ERA may use any manufacturer of PV panels which will produce the desired annual output and for which the installer has confidence in their long term outputs and integrity. Panels will also need to fit onto the space allowed for onsite and according to the plans. The following information will be provided to The Client upon request: • picture of module appearance • type of crystalline structure (eg: polycrystalline, monocrystalline) • electrical characteristics (eg: Pmax(W), Vpm, Ipm, Voc, Isc, coefficient of

voltage, coefficient of power) • structural loading data eg: thickness of glass and weight • electrical inverter and connection details, and • Impact and wind resistance certification • Other information as required.

PV modules shall comply with IEC61215 or IEC61646 and should be should be Class II. Class II is defined in clause 1.4.8. The normative reference to IEC 61829 is for information only. Alternative PV manufacturers must be approved by the persons in persons named in section E1.1.2 prior to the procurement of the equipment. Products that are relatively new to the market should be selected on the basis that they comply with standards, have been shown to be free of defects and have undergone design developments to eradicate any known design flaws, which could otherwise substantially impede their expected performance. Installers must be confident in the short term and long term performance of the panels nominated in the proposal.

2. MOUNTINGS 2.1. GENERAL

The azimuth angle of the array shall be to suit the buildings on site and south facing. The modules shall be located and positioned in such a way as to maximise annual output and avoid shading from adjacent structures, adjacent panels and trees.


2.2. SCOPE

The ERA venders shall supply a price for the following scope of works in regard to mounting: • The installation of the mounting system of the metal deck roof • The installation of the PV modules on the mounting system • Provision of structural engineers advice to certify that the PV systems may be

soundly supported on the roof

2.3. MOUNTAIN SYSTEM SPECIFICATIONS

• The mounting structures shall be of fixed type but may have allowance for thermal expansion

• The mounting frame shall be constructed of non-corrosive materials such as aluminium, fibre glass or stainless steel. Metal connections must not have anodic corrosive reactions.

• Dissimilar metallic materials shall be isolated from one another; for example an aluminium frame shall be isolated from stainless steel bolts to prevent corrosion via electrolysis using special washers

• Structural performance of panels and mounting systems shall be to cyclone wind region ‘D’ area to AS1170.2 (Wind Code) and Impact Resistance to AS1170.2 Cl 2.5.7. ERA venders shall engage a structural engineer to certify that the PV systems may be soundly supported on the roof. Source structural advice on the weight bearing capacity, lateral load capacity and capacity for resistance to uplift of the roof. Ensure that the solar panel installation does not compromise the structural capacity of the roofs.

• The warranty of the mounting system shall be equal or greater than 10 (ten) years

• The mountings shall be as Montavent or equal and approved.

3. INVERTERS 3.1. GENERAL

3.2. SCOPE

• Install grid connect inverters to provide electrical connection of the PV modules

to the low voltage distribution network • Connect the inverter to the AC network • Provide suitable mounting, location and installation of inverters in

collaboration with • architect and electrical key person for ERA


• ERA venders is to notify and confirm final location of Inverters with Head Key person for ERA prior to installation

• ERA venders is to notify and confirm final location of connection point of inverters to LV network prior to installation

3.3. INVERTER REQUIREMENTS

The inverter shall comply with the following requirements: • ERA venders is to confirm adequacy of proposed inverters with respect to

capacity and suitability for PV system • ERA venders is to confirm that the DC operating voltage window of the

inverters is not exceeded • ERA venders are to confirm that the current limits of the inverters are not

exceeded. • A separate, external manual isolation switch shall be installed next to the

inverters to provide isolation of the inverter/s from the LV network • The inverter shall be sized appropriately for the maximum module peak power

rating. • Due consideration shall be given to the performance of the inverter during high

ambient temperatures. The tender shall make themselves aware of the temperature conditions of the Philippines and shall select inverters and inverter locations appropriately so as not to compromise the output of the array.

