Loading...
HomeMy WebLinkAbout19H - ALTERNATIVE ENERGY STUDYREQUEST FOR COUNCIL ACTION CITY COUNCIL MEETING DATE: MARCH 5, 2019 CLERK OF COUNCIL USE ONLY: TITLE: APPROVED RECEIVE AND FILE WATER ENTERPRISE ❑ As Recommended ALTERNATIVE ENERGY FEASIBILITY ❑ As Amended STUDY NONGENERAL FUND E] Ordinance on sReading ( � ❑ 2 Ordinance on ntl Reading {STRATEGIC PLAN NO. 5, 2} ❑ Implementing Resolution ❑ Set Public Hearing For CONTINUED TO FILE NUMBER CITY MANAGER RECOMMENDED ACTION Receive and File DISCUSSION The City provides potable drinking water and sewage collection for all of the City's residents and businesses. To accomplish this, the City owns and operates a water and sewer system that consists of 870 miles of pipe, 22 groundwater wells, 4 pressure control stations, 7 import water connections, 7 water booster stations, 8 reservoirs, and 2 sanitary sewer lift stations. The groundwater wells, booster stations, and sewer lift stations consume a significant amount of energy to pump water out of the groundwater basin, maintain water system pressure, and maintain sewage flows. One of the objectives of the City's Strategic Plan is to expand opportunities for conservation and environmental sustainability. In this spirit, the Public Works Agency, Water Resources Division, with the assistance of a consultant, explored the feasibility of implementing alternative energy solutions at water system sites throughout the City. The 2019 Water Systems Alternative Energy Feasibility Study (Study) was developed to complete an independent and unbiased alternative energy feasibility assessment, and identify which alternative energy resources have the greatest economic opportunity and practical application for the City's water systems. The Study (Exhibit 1) finds that there does exist opportunities to develop alternative energy projects for the City's water systems and recommends a set of potential projects to be further developed. Highlights from the Study include the following: • The installation of three hydroelectric turbine generators • The installation of solar generation panels at six sites • A net effect of all projects is an investment of almost $8 million yielding a 25 -year savings of over $10 million in energy costs 19H-1 Water Enterprise Alternative Energy Feasibility Study March 5, 2019 Page 2 A reduction in electricity purchases of 25% A reduction in greenhouse gas emissions of 1,330 metric tons of CO2 equivalent Takes a major step toward reaching the goals established in the City of Santa Ana Climate Action Plan from 2015 The City of Santa Ana Water Resources department staff will utilize the Study to pursue grant funding opportunities and prepare future operations and capital improvements schedules with corresponding budgets. Staff will coordinate the Study's findings in conjunction with the current and future water rate studies, to provide a more environmentally responsible water system for City residents. STRATEGIC PLAN ALIGNMENT This item supports the City's efforts to meet Goal #5 - Community Health, Livability, Engagement & Sustainability, Objective #2 (expand opportunities for conservation and environmental sustainability). ENVIRONMENTAL IMPACT There is no environmental impact associated with this action. FISCAL IMPACT no fiscal impact associated with this action. 7 1-uao 5Jieiss, PE, PLS Executi a Director Public qorks Agency Exhibit: 1. 2019 Water Systems Alternative Energy Feasibility Study 19H-2 City of Santa Ana Public Works Agency Water Resources Division Water Systems Alternative Energy Feasibility Study Project Number: 2669.01 February 2019 NV=41144111 Newcomb I Anderson I McCormick A WILLDAN COMPANY 201 Mission Street, Suite 2000, San Francisco, CA 94105 1115 W. Sunset Blvd, Suite 8805, Los Angeles, CA 90012 fie -W13 1 19H-4 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study Foreword The City of Santa Ana Public Works Agency, Water Resources Division, hired Newcomb Anderson McCormick (NAM), a Willdan company, to evaluate the potential to offset some of their electricity purchases with renewable energy. The Agency uses electricity from Southern California Edison (SCE) at about 30 sites around the city for pumping out of wells and pressurizing the distribution system. NAM evaluated past records of pumping operations and electricity use; visited the prospective sites; and reviewed the 2017 Master Water Plan from the Agency. NAM also evaluated the potential to generate electricity from solar power by covering the water storage tanks with solar collectors and by recovering head from the water delivered directly from the Metropolitan Water District. This evaluation assumes that the hydro turbine at SA -1 would continue to generate renewable electricity at its current reduced capacity as a baseline. The savings in this report are the marginal additional savings that would be generated by a new turbine. NAM created cost estimates for constructing these projects and calculated the potential monetary savings by utilizing the new proposed SCE rate schedules, as opposed to the current rates. In addition, a life cycle cost analysis for each option was performed. NAM would like to thank the assistance in performing this project that was provided by Water Resources Manager, Nabil Saba and Assistant Engineer II, Brian Ige. CITY OF SANTA ANA 19H-5 Newcomb I Anderson I McCormick 19H-6 Job No. 2669.01 Water Systems Alternative Energy Feasibility St TABLE OF CONTENTS SECTION 1: EXECUTIVE SUMMARY............................................................................................................. 1 SECTION 2: INTRODUCTION........................................................................................................................ 3 SECTION 3: DESCRIPTION OF SANTA ANA POTABLE WATER DISTRIBUTION SYSTEM ................................ 4 SECTION 4: HISTORICAL WATER DELIVERY................................................................................................. 6 SECTION 5: HISTORICAL ELECTRICITY USE AND RATE SCHEDULES............................................................. 