DC Water Technical Memo 21Jan2014-Final - National · PDF fileDC Water Blue Plains Advanced Waste Water Treatment Plant ... Should DC Water move forward with this project and enter

Page 1 of 69 Technical Feasibility Study for Photovoltaic Systems at the DC Water Blue Plains Advanced Waste Water Treatment Plant

Technical Feasibility Study for Photovoltaic Systems

DC Water Blue Plains Advanced Waste Water Treatment Plant January 17, 2014


Table of Contents

1.0 Executive Summary ........................................................................................................ 3

1.1 Project Summary ............................................................................................................................................. 3

1.2 Summary of Assessment Findings ................................................................................................................... 3

1.3 Financial Summary .......................................................................................................................................... 3

1.4 Conclusion ....................................................................................................................................................... 4

2.0 Facility Description and Field Observations ................................................................ 5

2.1 Site Visit and Overview .................................................................................................................................... 5

2.2 Site Considerations .......................................................................................................................................... 6

3.0 Blue Plains Energy Demand Data Analysis .................................................................. 8

3.1 SCADA and Utility Analysis .............................................................................................................................. 8

4.0 PV System Sizing and Energy Production ................................................................... 9

5.0 PV Installations at Various Waste Water Treatment Plants ...................................... 13

5.1 Washington Suburban Sanitary Commission, Seneca and Western Branch Waste Water Treatment Plants, Germantown and Upper Marlboro, MD ................................................................................................................. 13

5.2 Hill Canyon Wastewater Treatment Plant (HCTP), Thousand Oaks, CA ........................................................ 13

5.3 Ventura County Waterworks District, Moorpark Water Reclamation Facility, Moorpark, CA ...................... 14

5.4 Camden County Municipal Utilities Authority, New Jersey ........................................................................... 15

5.5 West Basin Municipal Water District, El Segundo, CA ................................................................................... 18

5.6 Rancho California Water District, Santa Rosa Water Reclamation Facility, Murrieta, CA ............................ 19

6.0 Interconnection Requirements, Tariffs and SREC legislation .................................. 20

6.1 Public Service Commission and PEPCO Utility Considerations ....................................................................... 20

6.2 Net Metering ................................................................................................................................................. 20

6.3 Solar Renewable Energy Credits .................................................................................................................... 21

7.0 Potential PPA Pricing ................................................................................................... 23

8.0 Project Timeline with Gantt Chart................................................................................ 23

Appendix A. Conceptual Drawings .................................................................................... 25

Appendix B. PV Syst Annual Energy Estimate Data Sheets ........................................... 37


1.0 Executive Summary

1.1 Project Summary

The following Technical Memorandum prepared by AECOM was commissioned by the District of Columbia Water and Sewer Authority (DC Water) to evaluate the feasibility of locating a solar photovoltaic (PV) energy project at the Blue Plains Advanced Wastewater Treatment Plant (Blue Plains). In doing so, AECOM’s expert in solar energy visited Blue Plains in order to understand site related issues and create preliminary solar array layouts. AECOM also developed solar energy production estimates, analyzed site electricity consumption, reviewed the current regulatory environment in DC and conducted conversations with developers to understand the economics behind this project. The result of these efforts are contained within this technical study.

Figure 1. Panoramic View of Blue Plains Advanced Waste Water Treatment Plant

1.2 Summary of Assessment Findings

AECOM determined that physical constraints and buildable areas provided a maximum installed direct current (DC) capacity of 13.27 megawatts (MW) of canopy style solar PV arrays, an example of which can be seen in Figure 6, coupled with a smaller amount of more common rooftop arrays. This equates to an alternating current (AC) or interconnected capacity of 11.6 MW which is a DC to AC ratio of 1.14. However, because most of the solar PV system is orientated southwest, the maximum output never reaches 11.6 MW, but rather approximately 8.2 MW. From the on-site electricity consumption review it was found that the minimum consumption across the entire treatment center for a period of ten minutes throughout all of 2012 and 2013 was 11.7 MW. Based upon the utility data provided and analyzed, a solar system as determined in this report would not be expected to export power on to the PEPCO grid.

1.3 Financial Summary

Should DC Water move forward with this project and enter into a Power Purchase Agreement (PPA) with a solar developer for the purchase of on-site generated solar electricity, DC Water could financially benefit based on a solar energy PPA that offers a lower price than current and future utility prices. The advantage of power delivered on-site is that it offsets more expensive power purchased from PEPCO or a Competitive Electric Suppler (CES) as well as offsetting the transmission and distribution charges for that purchased power. AECOM is not in a position to provide forward looking utility electricity prices, however based on discussions with developers, a solar PPA price of 6 cents per kWh is a reasonable expectation given the current high value of solar renewable energy credits (SREC) and the Federal Incentive Tax Credit (FITC). At the time of this technical study, information with regard to the current DC Water electricity purchase


contract was not provided. An example calculation is provided below so DC Water, when inserting known values, can compute yearly electricity savings when comparing the utility rates versus the PPA rates. The conceptual solar system identified in this technical study is estimated to produce roughly 16,519 megawatt-hours (MWh) per year of annual energy production (AEP). Assuming the solar PPA price is 6 cents per kWh, grid electricity prices (GEP) are at 9 cents per kWh, whether from PEPCO or a CES, and that PEPCO transmission and distribution charges are factored into the GEP, then savings from solar power are found from the following equation:

Savings from Solar = AEP x (GEP– PPA)

16,519 MWh x 1,000 kWh/MWh x (9 – 6) cents/kWh / 100 cents/$

= $495,559 per year

The low solar PPA price indicated above is in large part supported by the large revenue from high SREC prices. Due to the lack of solar supply in the DC area the high SREC price is not expected to decrease in the 12-18 month time frame, thus helping to maintain low solar PPA prices.

1.4 Conclusion

AECOM recommends DC Water proceed with a solar energy project based on the following:

Blue Plains can utilize space above open tanks and rooftops that can be used to host the solar PV arrays as shown in conceptual layouts in Appendix A. and the examples of other water treatment facilities in Section 5.0

Blue Plains has the electrical infrastructure and consumption to handle in excess of 10 MW AC of onsite generated power

The solar development market is strong in the DC region based on high SREC prices and the FITC, which translates to solar PPA pricing below current utility electrical pricing

Due to the reasons stated above, a Blue Plains solar project appears to be very desirable to developers/PPA providers

In order for DC Water to achieve a successful project and PPA, the following should be addressed early in the project development process:

Coordination with the Public Service Commission (PSC) to address a potential 5 MW limit in the size of qualifying SREC projects.

Coordination with PEPCO to address a potential 10 MW limit on interconnections; what options does DC Water have with PEPCO even though it is unlikely a solar PV system at 11.6 MW would export power to PEPCO

How the tasks and critical path of the schedule in Section 8.0 can be achieved


2.0 Facility Description and Field Observations

2.1 Site Visit and Overview

On December 19 and 20, 2013, AECOM’s solar PV specialist visited the DC Water Blue Plains facility to assess available areas, the open tanks and rooftops, which could host PV module arrays. It was understood by AECOM prior to this visit that DC Water desired PV systems with an aggregate capacity of approximately 10 MW interconnected or commonly referred to as “AC”. Also see Appendix A. of this document which illustrates the conceptual PV system layouts and areas that require clearances as noted during the site visit. The areas assessed were as follows:

Open Tanks

East Secondary Sedimentation – a good candidate for a PV canopy type system with the sludge sections clear and uncovered to allow future removal and maintenance of the equipment in the tanks.

West Secondary Sedimentation– a good candidate for a PV canopy type system with the sludge sections clear and uncovered to allow future removal and maintenance of the equipment in the tanks.

Nitrification Reactors – not a very good candidate based on the configuration of above ground equipment and significant area that needs to be clear and uncovered for mixing equipment removal.

Dual Purpose Sedimentation – a good candidate for a PV canopy type system with the sludge sections clear and uncovered to allow future removal and maintenance of the equipment in the tanks.

Nitrification Sedimentation – a good candidate for a PV canopy type system with the sludge sections clear and uncovered to allow future removal and maintenance of the equipment in the tanks.

Filtration and Disinfection Facility – a good candidate for a PV canopy type system with some clearance needed from the center isle due to large equipment potentially shading the array.

Rooftops

Central Maintenance Facility – a good candidate for a PV rooftop system however it does have a lot of HVAC mechanical equipment on the roof so there will need to be access paths and clearance in the PV system around the equipment to allow for future repair or replacement of the equipment.

Solids Processing Building – the lower northern section of this roof is a good candidate for a PV rooftop system; however, it does have large mechanical equipment on the roof so there will need to be access paths and clearance in the PV array around the mechanical equipment to allow for future repair or replacement of the equipment. In addition, a section of roof will need to be clear from the shadow of the higher adjacent southern building.


Grit Chamber Building 1 – one of the smaller buildings evaluated but a decent candidate with some mechanical equipment on the roof so there will need to be access paths and clearance in the PV array around the mechanical equipment to allow for future repair or replacement of the equipment.

Grit Chamber Building 2 – A good candidate for a PV rooftop system with little obstructions on the roof. The eastern side of the roof should have a setback due to large pipe/ductwork that is adjacent to the building to prevent shading on the PV array.

Secondary Blower Building - one of the smaller buildings evaluated but a decent candidate with large mechanical equipment on the roof so there will need to be access paths and clearance in the PV array around the mechanical equipment to allow for future repair or replacement of the equipment.

The Newly Constructed Warehouse – not a good candidate at this time because a green roof was installed and although a solar array could be elevated and rack mounted above the green roof, it is not recommended considering there are better candidates at this site.