• Strong local support in the Philippines. • The inverter shall have at least one maximum power point tracker • The inverter shall have a written warranty on parts and defects of at least 5

years • The inverter shall be 3 phase. • All equipment to be suitably labelled • Inverters must comply with AS 4777.1 - 2002 Grid connection of energy systems

via inverters Part 1: Installation requirements. AS 4777.2 - 2002 Grid connection of energy systems via inverters Part 2: Inverter Requirements. AS 4777.3 - 2002 Grid connection of energy systems via inverters Part 1: Grid protection requirements.

• Inverters must be approved and listed by the Clean Energy Council of Australia.

• Targeted CEC efficiency should exceed 98% 3.4. PRIOR TO INSTALLATION

The following practices shall be followed during installation: • The inverters shall not be placed in direct sunlight • If an enclosure is used, the inverter enclosure shall be have an IP rating of 65 if

installed outdoors or IP 45 if installed in an indoor dry space. It must also be


ensured that the ventilation air requirements for the inverter are met. Outdoor installation of the inverters is acceptable if this would improve their performance and they are well protected and tolerant to weather conditions.

3.5. INVERTER

The chosen inverter for the project is selected due to its robust operation and high voltage range tolerance to cope with both variable grid and local diesel generation supply operation. Another important factor is a strong local presence and market presence in the Philippines high, medium and low voltage distribution, transformer, substation and switchboard markets. This inverter will be tested and approved to AS4777 standard.

4. WIRING AND SAFETY DEVICES 4.1. E5.1 WIRING SYSTEMS

The wiring for PV arrays shall be arranged to minimise the possibility of line-to-line and earth to line faults occurring.

4.1.1. E5.1.1 DC Wiring loops

As in accordance with AS/NZS 5033:2005, the PV DC wiring should be laid in such a way that the area of conductive loops is minimised.

4.1.2. E5.1.2 DC String wiring If the wiring of PV strings between modules is not in conduit, all the following shall apply: • Insulated and sheathed cables shall be used • Cables shall be protected from mechanical damage • Cables shall be clamped (to relieve tension and to prevent conductors coming

free from connections)

4.1.3. E5.1.3 Wiring installation in junction boxes

The following provisions apply to the installation of wiring systems in junction boxes: • Where conductors enter a junction box without conduit, a tension relief system

shall be used to avoid cable disconnections inside the junction box (for example by using a gland connector).

• All cable entries shall maintain the IP rating of the enclosure. • For LV PV arrays, where a return conductor is routed through module junction

boxes, such return conductor(s) shall be a single-core double-insulated cable,


and the cable and its insulation shall maintain double insulation status over its entire length, particularly through junction boxes (i.e. these provisions also apply to the joints, if any).

4.1.4. E5.1.4 Location of PV array and PV sub-array junction boxes

PV array and PV sub-array junction boxes, where installed, shall be readily available.

4.1.5. E5.1.5 Selection of Cables

Use the following systems: • Cast concrete slabs: Thermoplastic sheathed or unsheathed cable in heavy duty

UPVC conduit. • Accessible spaces: Thermoplastic sheathed cable. • Concealed spaces: Thermoplastic sheathed or unsheathed cable in UPVC

conduit. • Plant rooms: Thermoplastic sheathed or unsheathed cable in heavy duty UPVC

conduit. • Stud walls without bulk insulation: Thermoplastic sheathed cable. • ERA venders shall ensure that the DC voltage drop does exceed 1% • ERA venders shall ensure that the AC voltage drop does exceed 1%

4.1.6. E5.1.6 Cable Standards

• Conductors: To AS 1125. • Selection of cables: To AS 3008.1. • Elastomer insulated cables: To AS 3116. • PVC insulated cables: To AS 3147. • Silicone rubber insulated cables: To AS 3178. • Flexible cords: To AS 3191. • XPLE cables: To AS 3198.