7 SECTION 6: POTENTIAL FOR HEAD RECOVERY AT MWD CONNECTIONS ................................................. 10 SECTION 7: POTENTIAL FOR SOLAR POWER GENERATION AT PUMP STATIONS AND CITY YARD........... 22 APPENDICES APPENDIX A— HISTORICAL ELECTRICITY PURCHASES APPENDIX B — 2017 MASTER WATER PLAN APPENDIX C— EXISTING BYRON JACKSON HYDRO TURBINE APPENDIX D—TURBINE PROPOSALS APPENDIX E— PLANT OPERATING RECORDS APPENDIX F— MONTHLY PRODUCTION REPORTS APPENDIX G—TURBINE COST ESTIMATES APPENDIX H — SOLAR MODEL PARAMETERS CITY OF SANTA ANA 19H-7 Newcomb I Anderson I McCormick 19H-8 SECTION 1: EXECUTIVE SUMMARY SECTION 1: EXECUTIVE SUMMARY 1 The City of Santa Ana Public Works Agency purchases 18,000,000 kWh per year to operate well pumps and booster pumps to deliver potable water to 45,000 customer meters. This report evaluates the potential to install on-site renewable energy systems to offset some of this electric load, lowering electric bills and reducing the associated greenhouse gas (GHG) emissions. The renewable energy resources evaluated include placing solar PV modules on the roofs of the storage tanks at five pump stations (Cambridge, East, Garthe, South and West), as well as at the City Yard; and recovering head from water that is delivered directly to the city from the Metropolitan Water District at a pressure that is higher than the city uses (SA -1 replacement, SA -3, SA -6). The implementation cost and energy savings have been calculated for these projects and a life cycle cost analysis has been performed for the anticipated 25 -year life of the equipment. The following table shows the anticipated overall cost and benefit projected for the city. 1.1.3 The net effect of all these project is an investment of almost $8 million with 25 years of savings that will exceed the investment by about $2 million. This is not a great financial investment, but it is a good step in implementing the Climate Action Plan with a project that pays for itself. The implementation of these projects would reduce the Water Resources Divisions purchase of electricity by 25% compared to 2016. This would also reduce the GHG emissions of 1,330 Metric tons of CO2 equivalent by a similar percentage from 2016. As the SCE fuel mix changes to less GHG from year to year, the GHG savings will Newcomb I Anderson I McCormick 19H-9 CITY OF SANTA ANA Turbine SA -1 ($638,763) $38,441 $858,509 $0.090 425,299 Turbine SA -3 ($835,988) $31,965 $409,035 $0.060 536,973 Turbine SA -6 ($1,072,174) $55,131 $1,075,182 $0.065 845,901 Solar Garthe Station ($1,404,000) $38,165 ($148,834) $0.043 894,325 Solar South Station ($194,832) $3,492 ($77,488) $0.046 75,170 Solar West Station ($707,940) $39,780 $635,398 $0.094 422,617 Solar East Station ($677,160) $19,080 ($43,018) $0.048 393,985 Solar Cambridge Station ($334,800) $8,332 ($67,435) $0.045 184,480 Solar City Yard ($1,890,767) $46,325 ($298,129) $0.053 869,805 Total Total ($7,756,424) $280,711 $2,343,220 $0.060 4,648,554 The net effect of all these project is an investment of almost $8 million with 25 years of savings that will exceed the investment by about $2 million. This is not a great financial investment, but it is a good step in implementing the Climate Action Plan with a project that pays for itself. The implementation of these projects would reduce the Water Resources Divisions purchase of electricity by 25% compared to 2016. This would also reduce the GHG emissions of 1,330 Metric tons of CO2 equivalent by a similar percentage from 2016. As the SCE fuel mix changes to less GHG from year to year, the GHG savings will Newcomb I Anderson I McCormick 19H-9 CITY OF SANTA ANA 2 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study shift accordingly. The City of Santa Ana Climate Action Plan from 2015 indicates that the goal for municipal operations is a CO2e reduction of 30% by the year 2020 and 40% by 2035, relative to the 2008 baseline. It is recommended that the City consider investment in these projects to help achieve the GHG goals, while saving money over the life of the project. The summary table shows the effective cost per kWh at which electricity is being saved. Some of the savings are valued at less than the City currently pays for the electricity due to reasons described in this report. These include anticipated new SCE rates that will shift summer on peak hours later, so little solar power will be generated when it is most highly valued. In other cases where there is not a large existing load (such as SA -3 and SA -6) the power must be wheeled to other meters, which lowers its value. Substituting NEMA wheeling of this power for RES -BCT (described in the report) is a way to significantly increase the value of the electricity for these sites, but SCE would need to approve the arrangement. 1. The Total Installed Cost for the turbine projects includes the anticipated construction contract (labor, materials, tax, overhead and profit), contingency, engineering, and project management, minus a potential incentive for SA -1. See Appendix G. 2. The Total Installed Cost for the solar projects includes the anticipated construction contract, contingency, engineering, project management, and an upfront payment for a performance guarantee. The life cycle numbers include an annual maintenance agreement as well. See Appendix H. 3. The economic analysis assumes that electric rates will escalate at 3.5% per year and that the PV performance will degrade at 0.5% per year. The Net Present Value is calculated with a Discount Rate of 3%. See Appendix H. CITY OF SANTA ANA 19H-10 Newcomb I Anderson I McCormick SECTION 2: INTRODUCTION SECTION 2: INTRODUCTION 3 The City of Santa Ana Public Works Agency operates a water distribution system to deliver potable water to 45,000 meters throughout the city, using a series of pipes, pumps, tanks and wells. The Agency delivers an average of 33.5 million gallons per day (MGD) of water, purchasing 18,000,000 kWh of electricity annually to operate the pumps and other