Figure 2. Grit Chamber Building 2 Rooftop’s Large Open Space has a 247kW Solar System Potential

2.2 Site Considerations

In addition to assessing the available areas, the existing electrical infrastructure was assessed for potential points of interconnection (POI) for the solar PV systems in terms of electrical capacity and distance to the preliminary conceptual array locations (see Appendix A., Conceptual Drawings, of this document). To comply with the National Electrical Code (NEC), the amount of solar power that is interconnected on the customer side of an electrical meter cannot exceed 20% of the rating of the busbars to which it is interconnected. An electrical single line diagram showing how an interconnection should be distributed among the three main circuits at DC Water is also shown on the following page. It is important that the interconnection strategy be discussed with PEPCO as soon as practical in order to start the utility study process with PEPCO. The PEPCO studies are discussed in further detail on Section 6.1 of this document.

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3.0 Blue Plains Energy Demand Data Analysis

3.1 SCADA and Utility Analysis

Two full years of DC Water SCADA logged electrical data was examined. The consumption was calculated using the DC Water demand data and compared with PEPCO’s billed consumption for the same time period. The PEPCO consumption was slightly lower (less than a percent) likely based on PEPCO’s metering location upstream at the 69 kV switchyard coupled with transformer losses from 69 kV to 13.8 kV. The period of data that was analyzed was from December 18, 2011 to December 17, 2013. Fifteen minute demand data was taken from each of three electrical meters, A, B, and C, that are installed and owned by DC Water inside the 13.8 kV switchgear at the facility main substation (SS). A sample of the data set is shown in Table 1. In an assessment of the possibility of export power from solar generation, the two-year minimum demand was analyzed for each of the meters, as well as the total demand for all of the meters.

Date MAIN SS 13.8 kV Line A Demand

(kW)

MAIN SS 13.8 kV Line B Demand

(kW)

MAIN SS 13.8 kV Line C Demand

(kW)

12/17/11 5:00 AM 9754.00 9460.44 6482.04

12/17/11 5:15 AM 9718.25 9381.04 6464.04

12/17/11 5:30 AM 9743.47 9426.63 6443.21

12/17/11 5:45 AM 9747.03 9625.35 6470.60

Table 1. Sample of 15 Minute Interval Demand Data by Meter

Over the two-year period analyzed, the minimum total demand occurred on November 2, 2012 at 9:30 am as shown in Table 2. As seen below, the demand was 11,787 kW. This low level of demand occurred for roughly 30 minutes and appears that all of the feeders were connected.

Date MAIN SS 13.8 kV Line A Demand

(kW)

MAIN SS 13.8 kV Line B Demand

(kW)

MAIN SS 13.8 kV Line C Demand

(kW)

Total Demand, all Lines (kW)

11/2/12 9:15 AM 12568.96 6591.34 5203.57 24363.87

11/2/12 9:30 AM 3559.69 6743.98 1484.27 11787.95

11/2/12 9:45 AM 2756.10 7513.28 1596.89 11866.27

11/2/12 10:00 AM 4950.96 7626.60 2080.86 14658.42

Table 2. Lowest Site Energy Demand Over a Two Year Period

Over the course of the two year period analyzed, all three feeders had at least one instance when they were either not connected to PEPCO or the main 13.8 kV breaker at the substation was opened based on a zero demand value. When one of the feeders is interrupted, the consumption onsite does not decrease as the other feeders simply supply more power to meet


the on-site load. However, that also means that the solar PV system must be interconnected into the site electrical system between the 13.8 kV buses and the rest of the site electrical system to avoid any chance of the PV system from also going offline when one of the main feeders is de-energized.

If appropriately designed and connected to the site electrical system, based on the two years of 15 min average data that was analyzed, there does not appear to be any reason a 11 MW AC solar PV system will ever export power. In fact, it appears that a system much larger may be installed and never export power. The minimum on-site consumption at noon throughout the two years of data is around 18.5 MW. Thus for simplicity sake, it can be assumed that the largest solar PV system that could be installed onsite, and never export power, could approach 18.5 MW AC, and assuming no other on-site generation sources exist.

4.0 PV System Sizing and Energy Production

Module array layouts were produced in AutoCAD in order to provide a preliminary understanding of the potential solar capacity limited by physical constraints and waste water treatment plant maintenance considerations. AECOM visited the site and conferred with facility staff in order to understand the plant operational issues that a solar installation must accommodate. The solar PV layouts take into account our understanding of the site and facility constraints and are provided in Appendix A. Energy estimates for these layouts were also produced using the commercially available software and industry standard PV Syst, Version 5.67. These energy estimates are also shown in Appendix B. Both a module layout and an energy estimate were produced for each of the 10 sites contained in this report. All sites, their potential installed solar capacity, both in DC and AC are shown in Table 3. The total monthly potential energy production is broken out for each site in Table 4. All sites were modeled with a 270 watt, 60-cell module. Energy modeling was performed using a Suniva brand solar panel and inverters from Advanced Energy. All performance modeling assumed the PV modules are tilted at 10 degrees and rotated to align with the building or structure with which they are integrated. PV Syst requires the use of specific modules and inverters to perform the production analysis, but other equipment selections (modules and inverters) could be used with very similar production results.

Modified solar canopies were assumed as the racking system mounted above all of the tank sections at DC Water. These are racks typically made of galvanized steel members with stainless steel hardware, and sometimes anodized aluminum members as well. Due to the corrosive nature at DC Water, an all-aluminum structure will be needed. A very similar structure was installed in Camden, NJ and can be seen in Figure 6. Typically, the inverters, the equipment which converts the DC power from the modules to compatible AC power, are located near the solar array. An example of a pad mounted inverter can be seen in Figure 8.

When designing the module layouts on the building roof tops, consideration was given so as to provide sufficient access around the perimeter of each array for fire department requirements. In addition, the mechanical equipment, skylights, and other rooftop equipment was given ample space to avoid shading and provide access paths inside the PV arrays for future maintenance.


Location Total Modules

MW Capacity (DC)

Inverter Capacity (MW)

East Secondary Sedimentation 8,832 2.38 2

West Secondary Sedimentation 8,580 2.32 2

Dual Purpose Sedimentation 6,724 1.82 1.5

Nitrification Sedimentation 18,548 5.01 4.5

Filtration and Disinfection Facility

1,946 0.53 0.5

Solids Processing Building 1,001 0.27 0.25

Grit Chamber Building 1 396 0.11 0.1

Grit Chamber Building 2 913 0.25 0.2

Central Maintenance Facility 1,918 0.52 0.5

Secondary Blower Building 294 0.08 0.075

Totals 49,152 13.27 11.625

Table 3. Installed Solar Potential for Locations at Blue Plains

Table 4. Monthly Energy Output

To better understand the compatibility of on-site solar PV generation, solar energy generation production estimates on a monthly and time-of-day basis were produced. Table 5 below shows the hourly average energy kWh output by month of the entire solar PV system.

-

200,000

400,000

600,000

800,000

1,000,000

1,200,000

1,400,000

1,600,000

1,800,000

2,000,000

kilo

wat

t h

ou

rs

Blue Plains 11.6 MW Solar PotentialSecondary Blower Building

Central Maintenance Facility

Grit Chamber Building 2


Solids Processing Building


Nitrification Sedimentation

Dual Purpose Sedimentation

West Secondary Sedimentation

East Secondary Sedimentation


TOD Jan Feb March April May June July Aug Sept Oct Nov Dec Avg

0:00 0 0 0 0 0 0 0 0 0 0 0 0 0

1:00 0 0 0 0 0 0 0 0 0 0 0 0 0

2:00 0 0 0 0 0 0 0 0 0 0 0 0 0

3:00 0 0 0 0 0 0 0 0 0 0 0 0 0

4:00 0 0 0 0 0 0 0 0 0 0 0 0 0

5:00 0 0 0 0 196 422 135 0 0 0 0 0 63

6:00 0 0 83 782 914 1395 1133 881 376 0 0 0 464

7:00 13 208 892 2192 2173 2796 2377 2223 1568 1240 358 34 1340

8:00 797 1459 2642 4011 3811 4398 4059 3980 3270 2886 1759 977 2837

9:00 2006 2976 4127 5517 5037 5703 5474 5497 4924 4670 2999 2436 4280

10:00 3277 4490 5779 6965 6406 7008 6559 6639 6358 5946 3764 3484 5556

11:00 4260 4917 6598 7636 6626 7748 7510 7683 6729 6508 4138 4261 6218

12:00 4294 5150 7204 8207 6579 7581 7622 7622 6716 6869 4440 4256 6378

13:00 4027 5140 6294 7638 6585 7137 7270 6440 6233 6348 3906 3987 5917

14:00 3502 4394 5316 6543 5767 6890 6093 5571 5044 4892 2978 2874 4989

15:00 2244 3070 3809 4887 4503 5403 5495 4904 4189 3515 1761 1437 3768

16:00 861 1617 2507 3409 3073 4267 4187 3282 2359 1445 350 215 2298

17:00 0 202 758 1642 1613 2329 2225 1584 602 12 0 0 914

18:00 0 0 0 104 402 790 688 263 0 0 0 0 187

19:00 0 0 0 0 0 0 0 0 0 0 0 0 0

20:00 0 0 0 0 0 0 0 0 0 0 0 0 0

21:00 0 0 0 0 0 0 0 0 0 0 0 0 0

22:00 0 0 0 0 0 0 0 0 0 0 0 0 0

23:00 0 0 0 0 0 0 0 0 0 0 0 0 0

Table 5. Average Power Output in kW of 11.6 MW of Solar PV Arrays for Each Hour by Month

It is interesting to note that although all PV arrays have a combined DC output of 13.27 MW and a combined AC output nameplate rating of 11.6 MW, the maximum AC output throughout the year did not exceed 8.2 MW AC in the PV Syst performance modeling. The reduced output is mainly due to the fact that the majority of the PV arrays are orientated slightly southwest, and not due south facing when the sun is at its optimal position in the sky for energy generation. According to the results found in Section 3.1 the minimum on-site demand over the past two years is a little over 11 MW and according to the results shown above, it’s unlikely that there is any export of solar power back to the PEPCO utility grid.