4.1.7. E5.1.7 Cable Selection

For both AC and DC cables the following standards apply: • AS 3000 and AS 3008.1. AS 3012 for construction and demolition sites. • Use AS 3008.1 for the determination of current ratings and voltage drop. • Use multi-stranded copper conductors. • Minimum size: To AS 3000 Clause 3.3. • Unless otherwise specified use cable with insulation as appropriate to

application.


• During the DC cable selection process the tender shall insure that the selected DC cable is suitable for the DC operating voltage.

4.1.8. E5.1.8 Cable Installation

• Install, terminate and joint cables in accordance with manufacturers' recommendations.

• Remove redundant equipment and wiring, including that in accessible ceiling spaces, and make good exposed surfaces before commencing the installation of new wiring.

• Handle cables so as to avoid damage to insulation and serving or sheathing. Report all damage and replace or repair damaged cable as directed.

• Unless unavoidable due to length or difficult installation conditions, run cables for their entire route length without intermediate straight-through joints. Locate approved joints as directed.

• Cable joints: Locate in accessible positions in junction boxes. • Identify the origin of all wiring using legible indelible marking. • Install and adequately support fixed wiring as specified throughout the

installation. For cabling routes not specified in detail, submit a proposed route layout.

• Where TPS cables are installed in accessible locations concealed from view, or within suspended ceiling spaces, secure them to the roof framing, slab or softwood battens with approved clips, straps, clamps, or saddles located as close to the slab soffit as practicable. Cables shall not be secured to ceiling suspension system.

• Support all cables at a maximum of 1200 mm spacing with minimum sag.

4.1.9. E5.1.9 Conductors

AC conductors For AC fixed wiring colour the conductor insulation or, if this is not practicable, slide not less than 150 mm of close fitting coloured sleeving to each conductor at the termination points as follows: • Active conductors in single phase circuits: red. • Active conductors in polyphase circuits:

• A phase - red • B phase - white • C phase – blue

• Other conductors: To AS 3000 clause 3.2.


Identify multicore cables and trefoil groups at each end and at crowded intermediate points by means of stamped, non-ferrous tags, clipped around each cable, or trefoil group.

DC Conductors (power network)

For fixed DC wiring for power networks; wiring colour the conductor insulation or, if this is not practicable, slide not less than 150 mm of close fitting coloured sleeving to each conductor at the termination points as follows: • Positive conductors: Red. • Negative Conductors: Black • Ground Conductors: Yellow and Green

4.1.10. E5.1.10 Single Insulated Wiring in Conduit

• Complete and permanently fix the conduit run before installing the wiring. Use draw wires to pull in the conductor groups from outlet to outlet.

• Do not make conductor joints in through-runs of cables unless approved. Install boxes containing joints in accessible locations.

• For vertical conduit runs in excess of 15 m make adequate provision for supporting the weight of the wiring to avoid insulation damage.

• Replace all wiring in conduits containing conductors with insulation damaged during installation, after determining and removing the cause of damage.

4.1.11. E5.1.11 Conductor Terminations

• Unless otherwise approved, terminate copper conductors to equipment, other than small accessory and luminaire terminals, by means of compression-type lugs of the correct size for the conductor, compressed only by the correct tool.

• Within switchboards and equipment: Loom and lace together, with PVC straps or string, all conductors from within the same cable or conduit from the point of cable sheath or conduit termination to the terminal block.

• Neatly bend each conductor to enter directly into the terminal tunnel or terminal stud section, allowing sufficient slack for easy disconnection and Reconnection.

• Where core identification is required, fit to each core durable numbered ferrules permanently engraved with numbers and/or letters to suit the specified connection diagrams.

• Terminate and identify any spare cores into spare terminals, if available; otherwise neatly insulate and bind with PVC string, the spare cores to the terminated cores.