loads. The Agency's average electric load is a little over 2 megawatts. This electricity is purchased from Southern California Edison through meters at pump stations and wells on several different rate schedules. The GHG released in the generation of this electricity, based on the average Southern California Edison (SCE) rates used in the Santa Ana Climate Action Plan, is 0.286 metric tons of CO2 equivalent per Megawatt hour (MWh), or a total of 5,148 metric tons per year. This report evaluates the potential to generate renewable electricity to offset some of the cost of this pumping power and to reduce the GHG impact of this electricity use. The two local renewable resources evaluated in this report are the generation of solar power with photovoltaic (PV) modules mounted on storage tanks and carports at the City Yard, and the recovery of head from water delivered to the city system by the Metropolitan Water District. Newcomb I Anderson I McCormick 19H-1 1 CITY OF SANTA ANA 4 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study SECTION 3: DESCRIPTION OF SANTA ANA POTABLE WATER DISTRIBUTION SYSTEM The following information comes from discussions with the Agency engineers, observations at a number of pump stations, and a review of the 2017 Santa Ana Water Masterplan. 3.1 ZONES The city is divided into two zones for potable water supply, the small upper or north zone (northeast of Interstate 5), and the lower or main zone covering the rest of the city. The upper zone is kept at a pressure of about 100 psig, while the main zone was observed to have a pressure of about 70 psig as water leaves the booster pumps, with a lower pressure as it flows through the distribution system. 3.2 TANKS The City of Santa Ana Public Works Agency stores its water in grade level atmospheric tanks, or reservoirs, located around the city, with a total capacity of about 49 million gallons. The tanks are typically from 17 to 35 feet high, with water kept within several feet of the top. This is enough water to serve the city's typical load for more than a day, although it is important to keep the tanks relatively full to meet potential emergency requirements. 3.3 BOOSTER PUMPS Booster pumps (totaling a capacity of 105 million gallons per day and 3,975 hp motor capacity) at each of the tanks pressurize this water from about 6 to 12 psig in the tank to approximately 70 psig for distribution to customers in most of the city, or 100 psig in the upper zone. 3.4 WELL PUMPS Most water is supplied to these tanks by well pumps distributed around the city (21 pumps totaling 5,300 hp in motor capacity). These wells have the capacity to deliver 74 million gallons per day, pumping from a depth of 100 to 300 feet. Fourteen of these well pumps deliver water to the tanks, pumping to 6 to 12 psig. Seven well pumps feed directly into the higher distribution pressure, corresponding to the distribution pressure in that zone. Groundwater in this aquifer is managed by the Orange County Water District in coordination with Metropolitan Water District (MWD). 3.5 MWD CONNECTION POINTS About 25 to 30% of the City's water is delivered directly by MWD to the city's pressurized distribution system through 7 connection points around the city. The connection points use pressure reducing valves (PRVs) to drop the pressure from approximately 160 to 190 psig in the MWD pipes to the city pressure of approximately 70 psig, or 100 psig in the case of SA -6, the one connection in the upper zone. CITY OF SANTA ANA 19H-12 Newcomb I Anderson I McCormick SECTION 3: DESCRIPTION OF SANTA ANA POTABLE WATER DISTRIBUTION SYSTEM 5 One Connection Point, SA -1, has a hydro turbine to generate electricity with some of this pressure differential. Its operation will be discussed later in the report. The design capacity of these 7 connections is 87 million gallons per day, but they are typically operated at lower flow rates. 3.6 ELEVATIONS The city has relatively little change in elevation and the water is maintained in one distribution system for the main zone, more or less at the same pressure and elevation throughout most of the city. The analysis will assume that the small differences in elevation do not affect the performance of the systems. 3.7 WASTEWATER The Agency also operates two wastewater lift stations to deliver it to the regional treatment plant, although these are a small fraction of the annual electrical use. Newcomb I Anderson I McCormick 19H-13 CITY OF SANTA ANA 6 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study SECTION 4: HISTORICAL WATER DELIVERY Per the 2017 Master Water Plan, the City of Santa Ana delivers an average potable water flow of 33.5 MGD, with a maximum daily flow of 45.2 MGD. This total water use is about 12 billion gallons per year, with a peak flow rate of 45,000 gallons per minute (gpm) and an average flow rate of 23,000 gpm. The projection for growth in the Master Plan is fairly moderate, with an anticipated Near -Term average daily load rising to 34.9 MGD, and the full buildout (2040) average load rising to 35.5 MGD, 6% higher than today's load. This analysis will not evaluate the potential effects of increasing loads in the future, because the growth rate is expected to be quite low. CITY OF SANTA ANA 19H-14 Newcomb I Anderson I McCormick SECTION 5: HISTORICAL ELECTRICITY USE AND RATE SCHEDULES 7 SECTION S, HISTORICAL ELECTRICITY USE AND BATE SCHEDULES The Agency purchased 18,284,786 kWh in calendar year 2016. This implies an average use of 2,087 kW throughout the year. Note that the Agency used somewhat more electricity than this, but a portion of this use was offset by the existing hydro generator. There are 31 main Southern California Edison (SCE) electric meters throughout the city serving the water system. Some of these just serve one well pump or one pressure reducing valve. Other meters serve multiple booster pumps and well pumps at a given pump station. 