Table 6 shows how the contribution of solar energy production will offset some of the current grid power purchased at Blue Plains.


Table 6. Estimated Energy Usage with Solar Versus Current Energy Usage at Blue Plains

-

5,000,000

10,000,000

15,000,000

20,000,000

25,000,000

kilo

wat

t h

ou

rs

Estimated Energy Usage after Solar

Current PEPCO Energy Usage


5.0 PV Installations at Various Waste Water Treatment Plants

5.1 Washington Suburban Sanitary Commission, Seneca and Western Branch Waste Water Treatment Plants, Germantown and Upper Marlboro, MD

AECOM was recently retained by the Washington Suburban Sanitary Commission (WSSC) to act as Owner’s Engineer to assist in their goal of implementing two separate 2 MW solar PV plants, one at each of two of their Waste Water Treatment Plants (WWTP), with each system offsetting approximately 3278 MWh/year of annual grid purchased power. Both systems were ground mount systems on open fields immediately adjacent to the respective WWTP. Standard Solar was selected as EPC contractor with Washington Gas Energy Services (WGES) acting as owner and PPA provider. AECOM assisted WSSC in reviewing design documents from the EPC provider in order to insure that a high quality system was designed. AECOM also prepared and submitted environmental permitting documents to the Maryland Department of the Environment (MDE) as well as facilitated interaction with MDE to insure the solar PV system was compatible with local environmental regulations. Both systems were connected at the customer side of the 13.2kV/480V step down transformer. Both systems were connected between the transformer and any relays or breakers protecting the WWTPs. Because of the chosen point of interconnection, and the fact that the solar production could sometimes (although rarely) exceed the on-site consumption, new relays were put in place to prevent the export of power back to the grid. This was done at these WWTPs because of issues exporting power onto the PEPCO network due to the inability of PEPCO relays to process power bi-directionally. The interconnection strategy at DC Water’s Blue Plains facility, further discussed in this technical document, is quite different and will require a multi-interconnection approach considering there are two main utility feeders branched out to three main meters and corresponding medium voltage circuits.

5.2 Hill Canyon Wastewater Treatment Plant (HCTP), Thousand Oaks, CA

HCTP, constructed in 1961 and processes about 10 million gallons of water every day, is well known for its environmental stewardship. Incoming wastewater is treated to an advanced tertiary level which renders it suitable for unrestricted use, and 65% of site electricity consumption is produced by an on-site 500 kW digester co-generator and a 584 kW DC, 500 kW AC, solar PV energy system. Figure 3 below shows the 584 kW DC solar PV system that was installed inside an overflow retention basin used primarily as a bio-solids drying bed. The modules were mounted on a single axis tracker that was elevated above the expected highest water level. All electrical gear was mounted on the side of the access roads to minimize any potential water intrusion. While a tracking system is different than would be expected at Blue Plains, this system was designed and installed by simply anchor bolting the upright piers on the existing concrete slab basin reducing the construction effort required for traditional pilings or foundations. The solar PV system was installed in early 2007 and offsets about 15% of the current grid purchased power.


Figure 3. 584 kW DC Solar PV System at the City of Thousand Oaks,

Hill Canyon Wastewater Treatment Plant

5.3 Ventura County Waterworks District, Moorpark Water Reclamation Facility, Moorpark, CA

Every day roughly 2.2 million gallons of water flow into Moorpark’s reclamation facility from the city’s 9,200 customers. The County of Ventura Strategic Plan (2011-2016) details five “focus areas”, of which “Environment, Land Use and Infrastructure” is one. The following strategic goal is prominently listed as part of this particular focus area: “Champion cost-effective energy reduction measures through independent efforts as well as through regional initiatives and private/public partnerships.”

In 2010, Ventura County Waterworks District No. 1 (District) partnered with AECOM to begin an investigation of photovoltaic (PV) systems. In July 2011, the District secured the performance based incentives for a 1.13 MW PV project at the Moorpark Waste Reclamation Facility (WRF).

The District went through an extensive RFP process and in early 2012, REC Solar was awarded the project and received notice to proceed and begin design and construction of the PV system. The PV system was commissioned in November 2012 and received utility permission for parallel operation.


Figure 4. 1.13 MW DC Solar PV System at the Moorpark Water Reclamation Facility

Currently the solar PV system produces about 2.3 million kWh’s annually and offsets about 80% of the current grid power purchased by the facility. The increased output is due to the single axis tracking, as seen in Figure 3, which produces about a 20% greater yield over a traditional fixed tilt system. It should be noted that single axis trackers work optimally when rows are positioned in a North-South direction and the array is in a rectangular open area. The Moorpark WRF utilized neighboring farmland that it owned by the District. The tracker foundations are pile driven wide flange beams into the existing soil which saves construction time and costs compared to traditional poured concrete footings. Over the life of the project, the District will save about $4.5 million dollars and the system is expected to be cash positive in year 13.

5.4 Camden County Municipal Utilities Authority, New Jersey

In 2010, the Camden County Municipal Utilities Authority (CCMUA) set an audacious goal for itself: treat 60 million gallons of wastewater a day at with a source of power that was 100% renewable, and cheaper than the electricity from the local utility. CCMUA recognized that photovoltaic (PV) solar had potential, however, the plant was mainly comprised of open water treatment tanks, and traditional rooftop or an open space solar array was not viable on a meaningful scale. Discouraged but determined to find a solution, the CCMUA issued a bid for solar power services. HelioSage one of the respondents to the solicitation, was convinced that with some additional engineering, a solution similar to a solar carport could be deployed atop the eight-acre section of open clarifiers, putting to use the majority of a treatment facility that was otherwise unusable for any other purpose. Because the project only made sense if the CCMUA could realize instant energy savings, the design not only had to be robust, it had to be cost effective.


Figure 5. Solar Array Mounted Atop Tanks at CCMUA

Figure 6. Close-Up of Solar Canopy Style Array at CCMUA

In July, 2012 the CCMUA Solar Center commissioned a 1.8 Megawatt solar PV energy system comprised of more than 7,200 solar panels spanning seven acres of open tanks. The innovative design includes a canopy mounting system standing 8-9 feet tall which does not interfere with access, operations, or maintenance of the facility tank. The solar PV structure was designed to resist corrosion from brackish water, carbonic acid, and hydrogen sulfide. The structure is a modified carport canopy manufactured by a Schletter, a well-known supplier of photovoltaic racking systems including carports. Under a Power Purchase Agreement (PPA), the CCMUA faced no capital expenditures, and will not be responsible for any operations and maintenance costs. The CCMUA’s only financial responsibility is to pay a monthly solar energy bill that is fixed at grid-discounted prices for 15 years. The CCMUA estimates it will save several million dollars in energy costs over that time frame. The solar PV system is estimated to generate about 2.2 million kilowatt-hours annually and appears to be performing better than estimated based on the CCMUA interactive website that shows current and cumulative energy production


along with environmental attributes and a real-time display of current energy production as shown below in Figure 7.

Figure 7. CCMUA Solar Interactive Website

Figure 8. CCMUA Pad-Mounted Solar Inverter


5.5 West Basin Municipal Water District, El Segundo, CA

Since 1947, West Basin Municipal Water District (West Basin) is an innovative public agency that provides drinking and recycled water to a 185-square mile service area in the western portion of Los Angeles County. West Basin is the sixth-largest water district in California, and serves a population of nearly one million people.

In 2006, West Basin made the decision to install a PV solar electric solution at its water recycling facility to gain the long-term financial and environmental benefits of going solar.

In November 2006, SunPower completed the installation of West Basin’s PV solar array, comprised of 2,848 modules, 564 kW DC, installed atop the district’s in-ground concrete treatment storage tanks, utilizing what would be otherwise unused space. West Basin’s PV solar power system produces about 783,000 kilowatt-hours (kWh) annually of clean, renewable energy while reducing utility costs by over 10%. Figure 9 below shows the PV system at West Basin.

Figure 9. 564 kW DC Solar PV System at West Basin Water Recycling Facility

Since the PV system installation in 2006, the cumulative energy output production is 5.97 Gigawatt-hours (GWh) as of January 2014. West Basin showcases its carbon reduction, energy conservation, and environmental protection initiatives through an interactive, educational display at its treatment plant. Based on information provided by SunPower, the PV system project will pay for itself in 13 years.


5.6 Rancho California Water District, Santa Rosa Water Reclamation Facility, Murrieta, CA

Since 1965, Rancho California Water District (RCWD) provides water, wastewater, and reclamation services to an area of approximately 150 square miles. The District serves the area known as Temecula/Rancho California, which includes the city of Temecula, parts of the city of Murrieta, and other areas of Riverside County, CA.

RCWD is forward thinking, environmentally and strategically cost conscious, and when management was faced with rising utility rates and the district’s energy bill reaching over $5 million annually, they considered on-site PV solar energy as an alternative.

Prior to considering solar PV energy, RCWD’s Board of Directors had evaluated a variety of renewable energy initiatives, including hydroelectric power, reservoir pumped storage, and other measures. But with a concern of district’s finances –– the board had not identified a green program that seemed financially feasible. “Our major concern was economics, and none of these projects seemed to pencil out,” says Andy Webster, acting District Engineer. “Plus, there were many challenges with regard to regulatory compliance, and our local utility also had stringent requirements for implementing renewable energy programs.”