4.2. E5.2 CABLE SUPPORT SYSTEMS


4.2.1. E5.2.1 Conduits

Standards: • Galvanized steel water pipe: To AS 1074. • Metallic conduit and fittings: To AS 2052. • Non-metallic conduits and fittings: To AS 2053. • Minimum sizes: • Metallic and non-metallic conduits: 20 mm. • Galvanized water pipe: Medium or heavy tube to AS 1074, 20 mm nominal

bore.

Provide two fixings per conduit saddle. Do not use explosive-powered or similar equipment unless approved. • To woodwork: Conduit matching saddles and round head cadmium-plated

steel wood screws. • To masonry: Conduit matching saddles and round head cadmium-plated steel

screws screwed into expanded lead or other proprietary type plugs neatly fitting into drilled holes.

• To steelwork: Cadmium-plated steel metal-thread screws. Drill and tap the steelwork for each saddle.

Installation: • Fix conduit saddles at a maximum of 1 m intervals in horizontal runs and 2 m

intervals in vertical runs. Ensure that installed conduits are fully supported during construction.

• Protect UPVC conduits installed in accessible roof spaces and the like by timber battens.

• Up to the commercially obtainable conduit lengths of run, install conduits without joints.

• Remove all rags, burrs, and sharp edges from each length before completing each conduit joint. Fit moulded plastic screwed bushes to the free ends of metallic conduit runs before installing the conductors.

• Inspection fittings and the like shall be accessible. • Provide draw cords in conduits not in use. Leave 1 m of cord coiled at each end

of the run. • Provide draw-in boxes at suitable intervals not exceeding 30 m in straight runs,

and at intervals not exceeding 25 m in other runs including directional changes. • Fit draw-in boxes installed underground with gasketted covers and seal them

against entry of moisture.

4.2.2. E5.2.2 Concealed Conduits


• Run conduits concealed in wall chases, embedded in floor slabs and installed in

inaccessible locations always by agreement with main building key person for ERA, direct between points of termination with a minimum number of sets. Do not conceal conduit fittings.

• Locate conduits run in concrete slabs entirely within the structural slab. Do not run conduits in the concrete topping unless approved.

• Steel conduit shall be galvanized if run in concrete slabs. • Fix conduits directly to the reinforcing where the conduits pass above a single

layer of reinforcing, or fix midway between double layers of reinforcing. Route the conduits in slabs so as to avoid crossovers and to keep the number of conduits in any one location to a minimum. Space conduits 75 mm apart in slabs.

• Minimum cover: Conduit diameter or 20 mm. • Conduit size: 25 mm maximum diameter unless agreed otherwise • Ensure that conduits are not displaced, broken, or damaged during concrete

pours. • Hollow-block floors: Locate the conduits in the core-filled sections only of

precast hollow-block type floors. • Do not run conduits in the floor slab of boiler rooms, plant rooms, and tank

rooms.

4.2.3. E5.2.3 Cable Trays and Ladders

General • Bends, connectors, trays, ladders, brackets, and other supports necessary to

make a complete cable or conduit support system shall be of the same manufacture, sized to adequately support the installed cabling.

• Provide sufficient space on the tray or ladder for not less than 10% more cables or conduits than specified.

• Position the support system to give adequate access for inspecting, replacing, or adding cable.

• Fix cable to the support system by proprietary nylon ties, straps or saddles, at 1000 mm centres for vertical runs and 2000 mm centres for horizontal runs.

• Use stainless steel straps on cables supplying fire and essential services. • Provide a slightly curved support surface under cables leaving the tray or cable

ladder to protect the cable sheath from impingement by the tray or ladder edge. • Maintain at least 200 mm clearance from hot water pipes and 500 mm clearance

from boilers or furnaces.