5.1 RATE SCHEDULES The largest electric loads are served by TOU-8-13 rate schedules. Smaller pumping loads are served by TOU-PA-3 and TOU-PA-2 rate schedules. Other meters that just serve a pressure reducing valve (instrumentation, light, ventilation) are served by the TOU-GS-1 rate schedule. These are all Time of Use rate schedules. The most expensive electricity is sold during the summer On Peak period, which occurs from noon to 6 pm on weekdays during June, July, August and September. SCE announced in 2017 its intention to change the hours which are billed as On Peak, reflecting the amount of solar energy on their grid during the middle of the day. The proposed On Peak hours are 4 pm to 9 pm on weekdays, representing the new grid peak demand when loads are high and are not offset by solar generation. The proposal is currently under negotiation with the California Public Utilities Commission. The final outcome is uncertain, but the consensus is that the new On Peak period will be as requested by SCE, or within an hour of the request. Projects in this report will be evaluated based on the SCE proposed rate schedule. Even though it is not finalized, the proposed rate schedule should give a more accurate picture of the likely savings from these projects. The new time of use periods will not have a significant impact on the hydro turbine project because the turbines will typically operate the same during the afternoons as they do during the evenings. The new time of use periods, however, will adversely impact the value of solar energy. Under the current rate schedule most of the solar energy generated offsets the more expensive electricity of the On Peak and Mid Peak periods. Under the proposed rate schedule most solar energy will offset the less expensive Off Peak electricity during the summer and Super Off Peak electricity during the winter. The solar savings are calculated by calculating the performance of the solar system for every hour of the year, based on a Typical Meteorological Year, and applying the energy and demand costs for that hour to assemble a bill for every month of the year. Newcomb I Anderson I McCormick 19H-1 5 CITY OF SANTA ANA 8 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study 5.2 NET ENERGY METERING Net Energy Metering is an arrangement with SCE to give near -full retail value for renewable electricity to the customer who generates it. If the customer is generating more renewable electricity than the site is using, the net electricity is taken by SCE and credited to the customer for the retail value at the time the power is delivered. The solar projects will take advantage of this around noon at their peak output. They may be generating more power than the site is using, but they get compensated at the retail rate in effect whenever the power is exported. Solar projects attempting to offset a significant portion of the site load often export power during the middle of the day and import it the rest of the day. Without Net Energy Metering any excess electricity exported to SCE would be compensated at a few pennies a kWh. 5.3 NET ENERGY METERING AGGREGATION Net Energy Metering Aggregation (NEMA) is an arrangement with the utility to allow a site that generates more electricity than it uses over the course of the year to use the excess electricity to offset load on adjacent sites owned by the city. For example, if a renewable system were installed on one parcel and it generated more electricity than the loads on that parcel used in a year, the excess electricity could be used to offset electricity use at an adjacent parcel at retail rates. If Lot 1 had a renewable power source and it touched Lot 2 but not Lot 3, but Lot 2 touched Lot 3, then the Lot 1 power can be used to offset the Lot 3 load. A chain of contiguous sites can be used to pass power from one end to the other, even if it is not used by the middle sites. There are several sites that we anticipate will generate more electricity than they use. These include the hydro turbines at SA -3 and SA -6. The two turbine sites are offsetting very small loads at each site, as opposed to SA -1 which has a large pump load at the site to offset. One can make the argument that the SA -3 and SA -6 parcels are contiguous to the parcel the street is on, and all are owned by the city. That parcel is likely contiguous with all other parcels that hold streets and all are owned by the city. If this is the case, the power from one site, say the South Station, could be used at any city parcel contiguous with a street to offset electricity loads at retail rates. We have not seen this done before, but it is worth an attempt to maximize the value of the electricity. We raised the question with SCE NEM Customer Interconnection Services and they responded as follows: For the purpose of NEM Aggregation, Schedule NEM -ST. Special Condition 5 speaks to the eligibility requirements in great detail and addresses a few of your questions about parcel contiguity and eligibility, so I would recommend giving that a thorough read (a section touches on public thoroughfares/streets). From what you describe below, it sounds as though this may qualify for NEM -A, assuming there are no parcel adjacency/contiguity issues or other eligibility concerns mentioned in Schedule NEM -ST. Best Regards, NR NEM Customer Interconnection Services Southern California Edison Customer.Generation@sce.com (866)600-6290 CITY OF SANTA ANA 19H-16 Newcomb I Anderson I McCormick SECTION 5: HISTORICAL ELECTRICITY USE AND RATE SCHEDULES 9 This is the preferred rate schedule to use with this project, but if it is not available, rate schedule RES -BCT will work. 5.4 RENEWABLE ENERGY SELF -GENERATION -BILL CREDIT TRANSFER (RES - BCT) A more conventional approach to using excess renewable generation at one site to offset electricity use at another site is RES -BCT. This approach requires that the sites have the same owner, but they do not need to be contiguous. One Generating Account can deliver power to up to 50 Benefitting Accounts. This could assure that excess power at the South Station and the two hydro turbines could always be used to offset energy