In January 2007, RCWD took immediate advantage of a the California Solar Initiative and secured a performance based incentive of $0.34 per kWh paid over a five year period administered by the local utility, Southern California Edison. RCWD utilized a Power Purchase Agreement (PPA) through the installer, SunPower Corporation, which required no capital outlay. The district pays for only the electricity generated by the PV system. The PV system is financed, owned, and operated by SunPower Corporation. SunPower also receives the incentives secured by RCWD prior to the selection of an installer.

Since RCWD’s 1.1 MW DC PV system was installed in 2009, the district has been enjoying a multitude of benefits. The top of the list includes paying significantly less for electricity. For the Santa Rosa Water Reclamation Facility, savings are over $152,000 a year, and off-setting the facility’s energy demand by approximately 30%. In addition, as RCWD opted to keep the Renewable Energy Credits (RECs) associated with its system, the district also has the ability to market the positive impact they are making on the environment by reducing over 73 million pounds of harmful carbon emissions over the next thirty years through their solar investment. “In addition to helping us comply with future federal, state and local regulatory requirements for water and wastewater utilities, our ability to speak to our green focused initiatives, while saving money is of importance,” says Webster. The solar PV system is expected to save the district up to $6.8 million in electricity costs over the next 20 years. The solar PV system installed at RCWD Santa Rosa Facility is a tilted tracking system which has a higher energy production yield than traditional fixed tilt systems by about 25%, hence the higher cost benefit over similar single axis PV systems and fixed tilt systems installed in Southern California. In addition, tilted tracking systems require significantly larger area to avoid shading from row to row and must be orientated in straight contiguous lines. A tilted tracking system has its limitations and is designed to be in an open unrestricted rectangular area similar to the single axis tracking system.


6.0 Interconnection Requirements, Tariffs and SREC legislation

6.1 Public Service Commission and PEPCO Utility Considerations

Based on AECOM initial findings, DC Water has the potential to connect about 12 MW AC at Blue Plains, however, under the Public Service Commission of the District of Columbia, Chapter 40, District of Columbia Small Generator Interconnection Rules, up to 10 MW “nameplate capacity” may be interconnected. Per the definition in section 4099.1, “nameplate capacity” means the maximum rated output of a generator, prime mover, or other electric power production equipment under specific conditions designated by the manufacturer and is usually indicated on a nameplate physically attached to the power production equipment. For the purpose of this study, AECOM assumes this to be the nameplate rating of the aggregate of DC to AC inverters (AC) and not the nameplate rating of the total wattage of PV modules (DC). This rating characterization will need to be clarified if the PV project moves forward.

The interconnection of a PV system that runs in parallel with PEPCO requires an “Interconnection Application and Agreement” regardless of size and whether there is any likelihood of power export. Because Blue Plains has the potential to interconnect up to 10 MW and greater, a PEPCO Level 4 Interconnection Review (review) is required. This review is a multistep process as follows:

1. Submission of an interconnection request by DC Water to PEPCO

2. A scoping meeting between DC Water and PEPCO and based on the outcome of this scoping meeting, the following studies may be performed

3. A PEPCO interconnection feasibility study which determines any potential adverse impacts on PEPCO’s distribution system

4. A PEPCO interconnection system impact study is conducted if the feasibility study finds potential adverse system impacts to PEPCO’s distribution system

5. If an interconnection feasibility study and a system impact study are not required, then a PEPCO interconnection facilities study may be performed where switchgear, transformers, and other station equipment are investigated and potential upgrades are determined.

It is important to engage PEPCO early in the project development process for several reasons. First, so PEPCO can evaluate all other potential interconnections that could be in the works and on the same distribution system. Secondly, if DC Water has intentions of connecting other types of generation equipment, such as onsite cogeneration, all sources must be identified and included in the submissions to PEPCO.

6.2 Net Metering

Net metering is the concept by which a kWh credit is offered to the electrical account when the generator, in this case a solar photovoltaic system, produces more electricity than consumed on site for that meter/electrical account. A credit can be used at a later time (the evening) or date (winter when solar production is low). Net metering has been important for the success of solar when a PV system generates more on-site solar power than the instantaneous on-site electricity consumption, as the solar supply curve does not always match the load profile curve it is


interconnected to; excess daytime production provides a credit which can be used at nighttime. In the District of Columbia, the Clean and Affordable Energy Act of 2008 (Council Bill 17-492) established the regulation for a net metering limit of 1 MW, however this only applies to PEPCO. Competitive Electricity Suppliers are required to provide net-metering up to a system size of 100 kW. It should be noted that these are provisions that both PEPCO and the CES may provide net metering for greater than the required amount. It is also worth noting that it is currently assumed that the potential solar system capacity at Blue Plains will not likely export energy at any time and a net metering agreement may not be required. It is recommended that DC Water engage the Public Service Commission, PEPCO and their CES about whether a net metering agreement can be established for the benefit of Blue Plains.

6.3 Solar Renewable Energy Credits

Some states that have Renewable Portfolio Standards (RPS) have a specific carve-out in which they require the local electricity suppliers to secure a portion of their renewable energy from solar. In order to make sure the electricity suppliers do this, an administrative exchange is often set up to track the production of solar energy. A solar system must register with the local tracking administration and report the energy generation. An SREC is assigned to every MWh of generation that is reported. The local electricity suppliers are required to purchase a certain number of SRECs every year, however, they are not required to purchase the energy itself, just the SREC associated with each generated unit of energy. The energy can be used by the system owner, or sold to a third party by the system owner. The DC SREC market is currently governed by the Distributed Generation Amendment Act (D.C. Law 19-36). This law requires the solar system to be entirely located within the District of Columbia or connected to a power line that originates in the District of Columbia. The law also limits a system that qualifies for SRECs to a maximum size of 5 MW AC. This limit, however, is not specified in the current legislation to be a limit placed per electrical account, electric meter, or host site. AECOM has had preliminary, but inconclusive, conversations with the DC Public Service Commission regarding the limit and how it may apply to Blue Plains. The PSC recommended that DC water submit a formal request for information and clarification for rulemaking on the 5 MW limit.

Figure 10 below shows how pricing has changed over the last two years in the DC SREC market. Following that, Figure 11 shows how the SREC prices in DC compare to that of other states.


Figure 10. Washington DC Solar Renewable Energy Credits (SREC) Pricing 2012-2013

Figure 11. SREC Pricing by State


7.0 Potential PPA Pricing

AECOM queried confidentially a number of developers of solar energy that offer solar power purchase agreements in order to understand the range of electricity prices that may be available to DC Water for a solar project located at Blue Plains. The names of those companies are being withheld at the companies’ requests. All developers shared similar sentiments, those being that a PPA price in the range of 6 to 8 cents per kWh would be available with an approximate 2% annual escalation. In addition, they suggested this price assumed a racking system similar to a parking canopy would be used, which is one of the most expensive types of racking systems for a solar array, but a reasonable assumption given the site, and that the project would be a minimum of a few megawatts in size. Other assumptions include a 20 year PPA contract term to be executed by both parties, and that the PPA provider would own the SRECs, as opposed to DC Water. When speaking with the developers, all expressed that their calculations of a possible PPA price were heavily dependent on the price of the SRECs, as that is the driving force toward offering a lower price of power to DC Water. None expressed risk of not qualifying for the Federal Investment Tax Credit (FITC) that goes from 30% for systems commissioned before December 31, 2016, to 10% in 2017; however this was based upon the PPA providers assuming a development, construction, and commissioning in a 12 to 18 month time frame.

8.0 Project Timeline with Gantt Chart

The attached Gantt schedule was developed to show all phases in the project development of a third party developed and owned solar PV project. The RFQ, RFP, and Contract Phases were developed with input by AECOM Design-Build Management at the Blue Plains facility. These three phases can take almost one year from the time of RFQ development to the Notice to Proceed (NTP) to the selected developer.

The Engineer, Procure, and Construct (EPC) Phase is a little over a year and half and takes into consideration PEPCO document preparation and submission along with ample time for design review by DC Water and any other potential authority having jurisdiction. The actual physical installation time is just over a year in duration (long for PV projects of this scale) and this mainly has to do with the complexity of the installation over the open tanks. Based on construction photos and the similar installation of the CCMUA facility, large steel beams were placed straddling the tanks and sheets of plywood were installed on top of the beams temporarily covering the tanks. Covering the tanks ensures the installation workers safety from falling into the tanks and the potential for parts and tools from falling into the tanks. Placing the beams and plywood has to be done with utmost care and will most likely be done sections at a time, limiting the amount of tanks that can be covered and the following sequences of installing the racking structure and modules.

Keeping to the overall project timeline is very important in order to insure qualifying for the 30% FITC and to ensure a high SREC price, all of which will have an impact on the PPA pricing as discussed in Section 7.0. Any delays could negatively impact the PPA pricing available and the emphasis of this schedule is that time is of the essence.