Cable Trays • Galvanize after manufacture to AS 1650. • Minimum steel thickness:


• Trays up to 150 mm wide: 1.0 mm • Trays from 150 mm to 300 mm wide: 1.2 mm • Trays over 300 mm wide: 1.6 mm • Folded edge: Minimum height 20 mm, radiused. • Slotting: Normal or reverse with no burrs or sharp edges on the side to which

cables are attached. • Cable Ladder • Manufacture the cable ladder from two folded steel or extruded structural

grade aluminium side rails with cable support rungs between the two rails spaced at intervals of not more than 300 mm.

• Do not run cables smaller than 13 mm outside diameter on the cable ladder unless continuously supported.

• Slots or ladder rails shall be suitable for fixing cable ties, strapping or saddles. • Bends shall have a minimum inside radius of not less than twelve times the

outside diameter of the largest diameter cable carried.

4.3. SAFETY DEVICES

The term safety devices refers to the following but not limited to: • DC Bypass Diodes • DC Junction Boxes • DC Over current Protection Devices - String Fuses or Circuit Breakers • DC Switches • Ground Fault Detectors • Residual current devices • Earthing • Extra low voltage segmentation • Design guidelines regarding safety requirements in AS 5033:2005 Installation of

Photovoltaic Arrays shall be adhered to.

4.3.1. E5.3.1 DC Bypass Diodes

• Bypass diodes are used to prevent PV modules from becoming reverse-biased, which results in hotspot heating and module lifetime reduction. Bypass diodes shall be rated at 2 times the open circuit voltage and 1.25 times the short circuit current. No live parts should be exposed, and the diodes should be well-protected from the environment. Bypass diodes shall comply with AS 5033:2005 Installation of Photovoltaic Arrays all other relevant standards listed in section E1.3 of this document.

• Note: Blocking diodes are not a reliable protection against reverse current because they often fail in short circuit mode. The use of blocking diodes is currently restricted to preventing battery discharge to an unenergized PV array


at night. Their use should be avoided for other purposes because they are sources of failures and power loss.

4.3.2. E5.3.2 DC Junction Boxes

The junction boxes installed in the PV array shall be compliant to AS 60529 — Degrees of Protection of Enclosures. They must be rated for DC use at 1.2 times the open circuit voltage. Connections must shall with Class II equipment standards. Junction boxes shall comply with AS 5033:2005 Installation of Photovoltaic Arrays all other relevant standards listed in section E1.3 of this document.

4.3.3. E5.3.3 DC Over-current Protection Devices - String Fuses or Circuit Breakers

Unless specified otherwise by the manufacturer of the PV modules, the trip current for string fuses or circuit breakers shall lie within the bounds: 1.25 x short circuit current <rated trip current < 2 X short circuit current Overcurrent protection devices disconnect the circuit in case of a fault condition. These devices serve to protect the system components, prevent fire and protect people from the high current conditions. Overcurrent Protection Devices, String Fuses and Circuit Breakers shall comply with AS 5033:2005 Installation of Photovoltaic Arrays all other relevant standards listed in section E1.3 of this document. All DC over-current protection devices shall have a voltage rating greater than or equal to 1.2 x Voc array.

4.3.4. E5.3.4 Disconnection Devices and DC Switches

Switches used as disconnecting means must be rated for DC at a minimum of 1.2 times the open circuit voltage. Connections must comply with Class II equipment standards. The switch must be capable of interrupting the full load and prospective fault currents from the PV array. A clear ‘on’ and ‘off indicator must be present on the switch. Switches used shall comply with AS 5033:2005 Installation of Photovoltaic Arrays all other relevant standards listed in section E1.3 of this document. Disconnection devices and DC switches shall have a voltage rating greater than or equal to 1.2 x Voc array.

4.3.5. E5.3.5 Ground Fault Detectors

Ground fault detectors disconnect and short circuit the solar array if a ground fault occurs in the wiring. Ground fault detectors shall comply with AS 5033:2005 Installation of Photovoltaic Arrays all other relevant standards listed in section E1.3 of this document.