use at various pump loads. The disadvantage to RES -BCT is that the full retail value of the electricity does not get transferred to the other meter. The Generation portion of the rate transfers, but the Delivery Service (Transmission and Distribution) does not transfer. Under the Schedule TOU-GS-1-13 likely to be used, this excludes a portion of the monetary savings. These projects are evaluated in this report using the RES -BCT rate, which is the likely default. They will also be evaluated using the NEMA rate, which is more beneficial to the City, but not guaranteed to be accepted, should it be pursued with SCE. Newcomb I Anderson I McCormick 19H-17 CITY OF SANTA ANA 10 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study SECTION 6: POTENTIAL FOR HEAD RECOVERY AT MWD CONNECTIONS 6.1 METROPOLITAN WATER DISTRICT CONNECTIONS The Santa Ana water system has seven connection points with the Metropolitan Water District, SA -1 through SA - 7. Each station contains a pressure reduction controller to convert from MWD pressure to city water pressure. MWD pressure typically ranges from 160 to 190 psig, per logs of plant operation. City water is typically controlled at 63 to 75 psig. There are one to three pressure reducing valves at each station to regulate pressure, sized for different flow rates. Flow at a station is typically manually set at a given rate for weeks or months at a time, counting on the booster pumps to automatically cycle or change speed, to fine tune pressure in the distribution system. A number of these pumps operate with Variable Frequency Drive controls to more closely match the loads. The flow through each of these connection points is shown in the following table, derived from the city's Monthly Production Reports. This is monthly data for calendar year 2017 and is taken to be representative of flows in typical years. Cubic Feet Jan -17 SA -1 SA 400 -2 SA -3 - 500 SA -4 5A-5 - SA76 - 2,410,100 SA -7 2,402,400 Tota I 4,813,400 Feb -17 4,511,700 - 2,399,600 - - 13,949,500 8,302,400 29,163,200 Mar -17 5,350,500 - 5,739,400 - - 16,551,800 - 27,641,700 Apr -17 19,539,100 - 6,567,100 - - 25,336,200 3,395,800 54,838,200 May -17 20,903,300 - 9,248,200 - - 21,477,600 - 51,629,100 Jun -17 14,247,700 - 9,197,300 - - 21,670,300 4,672,800 49,788,100 Jul -17 21,471,100 - 10,073,800 - - 21,487,200 - 53,032,100 Aug -17 21,467,200 - 7,686,100 8,629,900 - 26,616,400 - 64,399,600 Sep -17 20,771,300 - 9,723,300 16,652,200 - 31,517,800 143,900 78,808,500 Oct -17 21,131,000 - 17,444,100 11,249,200 - 32,394,700 308,300 82,527,300 Nov -17 20,539,500 - 19,375,700 - - 20,765,900 - 60,681,100 Dec -17 21,451,800 - 19,702,700 - - 21,367,300 - 62,521,800 2017 Cubic Feet per Year 191,384,600 - 117,157,800 36,531,300 - 255,544,800 19,225,600 619,844,100 Total water delivered by MWD peaks in the fall months and is close to zero during January. Note that some interconnection points were not used at all in 2017, and some were used minimally. (SA -5 was out of service, per the 2017 Water Master Plan.) The following table shows the Normal Operating Capacity for each MWD connection, as listed in the 2017 Water Masterplan, and its equivalent in CFS. CITY OF SANTA ANA 19H-18 Newcomb I Anderson I McCormick SECTION 6: POTENTIAL FOR HEAD RECOVERY AT MWD CONNECTIONS MWD Connection SA -1 Bristol Normal Operating Capacity (MGD) 5.17 Operating Capacity CFS) 8.0 SA -2 First 5.17 8.0 SA -3 McFadden 5.17 8.0 SA -4 Warner 4.85 7.5 SA -5 Alton 4.85 7.5 SA -6 Santa Clara 7.76 12.0 SA -7 Red Hill 4.85 7.5 Total 37.82 58.5 11 One can see in the monthly water meter readings that station SA -1 delivered an almost constant flow from April through December, illustrating that the valves are sometimes fully opened for a month or more. This monthly flow of about 21 million cubic feet is equivalent to 8 CFS, the Normal Operating Capacity listed for this station. Similarly, station SA -3 operated at close to 8 CFS for all the hours of November and December. SA -6 operated at 12 CFS for all the hours of September and October. The following table shows the calculated percent operating time for each station by month in 2017. Normal Operating Capacity (CFS) MWD Connection Jan -17 Feb -17 Mar -17 Apr -17 May -17 Jun -17 Jul -17 Aug -17 Sep -17 Oct -17 Nov -17 Dec -17 8.0 8.0 8.0 7.5 7.5 12.0 7.5 SA -1 SA -2 SA -3 SA -4 SA -5 SA -6 SA -7 0% 0% 0% 0% 0% 7% 12% 23% 0% 12% 0% 0% 48% 46% 25% 0% 27% 0% 0% 51% 0% 94% 0% 32% 0% 0% 81% 17% 98% 0% 43% 0% 0% 67% 0% 69% 0% 44% 0% 0% 70% 24% 100% 0% 47% 0% 0% 67% 0% 100% 0% 36% 43% 0% 83% 0% 100% 0% 47% 86% 0% 101% 1% 99% 0% 81% 56% 0% 101% 2% 99% 0% 93% 0% 0% 67% 0% 100% 0% 92% 0% 0% 66% 0% It is understood that the MWD connections are typically operated fully open or fully closed. During months when the flow is less than this capacity, it is assumed that during some hours of the month this full rate is used and during the other hours of the month the flow is zero. Newcomb I Anderson I McCormick 19H-19 CITY OF SANTA ANA 12 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study In the evaluation of hydro turbines to make electricity from the excess pressure, this suggests that the efficiency at this design flow is important, but the partial flow efficiency is not critical. The monetary benefits for this project will be calculated according to the SCE rate schedules that are used for each account. When a unit operated, say 23% of the hours in a month, it will be assumed that this implies it operates 23% of the On Peak hours, 23% of the Mid Peak hours and 23% of the Off Peak hours. A demand savings for a given month is only be included if the unit operates at least 95% of the hours that month to keep the savings fairly conservative. The historical flow data is converted into anticipated full load operating hours per month for each MWD connection in the following table. calculated operating Hours Operating Capacity MWD SA -1 Connection per Month SA -2 at Normal SA -3 SA -4 SA -5 - SA -7 Total SA -6 Jan -17 0 - 0 SA -5 56 89 145 Feb -17 157 - 83 3% 323 307 870 