ID Task Name BusinessDays

Start Finish

1 DC Water, Photovoltaic Project 675 days Mon 2/3/14 Fri 9/2/162 RFQ Phase 40 days Mon 2/3/14 Fri 3/28/143 Develop RFQ 20 days Mon 2/3/14 Fri 2/28/144 Issue RFQ 0 days Fri 2/28/14 Fri 2/28/145 Prepare and Submit SOQ 20 days Mon 3/3/14 Fri 3/28/146 Pre-SOQ Meeting 0 days Fri 3/28/14 Fri 3/28/147 RFP Phase 140 days Mon 3/3/14 Fri 9/12/148 Develop RFP 26 days Mon 3/3/14 Mon 4/7/149 Review SOQs and Shortlist Teams 20 days Mon 3/31/14 Fri 4/25/14

10 Issue RFP to Shortlisted Bidders 0 days Fri 4/25/14 Fri 4/25/1411 Prepare and Submit Proposal 30 days Mon 6/9/14 Fri 7/18/1412 Proposal Evaluation and Interviews 30 days Mon 7/21/14 Fri 8/29/14

13 DC Water Management Review 10 days Mon 9/1/14 Fri 9/12/1414 Contract Phase 65 days Mon 9/15/14 Fri 12/12/1415 Prepare and Submit Agenda

Documents for Environmental Quality and Sewerage Services (EQ&SS) Committee

15 days Mon 9/15/14 Fri 10/3/14

16 EQ&SS Committee Approval 1 day Thu 10/16/14 Thu 10/16/1417 Approval by DC Water Board of

Directors1 day Thu 11/6/14 Thu 11/6/14

18 Contract Execution 25 days Fri 11/7/14 Thu 12/11/1419 NTP 1 day Fri 12/12/14 Fri 12/12/1420 Project Management -Engineering,

Procurement, Construction420 days Fri 12/12/14 Fri 7/22/16

21 Project Kick Off 0 days Fri 12/12/14 Fri 12/12/1422 Design 50 days Mon 12/15/14 Fri 2/20/1523 Design Review 30 days Mon 2/23/15 Fri 4/3/1524 Material Procurement and Delivery 60 days Mon 4/6/15 Fri 6/26/15

25 Preparation of PEPCO Documents for Interconnection and Net Metering

10 days Mon 4/6/15 Fri 4/17/15

26 PEPCO Submission 0 days Fri 4/17/15 Fri 4/17/1527 PEPCO Review 60 days Mon 4/20/15 Fri 7/10/1528 Installation 280 days Mon 6/29/15 Fri 7/22/1629 Civil Work 15 days Mon 6/29/15 Fri 7/17/1530 Structure 140 days Mon 6/29/15 Fri 1/8/1631 Delivery 20 days Mon 6/29/15 Fri 7/24/1532 Install Structures 120 days Mon 7/27/15 Fri 1/8/1633 PV Modules 180 days Mon 6/29/15 Fri 3/4/1634 PV Module Delivery 20 days Mon 6/29/15 Fri 7/24/1535 Install PV Modules 100 days Mon 10/19/15 Fri 3/4/1636 Install Electrical 198 days Wed 7/1/15 Fri 4/1/1637 Install Rough Electrical 60 days Wed 7/1/15 Tue 9/22/1538 Rough Inspection 5 days Wed 9/23/15 Tue 9/29/1539 Install Inverters 40 days Wed 9/30/15 Tue 11/24/1540 Install BOS equipment 40 days Mon 2/8/16 Fri 4/1/1641 Commission of system 75 days Mon 4/11/16 Fri 7/22/1642 System testing 20 days Mon 4/11/16 Fri 5/6/1643 Final inspection 5 days Mon 5/9/16 Fri 5/13/1644 Preparation of PEPCO Final

Documents for Interconnection and Net Metering

30 days Mon 5/16/16 Fri 6/24/16

45 PEPCO Permit to Operate 0 days Fri 7/22/16 Fri 7/22/1646 System In-Service 0 days Fri 7/22/16 Fri 7/22/1647 Project Closeout 30 days Mon 7/25/16 Fri 9/2/1648 Coordinate Record Drawings 20 days Mon 7/25/16 Fri 8/19/1649 Update Project Binder 5 days Mon 8/22/16 Fri 8/26/1650 Coordinate O & M 5 days Mon 8/29/16 Fri 9/2/16

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep2014 2015 2016

DC WaterSolar Photovoltaic Project

DRAFT-Proposal


Appendix A. Conceptual Drawings

Pages 26 through 36 are solar array layouts.

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PV-1.0 COVER SHEET

PV-1.1 EAST SECONDARY SEDIMENTATIONMODULE LAYOUT

PV-1.2 WEST SECONDARY SEDIMENTATIONMODULE LAYOUT

PV-1.3 DUAL PURPOSE SEDIMENTATIONMODULE LAYOUT

PV-1.4 NITRIFICATION SEDIMENTATIONMODULE LAYOUT

PV-1.5 FILTRATION AND DISINFECTIONFACILITY MODULE LAYOUT

PV-1.6 SOLIDS PROCESSING BUILDINGMODULE LAYOUT

PV-1.7 GRIT CHAMBER BUILDING 1 MODULELAYOUT

PV-1.8 GRIT CHAMBER BUILDING 2 MODULELAYOUT

PV-1.9 CENTRAL MAINTENANCE FACILITYMODULE LAYOUT

PV-1.10 SECONDARY BLOWER BUILDINGMODULE LAYOUT

SOLAR PHOTOVOLTAIC FEASIBILITY PROJECTDISTRICT OF COLUMBIA WATER AND SEWER AUTHORITY

BLUE PLAINS ADVANCED WASTEWATER TREATMENT PLANT

PV SOLAR ARRAY SYSTEM DATA TABLE :

Location Sheet No. TotalModule

ModuleNameplate (W)

DC Capacity(MW)

Azimuth(degrees)

Tilt(degrees)

Inverter Mfg. orApproved Equivalent

Inverter ACCapacity

(MW)

InverterQty.

Annual EnergyOutput (MWh)

East Secondary Sedimentation PV-1.1 8,832 270 2.38 217 10 ADVANCED ENERGY 2 2 2,973

West Secondary Sedimentation PV-1.2 8,580 270 2.32 217 10 ADVANCED ENERGY 2 2 2,888

Dual Purpose Sedimentation PV-1.3 6,724 270 1.82 217 10 ADVANCED ENERGY 1.5 2 2,264

Nitrification Sedimentation PV-1.4 18,548 270 5.01 217 10 ADVANCED ENERGY 4.5 5 6,245

Filtration and Disinfection Facility PV-1.5 1,946 270 0.53 166 10 ADVANCED ENERGY 0.5 1 661Solids Processing Building PV-1.6 1,001 270 0.27 217 10 ADVANCED ENERGY 0.250 1 321

Grit Chamber Building 1 PV-1.7 396 270 0.11 171 10 ADVANCED ENERGY 0.100 1 128Grit Chamber Building 2 PV-1.8 913 270 0.25 217 10 ADVANCED ENERGY 0.200 2 292

Central Maintenance Facility PV-1.9 1,918 270 0.52 171 10 ADVANCED ENERGY 0.500 1 653Secondary Blower Building PV-1.10 294 270 0.08 217 10 ADVANCED ENERGY 0.075 1 94

Totals 49,152 13.27 11.625 18 16,519



Filtration and DisinfectionFacility







Secondary BlowerBuilding

PV SOLAR ARRAY SYSTEM DATA TABLEArea Total

ModulesModule

Nameplate(W)

DCCapacity

(MW)

Azimuth(degrees)

Tilt(degrees)

InverterMfg.

Inverter ACCapacity

(MW)

InverterQty.

East SecondarySedimentation

8,832 270 2.38 217 10ADVANCED

ENERGY1 2

Totals 8,832 2.38 2 2

MINIMUM FOUR FOOT CLEARANCEFOR EQUIPMENT ACCESS

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ModulesModule

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(MW)

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Capacity(MW)

InverterQty.

West SecondarySedimentation

8,580 270 2.32 217 10ADVANCED

ENERGY1 2

Totals 8,580 2.32 2 2

MINIMUM FOUR FOOT CLEARANCE FOR EQUIPMENT ACCESS

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POINT OF INTERCONNECTION

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ModulesModule

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Capacity(MW)

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Dual PurposeSedimentation

6,724 270 1.82 217 10ADVANCED

ENERGY1, 0.5 2

Totals 6,724 1.82 1.5 2

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MINIMUM FOUR FOOT CLEARANCEFOR EQUIPMENT ACCESS

ALL LIGHT POSTS IN VICINITY OF SOLAR ARRAYTO BE REMOVED


ModulesModule

Nameplate(W)

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(MW)

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InverterMfg.

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(MW)

InverterQty.

NitrificationSedimentation

18,548 270 5.01 217 10ADVANCED

ENERGY1,1,1,1,0.5 5

Totals 18,548 5.01 4.5 5

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MINIMUM FOUR FOOT CLEARANCE REQUIRED FOR EQUIPMENT ACCESS

LIGHT POSTS TO BE REMOVED LIGHT POSTS TO BE REMOVED LIGHT POSTS TO BE REMOVED

LIGHT POSTS TO BE REMOVED LIGHT POSTS TO BE REMOVED LIGHT POSTS TO BE REMOVED

LIGHT POSTS TO BE REMOVED THROUGHOUT THIS AISLE

NEW DENITE USS SWITCHGEARLINES UNKNOWN, POSSIBLEPOINT OF INTERCONNECTION

NEW NSB USS 3000 KVA (4160V), LINES UNKNOWN, POSSIBLE POINT OF INTERCONNECTION

AREA SUBSTATION 16 MVA (13.8 KV & 4160V)LINES A, B & C, POSSIBLE POINT OF INTERCONNECTION


ModulesModule

Nameplate (W)DC

Capacity(kW)

Azimuth(degrees)

Tilt(degrees)

Inverter Mfg. Inverter ACCapacity (kW)

InverterQty.