4.3.6. E5.3.6 Residual Current Devices

Residual current devices shall comply with AS 5033:2005 Installation of Photovoltaic Arrays all other relevant standards listed in section E1.3 of this document.

4.3.7. E5.3.7 Earthing

Earthing of the DC and AC components shall be made in accordance with AS/NZS 5033:2000 and AS 3000. Care should be taken to distinguish between earthing requirements of isolated and direct connected inverters.

4.3.8. E5.3.8 Extra Low Voltage Segmentation

Means shall be provided to sectionalise each PV string into segments whose Voc at STC (standard test conditions) is within the ELV (extra low voltage rage) where EVL ≤ 50V DC.

5. METERING AND MONITORING 5.1. E6.1 GENERAL

5.2. E6.1.1 Scope

The scope of work under the metering phase of the works is described in this section. • Assist the main electrical key person for ERA to liaise with the utility company

and provide all necessary actions to connect the PV system to the utility grid through the HV or MV ring main as necessary.

• Provide metering points for the BMS (Building Management System) which include:

• Imp current • Vmp voltage • Faults • As a minimum metering shall be provided to show the total generated output

from the local PV system at each low rise hub, north hotel and south hotel. The total PV power generated on site within the contracted scope of works should also be measured.

6. MARKING, SIGNS AND DOCUMENTATION

6.1. E7.1.1 General

All electric equipment shall be marked according to the requirements for marking in AS/NZS 3100.


All signs required shall: • comply with AS 1319 • be indelible • be legible from at least 0.8 m unless otherwise specified in the relevant AS/NSZ

5033:2000 Clauses • be constructed and affixed to remain legible for the life of the equipment it is

attached or related to.

6.2. E7.1.2 PV Array and PV Sub-Array Junction Boxes

A sign containing the text ‘SOLAR D.C.’ shall be attached to PV array and PV sub-array junction boxes. 6.3. E7.1.3 Disconnection Devices

Disconnection devices shall be marked with an identification name or number in accordance with the PV array wiring diagram. All switches shall have the ON and OFF positions clearly indicated. 6.4. E7.1.4 PV array main switch

The PV array main switch shall be provided with a sign affixed in a prominent location with the following text: ‘PV ARRAY MAIN SWITCH’. 6.5. E7.1.5 Fire emergency information

For PV arrays that are installed on buildings and have a rated power greater than 500 W or with VOC ARRAY greater than 50 V, a sign shall be installed next to the meter box (if one exists) and the building’s main switchboard. This sign shall state ‘Solar Array’ and provide information on the location of the PV array connected to that meter box. This sign shall comply with AS 1319 and be legible from at least 1.5 m. NOTE: In small installations, the location information may be very simple (e.g. ‘on roof’); in larger installations more information should be provided. The sign shall also include the following PV array information: • Open circuit voltage • Short circuit current

6.6. E7.1.6 Additional Information

The ERA venders shall include in his/her price to following documents: • A list of all alarms, both visual and audible, and the action that should be taken

when the alarm is activated. • A basic circuit diagram that includes the electrical ratings of the PV array, and

the ratings of all fuses and circuit breakers.


7. Construction Overview ERA will prepare a comprehensive project plan prior to construction that will include all critical paths. The general sequencing of the works will be: • Establishment of Secured Laydown Area • Substructure Construction • Framing and Modules Installation • Cabling • Inverters • SCADA • Quality Inspection and Rectifications • Systems Testing • Connection to Switchboard • System Commissioning • System Monitoring and O&M


Appendix B In-‐House Financing ................................................................................................................................................................. 32 30% Down Payment ............................................................................................................................................................... 32 20% Down Payment ............................................................................................................................................................... 33 10% Down Payment ............................................................................................................................................................... 34 0% Down Payment .................................................................................................................................................................. 35