Mar -17 186 - 199 383 - 768 Apr -17 678 - 228 586 126 1,619 May -17 726 - 321 497 - 1,544 Jun -17 495 - 319 502 173 1,489 Jul -17 746 - 350 497 - 1,593 Aug -17 745 - 267 320 - 616 - 1,948 Sep -17 721 - 338 617 - 730 1 5 2,410 Oct -17 734 - 606 417 - 750 11 2,517 Nov -17 713 - 673 - 481 - 1,867 Dec -17 745 - 684 - - 495 - 1,924 Total 6,645 - 4,068 1,353 - 5,915 712 The following table shows the total water flow in 2017 by connection point. Note that three connection points, SA -1, SA -3 and SA -6 represent 91% of all the MWD flow for the year. These three stations will be investigated for the potential to generate power from this water flow. IMWD Connection SA -1 2017 Cubic Feet per Year 191,384,600 Percent of MWD Flow 31% SA -2 - 0% SA -3 117,157,800 19% SA -4 36,531,300 6% SA -5 - 0% SA -6 255,544,800 41% SA -7 19,225,600 3% Total 619,844,100 100% CITY OF SANTA ANA 19H-20 Newcomb I Anderson I McCormick SECTION 6: POTENTIAL FOR HEAD RECOVERY AT MWD CONNECTIONS 13 6.2 MWD STATION SA -1 Station SA -1 is the only MWD connection point where electricity is currently generated. The generator is in a pump building at the Garthe Pumping Station. MWD water is fed through a Byron Jackson two stage hydro turbine, which drives a 200 hp Siemens Allis generator to offset purchases of electricity for the wells and booster pumps at this site. The address of this station is 2401 N. Bristol Street. The SCE Service Account number is 3- 001-3273-57 and the Rate Schedule is TOU-PA-3-B-S. The configuration of this turbine installation is shown in Figure 1. After the discharge of the turbine there is a manual control valve (fully open during the site visit) and a pressure regulating valve to drop the pressure as needed to match the City pressure. The MWD pressure observed at SA -1 during July 2018 was 164 psig, while the City system pressure was observed to be 73 psig. Figure 1. SA -1 Existing Configuration (July 2018) Generator Ball Valve 68 kW with Motorized Flow Controller 164 f=j127 73 DSIG PSIG r1 PSI( Turbine PRV Pump Room [d Motorized MWD I.:I pRV �.:� To Santa Ana Distribution The pressure after the turbine and before the PRV was observed to be 127 psig per the local meter. This means a pressure drop of 37 psi, or 85 feet through the turbine. The flow at this time was 8.2 CFS and the turbine was metered at 68 kW of electrical power. Note that the theoretical power can be calculated from flow and pressure drop as follows. This calculation assumes a turbine mechanical efficiency of 70%. This low pressure drop puts the turbine outside its normal operating range, so the efficiency is only an assumption. 8.2 ft3hp sec 62.4 lbs 0.746 kW sec x 85 ft x 550 ft lbs x fta x 70% mech. 95% elect.eff x hp = 39 kW The theoretical power production under these conditions is estimated at 39 kW, while the electric meter reads 68 kW. We will assume that the electric meter is reading correctly here, as that gives more conservative results Newcomb I Anderson I McCormick 19H-21 CITY OF SANTA ANA 14 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study for the project. This would mean that perhaps the intermediate pressure meter was not reading accurately. The original design submittal for the turbine showed a selection point at 8.0 CFS and 200 feet. Note, there are two stages of the turbine in series, so the pressure -drop for each stage (100 feet) is added together to get the total pressure drop of 200 feet. Historical logs available for 2006 and earlier indicate the following typical operation points: • MWD pressure at 165 to 190 psig. (average 177 psig) • Mid pressure at 68 to 75 psig. (average 71 psig) • System pressure at 60 to 69 psig. (average 64 psig) • This corresponds to the generator putting out 130 to 165 kW of power output. (average 147 kW) The pressure -drop in previous years averaged 106 psi through the turbine, or 244 feet of water, closer to its design drop of 200 feet. This leads us to the conclusion that the head recovery system is not currently working properly, as less head is dropped through the turbine than shown in the design or shown in historical operation records. It is assumed for this report that the observed operations represent the actual baseline operations for this unit. The unit is about 32 years old and was rebuilt about 14 years ago. It is assumed that the inefficiencies in the current operations represent the typical operating conditions due to the condition of the turbine, or its controls, or the PRV's controls, and that this can be considered the baseline operation of the system. If the Agency has a quick -fix and can lower the discharge pressure of the turbine back to about 71 psig, that can then be treated as the baseline of operations for this project. 6.3 POTENTIAL PROJECT AT SA -1 The proposed project for SA -1 is to replace the hydro -generator with a new unit, as illustrated in Figure 2. The new unit would be designed around the parameters the original unit was built for. The original operation was called out for a flowrate of 8 CFS. This is the flowrate that the unit is typically controlled to. CITY OF SANTA ANA 19H-22 Newcomb I Anderson I McCormick SECTION 6: POTENTIAL FOR HEAD RECOVERY AT MWD CONNECTIONS 1s MWD Figure 2 SA -1 Proposed Configuration Ball Valve New Generator with Motorized Flow Controller Normally Normally open Open New Turbine PRV Pump Room Motorized To Santa Ana Distribution ............. New Construction The original pressure drop was designed for 200 feet, or 87 psi. The actual pressure drop appears to range from 217 to 275 feet, or 94 to 119 psi. A turbine should be selected that operates well over this pressure range. For the purposes of this analysis, a single operating pressure differential will be used. The midpoint of the observed pressure ranges is 245 feet, or 106 psi. One potential turbine that could be used in place of the Byron Jackson turbine is a Canyon Hydro In -Line Turbine ILT12-33-9.0. This turbine has a 12 -inch supply and discharge pipes in the same configuration as the current turbine, with a vertical