Filtration andDisinfection Facility

1,946 270 525.4 166 10ADVANCED

ENERGY500 1

Totals 1,946 525.4 500 1

DIS

TR

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OF

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IA W

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ASS-6 16 MVA (13.8kV & 4160V),LINES A, B & CPOSSIBLE POINT OF INTERCONNECTION


ModulesModule

Nameplate(W)

DCCapacity

(kW)

Azimuth(degrees)

Tilt(degrees)


InverterQty.

SolidsProcessing

Building1,001 270 270.3 217 10

ADVANCEDENERGY

250 1

Totals 1,001 270.3 250 1

DIS

TR

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OF

CO

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MB

IA W

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ModulesModule

Nameplate(W)

DCCapacity

(kW)

Azimuth(degrees)

Tilt(degrees)


InverterQty.

Grit ChamberBuilding 1 396 270 106.9 171 10

ADVANCEDENERGY

100 1

Totals 396 106.9 100 1

DIS

TR

ICT

OF

CO

LU

MB

IA W

AT

ER

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Pro

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PRI SED USS 1-2500 KVA(4160V) LINES B & C, POSSIBLEPOINT OF INTERCONNECTION


ModulesModule

Nameplate(W)

DCCapacity

(kW)

Azimuth(degrees)

Tilt(degrees)

Inverter Mfg. Inverter ACCapacity

(kW)

InverterQty.

Grit ChamberBuilding 2 913 270 246.5 217 10

ADVANCEDENERGY

100,100 2

Totals 913 246.5 200 2

DIS

TR

ICT

OF

CO

LU

MB

IA W

AT

ER

AN

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Pro

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:\US

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PRI SED USS 4-2500 KVA(4160V) LINE A ONLY, POSSIBLE



ModulesModule

Nameplate(W)

DCCapacity

(kW)

Azimuth(degrees)

Tilt(degrees)


InverterQty.

CentralMaintenance

Facility1,918 270 517.9 171 10

ADVANCEDENERGY

500 1

Totals 1,918 517.9 500 1

DIS

TR

ICT

OF

CO

LU

MB

IA W

AT

ER

AN

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-01-

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MSS USS 2000KVA(4160V), LINES B & C, POSSIBLE



ModulesModule

Nameplate(W)

DCCapacity

(kW)

Azimuth(degrees)

Tilt(degrees)

Inverter Mfg. Inverter ACCapacity

(kW)

InverterQty.

SecondaryBlower Building 294 270 79.4 171 10

ADVANCEDENERGY

75 1

Totals 294 79.4 75 1

DIS

TR

ICT

OF

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MB

IA W

AT

ER

AN

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AN

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WA

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No

.: 60

2900

24

Iss

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Sta

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DR

AF

T,

NO

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OR

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UC

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x 17

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(20

14

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st P

lott

ed:

20

14

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-21

Pro

ject

Ma

na

ge

me

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Initi

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Ap

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ved:

File

nam

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:\US

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S\G

OLD

D\D

ES

KT

OP

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CT

S\D

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1.1

0D

ate

: 2

01

4-0

1-17

DZ

GA

AA

A

SEC BLOWER BLDG - NEW 2000A(4160V) SWGR, LINES A, B & C,POSSIBLE POINT OF INTERCONNECTION


Appendix B. PV Syst Annual Energy Estimate Data Sheets

Pages 38 through 69 are the PV Syst energy production reports.

Page 1/316/01/14PVSYST V5.67

Grid-Connected System: Simulation parameters

Project : Blue Plains Advanced Wastewater Treatment Plant

Geographical Site Washington Country USA

Situation Latitude 39.1°N Longitude 76.5°WTime defined as Legal Time Time zone UT-5 Altitude 5 m

Albedo 0.20Meteo data : Washington Dc Reagan Ap

Simulation variant : East Secondary Sedimentation

Simulation date 16/01/14 12h00

Simulation parameters

Collector Plane Orientation Tilt 10° Azimuth 37°

Horizon Free Horizon

Near Shadings No Shadings

PV Array Characteristics

PV module Si-mono Model OPT270-60-4-100Manufacturer Suniva, Inc.

Number of PV modules In series 46 modules In parallel 192 stringsTotal number of PV modules Nb. modules 8832 Unit Nom. Power 270 WpArray global power Nominal (STC) 2385 kWp At operating cond. 2144 kWp (50°C)Array operating characteristics (50°C) U mpp +/-655 V I mpp 1637 ATotal area Module area 14328 m²

Inverter Model AE 1000NX - 800 SINGLE MFGManufacturer Advanced Energy Industries, Inc.

Characteristics Operating Voltage +/-550-1000 V Unit Nom. Power 1000 kW ACInverter pack Number of Inverter 2 units Total Power 2000 kW AC

PV Array loss factorsThermal Loss factor Uc (const) 29.0 W/m²K Uv (wind) 0.0 W/m²K / m/s

=> Nominal Oper. Coll. Temp. (G=800 W/m², Tamb=20°C, Wind=1 m/s.) NOCT 45 °C

Wiring Ohmic Loss Global array res. 13 mOhm Loss Fraction 1.5 % at STC

Array Soiling Losses Loss Fraction 3.0 %Module Quality Loss Loss Fraction 1.0 %Module Mismatch Losses Loss Fraction 2.0 % at MPPIncidence effect, ASHRAE parametrization IAM = 1 - bo (1/cos i - 1) bo Parameter 0.05

User's needs : Unlimited load (grid)

Page 2/316/01/14PVSYST V5.67

Grid-Connected System: Main results



Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 8832 Pnom total 2385 kWpInverter Model AE 1000NX - 800 SINGLE MFGPnom 1000 kW acInverter pack Nb. of units 2.0 Pnom total 2000 kW acUser's needs Unlimited load (grid)

Main simulation resultsSystem Production Produced Energy 2973 MWh/year Specific prod. 1247 kWh/kWp/year

Performance Ratio PR 81.1 %

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec0

1

2

3

4

5

6

7

Nor

mal

ized

Ene

rgy

[kW

h/kW

p/da

y]

Normalized productions (per installed kWp): Nominal power 2385 kWp

Yf : Produced useful energy (inverter output) 3.42 kWh/kWp/dayLs : System Loss (inverter, ...) 0.08 kWh/kWp/dayLc : Collection Loss (PV-array losses) 0.72 kWh/kWp/day

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec0.0

0.2

0.4

0.6

0.8

1.0

Per

form

ance

Rat

io P

RPerformance Ratio PR

PR : Performance Ratio (Yf / Yr) : 0.811


Balances and main results

GlobHor T Amb GlobInc GlobEff EArray E_Grid EffArrR EffSysR

kWh/m² °C kWh/m² kWh/m² MWh MWh % %

January 59.4 2.44 69.2 65.7 144.5 140.9 14.58 14.22

February 73.6 1.26 81.9 78.2 173.4 169.3 14.77 14.42

March 117.2 6.17 125.9 121.3 262.5 256.6 14.55 14.22

April 158.2 14.15 164.1 158.9 328.8 321.6 13.98 13.68

May 154.8 17.56 156.3 151.4 306.8 299.8 13.70 13.38

June 183.5 24.20 184.0 178.2 352.9 345.3 13.39 13.10

July 182.2 27.18 183.8 178.2 347.3 339.8 13.19 12.90

August 167.0 25.91 169.9 164.4 322.6 315.6 13.25 12.96

September 128.6 19.62 136.0 131.4 267.1 261.2 13.70 13.40

October 113.2 15.36 126.7 121.8 252.7 247.2 13.91 13.61

November 62.5 8.32 71.8 68.3 146.2 142.6 14.22 13.86

December 56.4 6.44 67.1 63.5 136.8 133.3 14.22 13.86

Year 1456.5 14.13 1536.9 1481.3 3041.7 2973.1 13.81 13.50

Legends: GlobHor Horizontal global irradiation

T Amb Ambient Temperature

GlobInc Global incident in coll. plane

GlobEff Effective Global, corr. for IAM and shadings

EArray Effective energy at the output of the array

E_Grid Energy injected into grid

EffArrR Effic. Eout array / rough area

EffSysR Effic. Eout system / rough area

Page 3/316/01/14PVSYST V5.67

Grid-Connected System: Loss diagram




Loss diagram over the whole year

Horizontal global irradiation1457 kWh/m²

+5.5% Global incident in coll. plane

-3.6% IAM factor on global

Effective irradiance on collectors1481 kWh/m² * 14328 m² coll.

efficiency at STC = 16.76% PV conversion

Array nominal energy (at STC effic.)3557 MWh

-4.1% PV loss due to irradiance level

-4.1% PV loss due to temperature

-3.2% Array Soiling loss

-1.1% Module quality loss

-2.1% Module array mismatch loss

-0.8% Ohmic wiring loss

Array virtual energy at MPP3042 MWh

-2.3% Inverter Loss during operation (efficiency)

-0.0% Inverter Loss over nominal inv. power

0.0% Inverter Loss due to power threshold

0.0% Inverter Loss over nominal inv. voltage

-0.0% Inverter Loss due to voltage threshold

Available Energy at Inverter Output2973 MWh

Energy injected into grid2973 MWh

Page 1/328/12/13PVSYST V5.67






Simulation variant : West Secondary Sedimentation








Number of PV modules In series 44 modules In parallel 195 stringsTotal number of PV modules Nb. modules 8580 Unit Nom. Power 270 WpArray global power Nominal (STC) 2317 kWp At operating cond. 2083 kWp (50°C)Array operating characteristics (50°C) U mpp +/-626 V I mpp 1662 ATotal area Module area 13919 m²

Inverter Model AE 1000NX - 800 SINGLE MFGManufacturer Advanced Energy Industries, Inc.