In-‐House Financing ERA also provides another financing option for CLIENT. Under In-House Financing (IHF) financial modeling, CLIENT can potentially acquire the system at a low upfront investment. ERA, through its partner company, can finance the system in partnership with CLIENT. ERA will charge the client based on generation of the system with a potentially lower rate than the current rate being paid to the public utility – instead of an amortization table. In addition, CLIENT is able to fully utilize the accelerated depreciation of the system (10 years), which will help to reduce the company’s tax liability and achieve savings on its first billing month after installation. Depending on the initial down payment of the client and the loan term in the IHF model, the rate will be adjusted accordingly – the longer the term and the higher the down payment, the lower the rate. The options are demonstrated below for the 80 kWp. Take note that the percentages and loan terms are further negotiable.

30% Down Payment

With an initial investment of 30% from the client, the above showcases the payment scheme to be made to ERA. This flat rate of PHP 7.18/kWh will remain as such for the entire duration of the loan term – as stated, 15 years. After the 15th year of payment for the generated solar power, a transfer of ownership will occur from ERA to the client. The following figure shows the return on this 30% investment:

Term%of%IHF%Loan 15#YearsDown%Payment%of%Client: PHP %%%%%%%%%2,560,195.37%

IHF%Loan%Amount: PHP %%%%%%%%%5,973,789.21%

Total%Rate%/%kWh PHP 7.18#/#kWh

InIHouse%Financing


20% Down Payment

With an initial 20% down payment, the client can still enjoy a low rate of PHP 8.21/kWh. And as mentioned, after 15 years of payment of this flat rate, the system will be under the full ownership of the client. The return on investment is shown in the following figure:

!(5,000,000.00)!

!(!!!!

!5,000,000.00!!

!10,000,000.00!!

!15,000,000.00!!

!20,000,000.00!!

!25,000,000.00!!

!30,000,000.00!!

!35,000,000.00!!

0" 1" 2" 3" 4" 5" 6" 7" 8" 9" 10" 11" 12" 13" 14" 15" 16" 17" 18" 19" 20" 21" 22" 23" 24" 25"

Cumula1ve!Project!Cash!Flow!Projec1on!

Cumula1ve" Payback"

Term%of%IHF%Loan 15#YearsDown%Payment%of%Client:

PHP %%%%%%%%%1,706,796.92%



InGHouse%Financing


10% Down Payment

With a commitment of only 10%, while ERA at 90%, the rate is slightly higher than the benchmark rate. The return on investment can be seen in the following graph. Within the first year of operation, the amount of savings generated for the client has already surpassed the initial down payment made to ERA.

!(5,000,000.00)!

!(!!!!

!5,000,000.00!!

!10,000,000.00!!

!15,000,000.00!!

!20,000,000.00!!

!25,000,000.00!!

!30,000,000.00!!

!35,000,000.00!!

0" 1" 2" 3" 4" 5" 6" 7" 8" 9" 10" 11" 12" 13" 14" 15" 16" 17" 18" 19" 20" 21" 22" 23" 24" 25"


Cumula1ve" Payback"

Term%of%IHF%Loan 15#YearsDown%Payment%of%Client: PHP %%%%%%%%%%%%%853,398.46%



InJHouse%Financing


0% Down Payment

With no commitment, and ERA taking all the risks, the rate is projected to be marginally higher than the current average the client is paying now.

!(5,000,000.00)!

!(!!!!

!5,000,000.00!!

!10,000,000.00!!

!15,000,000.00!!

!20,000,000.00!!

!25,000,000.00!!

!30,000,000.00!!

0" 1" 2" 3" 4" 5" 6" 7" 8" 9" 10" 11" 12" 13" 14" 15" 16" 17" 18" 19" 20" 21" 22" 23" 24" 25"


Cumula1ve" Payback"

Term%of%IHF%Loan 15#YearsDown%Payment%of%Client: PHP %%%%%%%%%%%%%%%%%%%%%%%%%%%%%%7%%%



In7House%Financing

Documents

40 KWp Santiago