axis and the generator mounted above the turbine. A proposal for this turbine generator package is contained in the Appendix. Another proposal is presented for a turbine with a horizontal axis manufactured by Gilkes. In this case the Canyon turbine is less expensive and matches the geometry of the existing installation. The Canyon Hydro turbine curve indicates a mechanical efficiency of 83.5% at the design point of 8 CFS and 245 feet. This implies an electrical output calculated as follows: 8.0 ft3hp sec 62.4 lbs 0.746 kW sec x 245 ft x 550 ft ibs x ft3 x 83.5%meth of f.x 95%elect. of f x hp =132 kW Through the installation of a new hydro -turbine and generator at SA -1, the output of the generator will increase from 68 kW to 132 kW. This will happen for the 6,645 hours per year that this connection is in use, for an electrical savings of 425,280 kWh per year. Note, the existing turbine is calculated to generate 68 kW x 6,645 hours per year, or 425,299 kWh per year of renewable electricity. Newcomb I Anderson I McCormick 19H-23 CITY OF SANTA ANA 16 job No. 2669.01 Water Systems Alternative Energy Feasibility Study When this savings is applied to the appropriate hours for each month with the rate schedule in use at the site, the monetary savings for one year is projected to be $38,441. The electricity saved through this rate schedule is worth approximately $0.09 per kWh on rate TOU-PA-3-E. The projected cost to purchase and install the new hydro turbine is $718,000. This involves removing the existing turbine/generator and installing a new, similar unit and connecting it to the electrical and control systems. Interconnection with SCE is required for this project, but since the turbine is small relative to the site load, and since a turbine generator has been tied to SCE in the past, a large effort is not projected. The Pressure Reduction Turbine project at SA -1 is likely eligible for an SCE incentive through the statewide Self Generation Incentive Program. This is currently offering $600 per kW for this type of installation. This incentive of $79,200 would lower the capital cost of the project to $638,763. Note that half of this incentive is likely to be payable upfront, while the other half is payable over the first five years of operation. For simplicity's sake it is all being treated as an upfront incentive. Only the SA -1 is eligible for an incentive under the SGIP program. This turbine will offset electricity already used at the site. Since the turbines at SA -3 and SA -6 will primarily export power to other sites, as they have no significant power use onsite to offset, they likely do not qualify for the SGIP incentive. Also, SGIP incentives for solar power generation were fully expended a number of years ago. In this application, the demolition of the existing unit is expected to include the removal of the generator, turbine shaft, impellers and upper housing. The existing turbine has a large bell set in concrete to house the impellers which hang down from the frame. This bell can likely be filled with rebar and concrete to form the foundation for the new turbine, whose impeller does not hang lower than the inlet and outlet pipes. The typical design of a head recovery turbine puts it in parallel with the existing PRV. Water flow through the turbine is the first loading order, controlled to a setpoint such as 8 CFS by the turbine wicket gates. If the resulting flow does not meet the pressure requirements of the plant discharge, the parallel PRV can open to maintain the desired pressure setpoint. In this case, the parallel PRV is installed in a room at a lower elevation than the existing turbine. However, it is expected that the turbine alone would operate normally when the 8 CFS flow is desired. In the new scenario, the manual valve and PRV installed in series with the turbine not necessary. A new automated valve will be installed upstream of the turbine to provide a remote shut off for water flow through the turbine. The existing manual valve and PRV in series with the turbines can be opened fully or removed to create a smaller pressure drop. The existing turbine generator is 32 years old, presumably approaching the end of its useful life. Should the turbine fail the baseline generation would be zero kWh per year. In that case the installation of the new turbine would increase net -generation by 877,140 kWh per year. When this savings is applied to the appropriate hours each month the monetary savings for one year is projected to be about $90,000. Note that these savings assume that the rate schedule remains unchanged for the meter that serves the whole site. CITY OF SANTA ANA 19H-24 Newcomb I Anderson I McCormick SECTION 6: POTENTIAL FOR HEAD RECOVERY AT MWD CONNECTIONS 17 6.4 MWD STATION SA -3 The pressure reducing station SA -3 is installed in a vault under the sidewalk at the south east corner of Bristol Street and McFadden Avenue. The configuration is shown in Figure 3, with one PRV and two isolation valves, approximately eight feet below the sidewalk. The SCADA monitoring and associated electrical meter are installed in small cabinets mounted nearby on the sidewalk. The SCE Service Account is 3-035-8796-80 and the Rate Schedule is TOLI-GS-1-A. The PRV flow rate is typically controlled to 8 CFS when in use. The observed pressure drop was from 172 to 85 psig, according to the installed pressure gages. 