Characteristics Operating Voltage +/-550-1000 V Unit Nom. Power 1000 kW ACInverter pack Number of Inverter 2 units Total Power 2000 kW AC






Page 2/328/12/13PVSYST V5.67








1

2

3

4

5

6

7

Nor

mal

ized

Ene

rgy

[kW

h/kW

p/da

y]




0.2

0.4

0.6

0.8

1.0

Per

form

ance

Rat

io P







January 59.4 2.44 69.2 65.7 140.4 136.8 14.58 14.21

February 73.6 1.26 81.9 78.2 168.5 164.4 14.77 14.42

March 117.2 6.17 125.9 121.3 255.0 249.2 14.55 14.22

April 158.2 14.15 164.1 158.9 319.5 312.5 13.98 13.68

May 154.8 17.56 156.3 151.4 298.1 291.2 13.70 13.38

June 183.5 24.20 184.0 178.2 342.9 335.4 13.39 13.10

July 182.2 27.18 183.8 178.2 337.4 330.0 13.19 12.90

August 167.0 25.91 169.9 164.4 313.4 306.5 13.25 12.96

September 128.6 19.62 136.0 131.4 259.5 253.7 13.70 13.40

October 113.2 15.36 126.7 121.8 245.5 240.1 13.91 13.61

November 62.5 8.32 71.8 68.3 142.1 138.5 14.22 13.86

December 56.4 6.44 67.1 63.5 132.9 129.5 14.22 13.86

Year 1456.5 14.13 1536.9 1481.3 2955.0 2887.9 13.81 13.50









Page 3/328/12/13PVSYST V5.67




















0.0% Inverter Loss over nominal inv. power






Page 1/428/12/13PVSYST V5.67






Simulation variant : Dual Purpose Sedimentation






PV Arrays Characteristics (2 kinds of array defined )


Array#1: Number of PV modules In series 44 modules In parallel 102 stringsTotal number of PV modules Nb. modules 4488 Unit Nom. Power 270 WpArray global power Nominal (STC) 1212 kWp At operating cond. 1089 kWp (50°C)Array operating characteristics (50°C) U mpp +/-626 V I mpp 870 A


Total Arrays global power Nominal (STC) 1815 kWp Total 6724 modulesModule area 10908 m²

Array#1 : Inverter Model AE 1000NX - 800 TRI MFGManufacturer Advanced Energy Industries, Inc.

Characteristics Operating Voltage +/-550-1000 V Unit Nom. Power 1000 kW AC

Array#2 : Inverter Model Solaron 500/EManufacturer Advanced Energy Industries, Inc.




Wiring Ohmic Loss Array#1 24 mOhm Loss Fraction 1.5 % at STCArray#2 17 mOhm Loss Fraction 1.5 % at STC

Global Loss Fraction 1.5 % at STC


Page 2/428/12/13PVSYST V5.67

Grid-Connected System: Simulation parameters (continued)


Page 3/428/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 6724 Pnom total 1815 kWpInverter Model AE 1000NX - 800 TRI MFG Pnom 1000 kW acInverter Model Solaron 500/E Pnom 500 kW acInverter pack Nb. of units 2.0 Pnom total 1500 kW acUser's needs Unlimited load (grid)




1

2

3

4

5

6

7

Nor

mal

ized

Ene

rgy

[kW

h/kW

p/da

y]




0.2

0.4

0.6

0.8

1.0

Per

form

ance

Rat

io P

R

Performance Ratio PR






January 59.4 2.44 69.2 65.7 110.0 107.2 14.58 14.21

February 73.6 1.26 81.9 78.2 132.0 128.7 14.77 14.41

March 117.2 6.17 125.9 121.3 199.9 195.2 14.55 14.21

April 158.2 14.15 164.1 158.9 250.3 244.8 13.98 13.67

May 154.8 17.56 156.3 151.4 233.6 228.2 13.70 13.38

June 183.5 24.20 184.0 178.2 268.7 263.0 13.39 13.11

July 182.2 27.18 183.8 178.2 264.4 258.9 13.19 12.91

August 167.0 25.91 169.9 164.4 245.6 240.4 13.25 12.97

September 128.6 19.62 136.0 131.4 203.3 198.9 13.70 13.41

October 113.2 15.36 126.7 121.8 192.4 188.3 13.91 13.62

November 62.5 8.32 71.8 68.3 111.3 108.5 14.22 13.86

December 56.4 6.44 67.1 63.5 104.1 101.5 14.22 13.86

Year 1456.5 14.13 1536.9 1481.3 2315.7 2263.7 13.81 13.50









Page 4/428/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 6724 Pnom total 1815 kWpInverter Model AE 1000NX - 800 TRI MFG Pnom 1000 kW acInverter Model Solaron 500/E Pnom 500 kW acInverter pack Nb. of units 2.0 Pnom total 1500 kW acUser's needs Unlimited load (grid)
















-0.0% Inverter Loss over nominal inv. power






Page 1/428/12/13PVSYST V5.67






Simulation variant : Nitrification Sedimentation






PV Arrays Characteristics (2 kinds of array defined )




Total Arrays global power Nominal (STC) 5008 kWp Total 18548 modulesModule area 30090 m²

Array#1 : Inverter Model Solaron 500Manufacturer Advanced Energy Industries, Inc.


Array#2 : Inverter Model AE 1000NX - 800 SINGLE MFGManufacturer Advanced Energy Industries, Inc.

Characteristics Operating Voltage +/-550-1000 V Unit Nom. Power 1000 kW ACInverter pack Number of Inverter 4.0 units Total Power 4000 kW AC



Wiring Ohmic Loss Array#1 18 mOhm Loss Fraction 1.5 % at STCArray#2 7.2 mOhm Loss Fraction 1.5 % at STC

Global Loss Fraction 1.5 % at STC

Array Soiling Losses Loss Fraction 3.0 %Module Quality Loss Loss Fraction 1.0 %Module Mismatch Losses Loss Fraction 2.0 % at MPP

Page 2/428/12/13PVSYST V5.67

Grid-Connected System: Simulation parameters (continued)

Incidence effect, ASHRAE parametrization IAM = 1 - bo (1/cos i - 1) bo Parameter 0.05


Page 3/428/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 18548 Pnom total 5008 kWpInverter Model Solaron 500 Pnom 500 kW acInverter Model AE 1000NX - 800 SINGLE MFGPnom 1000 kW acInverter pack Nb. of units 5.0 Pnom total 4500 kW acUser's needs Unlimited load (grid)




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0.2

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form

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R







January 59.4 2.44 69.2 65.7 303.5 295.9 14.58 14.22

February 73.6 1.26 81.9 78.2 364.2 355.4 14.77 14.42

March 117.2 6.17 125.9 121.3 551.4 539.0 14.55 14.23

April 158.2 14.15 164.1 158.9 690.7 675.8 13.98 13.68

May 154.8 17.56 156.3 151.4 644.4 629.7 13.70 13.39

June 183.5 24.20 184.0 178.2 741.2 725.3 13.39 13.10

July 182.2 27.18 183.8 178.2 729.3 713.7 13.19 12.90

August 167.0 25.91 169.9 164.4 677.5 662.9 13.25 12.96

September 128.6 19.62 136.0 131.4 560.9 548.6 13.70 13.40

October 113.2 15.36 126.7 121.8 530.6 519.3 13.91 13.62

November 62.5 8.32 71.8 68.3 307.1 299.4 14.22 13.86

December 56.4 6.44 67.1 63.5 287.3 279.9 14.22 13.86

Year 1456.5 14.13 1536.9 1481.3 6388.1 6244.9 13.81 13.50









Page 4/428/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 18548 Pnom total 5008 kWpInverter Model Solaron 500 Pnom 500 kW acInverter Model AE 1000NX - 800 SINGLE MFGPnom 1000 kW acInverter pack Nb. of units 5.0 Pnom total 4500 kW acUser's needs Unlimited load (grid)






















Page 1/328/12/13PVSYST V5.67






Simulation variant : Filtration and Disinfection Facility



Collector Plane Orientation Tilt 10° Azimuth -14°





Number of PV modules In series 14 modules In parallel 139 stringsTotal number of PV modules Nb. modules 1946 Unit Nom. Power 270 WpArray global power Nominal (STC) 525 kWp At operating cond. 472 kWp (50°C)Array operating characteristics (50°C) U mpp 399 V I mpp 1185 ATotal area Module area 3157 m²

Inverter Model Solaron 500Manufacturer Advanced Energy Industries, Inc.

Characteristics Operating Voltage 330-550 V Unit Nom. Power 500 kW AC



Wiring Ohmic Loss Global array res. 5.6 mOhm Loss Fraction 1.5 % at STC



Page 2/328/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth -14°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 1946 Pnom total 525 kWpInverter Model Solaron 500 Pnom 500 kW acUser's needs Unlimited load (grid)




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erfo

rman

ce R

atio

PR







January 59.4 2.44 70.5 67.0 32.55 31.74 14.63 14.26

February 73.6 1.26 83.8 80.1 39.16 38.20 14.81 14.45

March 117.2 6.17 127.9 123.4 58.87 57.40 14.58 14.21

April 158.2 14.15 164.8 159.6 72.85 71.06 14.00 13.66

May 154.8 17.56 156.7 151.7 67.79 66.06 13.70 13.35

June 183.5 24.20 183.3 177.4 77.44 75.59 13.38 13.06

July 182.2 27.18 183.3 177.6 76.29 74.50 13.18 12.87

August 167.0 25.91 171.7 166.3 71.95 70.26 13.27 12.96

September 128.6 19.62 137.3 132.6 59.43 58.01 13.71 13.39

October 113.2 15.36 128.6 123.7 56.57 55.28 13.94 13.62

November 62.5 8.32 73.6 70.2 33.16 32.30 14.27 13.90

December 56.4 6.44 69.7 66.2 31.47 30.65 14.30 13.93

Year 1456.5 14.13 1551.2 1495.8 677.53 661.04 13.84 13.50









Page 3/328/12/13PVSYST V5.67


























Page 1/316/01/14PVSYST V5.67






Simulation variant : Solids Processing Building









Inverter Model AE 250TXManufacturer Advanced Energy Industries, Inc. (AE)







Page 2/316/01/14PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 1001 Pnom total 270 kWpInverter Model AE 250TX Pnom 250 kW acUser's needs Unlimited load (grid)

Main simulation resultsSystem Production Produced Energy 320.5 MWh/year Specific prod. 1186 kWh/kWp/year



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January 59.4 2.44 69.2 65.7 16.38 15.23 14.58 13.56

February 73.6 1.26 81.9 78.2 19.65 18.28 14.77 13.74

March 117.2 6.17 125.9 121.3 29.76 27.66 14.55 13.53

April 158.2 14.15 164.1 158.9 37.27 34.65 13.98 13.00

May 154.8 17.56 156.3 151.4 34.77 32.33 13.70 12.74

June 183.5 24.20 184.0 178.2 40.00 37.19 13.39 12.45

July 182.2 27.18 183.8 178.2 39.36 36.59 13.18 12.26

August 167.0 25.91 169.9 164.4 36.56 33.98 13.25 12.32

September 128.6 19.62 136.0 131.4 30.27 28.14 13.70 12.74

October 113.2 15.36 126.7 121.8 28.64 26.62 13.91 12.93

November 62.5 8.32 71.8 68.3 16.58 15.42 14.22 13.22

December 56.4 6.44 67.1 63.5 15.50 14.42 14.22 13.23

Year 1456.5 14.13 1536.9 1481.3 344.73 320.50 13.81 12.84









Page 3/316/01/14PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 1001 Pnom total 270 kWpInverter Model AE 250TX Pnom 250 kW acUser's needs Unlimited load (grid)







Array nominal energy (at STC effic.)403.2 MWh







Array virtual energy at MPP344.8 MWh



-0.0% Inverter Loss due to power threshold



Available Energy at Inverter Output320.5 MWh

Energy injected into grid320.5 MWh

Page 1/328/12/13PVSYST V5.67






Simulation variant : Grit Chamber Building 1








Number of PV modules In series 11 modules In parallel 36 stringsTotal number of PV modules Nb. modules 396 Unit Nom. Power 270 WpArray global power Nominal (STC) 107 kWp At operating cond. 96.1 kWp (50°C)Array operating characteristics (50°C) U mpp 313 V I mpp 307 ATotal area Module area 642 m²

Inverter Model AE 100TX-480Manufacturer Advanced Energy Industries, Inc. (AE)







Page 2/328/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth -9°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 396 Pnom total 107 kWpInverter Model AE 100TX-480 Pnom 100 kW acUser's needs Unlimited load (grid)




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January 59.4 2.44 70.8 67.3 6.64 6.19 14.61 13.60

February 73.6 1.26 84.0 80.4 7.97 7.42 14.77 13.75

March 117.2 6.17 128.2 123.6 11.99 11.16 14.56 13.55

April 158.2 14.15 165.0 159.9 14.83 13.80 13.99 13.01

May 154.8 17.56 156.8 151.8 13.77 12.82 13.67 12.72

June 183.5 24.20 183.5 177.6 15.77 14.67 13.38 12.45

July 182.2 27.18 183.5 177.8 15.53 14.46 13.18 12.26

August 167.0 25.91 171.8 166.3 14.63 13.61 13.25 12.33

September 128.6 19.62 137.5 132.9 12.10 11.26 13.70 12.75

October 113.2 15.36 129.0 124.1 11.55 10.74 13.93 12.96

November 62.5 8.32 73.8 70.5 6.75 6.29 14.23 13.26

December 56.4 6.44 69.9 66.4 6.40 5.96 14.25 13.27

Year 1456.5 14.13 1553.7 1498.5 137.93 128.37 13.82 12.86









Page 3/328/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth -9°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 396 Pnom total 107 kWpInverter Model AE 100TX-480 Pnom 100 kW acUser's needs Unlimited load (grid)






















Page 1/328/12/13PVSYST V5.67
















Characteristics Operating Voltage 295-595 V Unit Nom. Power 100 kW ACInverter pack Number of Inverter 2 units Total Power 200 kW AC






Page 2/328/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 913 Pnom total 247 kWpInverter Model AE 100TX-480 Pnom 100 kW acInverter pack Nb. of units 2.0 Pnom total 200 kW acUser's needs Unlimited load (grid)




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January 59.4 2.44 69.2 65.7 14.93 13.90 14.57 13.57

February 73.6 1.26 81.9 78.2 17.87 16.63 14.73 13.71

March 117.2 6.17 125.9 121.3 27.12 25.23 14.54 13.53

April 158.2 14.15 164.1 158.9 33.98 31.60 13.98 13.00

May 154.8 17.56 156.3 151.4 31.68 29.48 13.68 12.73

June 183.5 24.20 184.0 178.2 36.48 33.94 13.39 12.45

July 182.2 27.18 183.8 178.2 35.89 33.39 13.18 12.26

August 167.0 25.91 169.9 164.4 33.34 31.01 13.25 12.32

September 128.6 19.62 136.0 131.4 27.59 25.67 13.69 12.74

October 113.2 15.36 126.7 121.8 26.12 24.30 13.91 12.94

November 62.5 8.32 71.8 68.3 15.10 14.06 14.20 13.22

December 56.4 6.44 67.1 63.5 14.10 13.12 14.18 13.20

Year 1456.5 14.13 1536.9 1481.3 314.17 292.33 13.80 12.84









Page 3/328/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 913 Pnom total 247 kWpInverter Model AE 100TX-480 Pnom 100 kW acInverter pack Nb. of units 2.0 Pnom total 200 kW acUser's needs Unlimited load (grid)






















Page 1/328/12/13PVSYST V5.67






Simulation variant : Central Maintenance Facility









Inverter Model Solaron 500Manufacturer Advanced Energy Industries, Inc.







Page 2/328/12/13PVSYST V5.67








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atio

PR







January 59.4 2.44 70.8 67.3 32.23 31.43 14.63 14.27

February 73.6 1.26 84.0 80.4 38.72 37.76 14.82 14.45

March 117.2 6.17 128.2 123.6 58.12 56.68 14.58 14.21

April 158.2 14.15 165.0 159.9 71.90 70.14 14.00 13.66

May 154.8 17.56 156.8 151.8 66.83 65.14 13.70 13.35

June 183.5 24.20 183.5 177.6 76.41 74.59 13.38 13.07

July 182.2 27.18 183.5 177.8 75.27 73.51 13.19 12.88

August 167.0 25.91 171.8 166.3 70.91 69.25 13.27 12.96

September 128.6 19.62 137.5 132.9 58.68 57.28 13.72 13.39

October 113.2 15.36 129.0 124.1 55.95 54.67 13.94 13.62

November 62.5 8.32 73.8 70.5 32.79 31.95 14.27 13.90

December 56.4 6.44 69.9 66.4 31.13 30.32 14.31 13.94

Year 1456.5 14.13 1553.7 1498.5 668.96 652.71 13.84 13.50









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Page 1/328/12/13PVSYST V5.67






Simulation variant : Secondary Blower Building








Number of PV modules In series 14 modules In parallel 21 stringsTotal number of PV modules Nb. modules 294 Unit Nom. Power 270 WpArray global power Nominal (STC) 79.4 kWp At operating cond. 71.4 kWp (50°C)Array operating characteristics (50°C) U mpp 399 V I mpp 179 ATotal area Module area 477 m²








Page 2/328/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 294 Pnom total 79.4 kWpInverter Model AE 75TX-208 Pnom 75.0 kW acUser's needs Unlimited load (grid)




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Normalized productions (per installed kWp): Nominal power 79.4 kWp



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Secondary Blower Building




January 59.4 2.44 69.2 65.7 4.80 4.47 14.55 13.56

February 73.6 1.26 81.9 78.2 5.74 5.34 14.68 13.68

March 117.2 6.17 125.9 121.3 8.72 8.12 14.52 13.52

April 158.2 14.15 164.1 158.9 10.93 10.18 13.96 13.00

May 154.8 17.56 156.3 151.4 10.18 9.48 13.65 12.71

June 183.5 24.20 184.0 178.2 11.74 10.93 13.38 12.45

July 182.2 27.18 183.8 178.2 11.54 10.75 13.17 12.26

August 167.0 25.91 169.9 164.4 10.72 9.98 13.23 12.32

September 128.6 19.62 136.0 131.4 8.88 8.27 13.69 12.75

October 113.2 15.36 126.7 121.8 8.41 7.83 13.91 12.95

November 62.5 8.32 71.8 68.3 4.85 4.52 14.16 13.20

December 56.4 6.44 67.1 63.5 4.54 4.23 14.17 13.20

Year 1456.5 14.13 1536.9 1481.3 101.04 94.10 13.78 12.84









Page 3/328/12/13PVSYST V5.67




Main system parameters System type Grid-ConnectedPV Field Orientation tilt 10° azimuth 37°PV modules Model OPT270-60-4-100 Pnom 270 WpPV Array Nb. of modules 294 Pnom total 79.4 kWpInverter Model AE 75TX-208 Pnom 75.0 kW acUser's needs Unlimited load (grid)



















0.0% Inverter Loss due to voltage threshold