1..WTI �: Figure 3 SA -3 Existing Configuration Vault Under Sidewalk 6.5 POTENTIAL PROJECT AT SA -3 To Santa Ana Distribution The proposed project at SA -3 is to install a new hydro -turbine generator in parallel with the existing Pressure Reducing Valve. There is no room in the existing vault, so a new vault would be required side by side with the existing vault. This is illustrated in Figure 4. The new vault would contain the new hydro -turbine and generator, a remotely controlled valve on the inlet of the turbine and an isolation valve on the discharge, an electrical panel to control the turbine and take power from it, a new metered connection to deliver the power to SCE, and some additional SCADA points. Newcomb I Anderson I McCormick 19H-25 CITY OF SANTA ANA 18 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study Figure 4 SA -3 Proposed Configuration New Vault ® New Construction When the Agency needs 8 CFS through this station it would open flow through the turbine, using a combination of the automated valve and the wicket gates to minimize sudden pressure changes. The existing PRV could be kept at a higher setpoint so that it does not typically operate unless there were an unusual demand for water at this point. The control valve and wicket gates would be remotely operated to shut down flow in the turbine when appropriate as well. The electricity generated by the hydro turbine at this location cannot offset an adjacent City of Santa Ana load, as the only electric load at this location is instrumentation and lighting. It is anticipated that the generated electricity will be used to off -set another city meter through the Renewable Energy Self -generation Bill Credit Transfer mechanism know as RES BCT. This allows the value of electricity generated by the turbine to be metered by SCE on a TOU-GS-1 rate schedule. The dollar value of this electricity can be used to offset the generation component at one or more city electric meters. The anticipated generation of electricity from this turbine at 8 CFS and the standard pressure drop means it will generate the same average electric output as the SA -1 installation, 132 kW. In the case of SA -3, the anticipated full load hours of operation are expected to be 4,068 hours per year, so the anticipated energy generation is 536,976 kWh per year. The monetary value for this savings based on the RES -BCT Generation portion of the TOU-GS-I-LG rate schedule is $31,965 per year. The electricity is worth about $0.06 per kWh through the RES -BCT program. If this project were approved by SCE as a NEMA project, the value of the electricity generated at the TOU-GS-1-E rate schedule would be approximately $0.14 per kWh, more than doubling the monetary savings. CITY OF SANTA ANA 19H-26 Newcomb I Anderson I McCormick SECTION 6: POTENTIAL FOR HEAD RECOVERY AT MWD CONNECTIONS 19 The projected cost to purchase and install the new hydro turbine is $835,988. This involves the purchase of the new turbine generator set with electrical panel and controls, the construction of a new vault below the sidewalk to house the turbine and switchgear, the connection with SCE including a new transformer to accept the power, and integration with the existing SCADA controls. 6.6 MWD STATION SA -6 The pressure reducing station SA -6 is installed in a vault under the sidewalk at the northeast corner of E. Santa Clara Avenue and Tustin Avenue. The configuration is shown in Figure 5, with three PRVs and six isolation valves, approximately eight feet below the sidewalk. The SCADA monitoring and associated electrical meter are installed in small cabinets mounted nearby on the sidewalk. The SCE Service Account number and rate schedule is not known. The three PRVs are installed in parallel at different sizes, 6 -inch, 10 -inch and 16 -inch. The combined operation of these PRVs is typically controlled at 12 CFS. The typical pressure drop through this station is assumed to be the typical MWD pressure (177 psig) reduced to the upper zone pressure of 100 psig, for a pressure difference of 77 psig (or 178 feet). Figure 5 SA -6 Existing Configuration .............................. .............................. Pressure Relief Valve_ h. ,T 24 I To Santa Ana hrust 11 Block Pressure Reduction 6" 70" 7y'• Valves with Flow Control 24 I L.J MWD Thrust Block Vault Under Sidewalk 6.7 POTENTIAL PROJECT AT SA -6 The proposed project at SA -6 is to install a new hydro turbine generator in parallel with the existing Pressure Reducing Valves. There is no room in the existing vault, so a new vault would be required, potentially on the north side of the existing vault. This is illustrated in Figure 6. The new vault would contain the new hydro Newcomb I Anderson I McCormick 19H-27 CITY OF SANTA ANA 20 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study turbine and generator, a remotely controlled valve on the inlet of the turbine and an isolation valve on the discharge, an electrical panel to control the turbine and take power from it, a new metered connection to deliver the power to SCE, and some additional SCADA points. Thrust Block New Generator Vault MWD 1::1 24.. Figure 6 SA -6 Proposed Configuration Pressure Relief ---Va�lvee L ' '/ ' a" � Y 24 L'.j To Santa Ana Pressure Reduction 6" 10" 16^ Valveswith Flow Control Vault Under Sidewalk Thrust Block New Construction When the Agency needs 12 CFS through this station it would open flow through the turbine, using a combination of the automated valve and the wicket gates to minimize sudden pressure changes. The PRV could be kept at a higher setpoint so that it does not typically operate unless there were an unusual demand for water at this point. The control valve and wicket gates would be remotely operated to shut down flow in the turbine when appropriate, as well. The electricity generated by the hydro -turbine at this location cannot offset an adjacent City of Santa Ana load, as the only electric load at this location is instrumentation and lighting. It is anticipated that the generated electricity will be used to off -set another city meter through the Renewable Energy Self -generation Bill Credit Transfer mechanism know as RES BCT. This allows the value of electricity generated by the turbine to be metered by SCE on a TOU-GS-1-C rate schedule. The dollar value of this electricity can be used to offset the generation component at one or more city electric meters. The power produced by this flow and pressure difference is calculated here. The pressure drop is lower than for the other turbines, because the discharge of the turbine goes to the higher -pressure zone in the city, so the typical pressure drop is from 177 to 100 psig. CITY OF SANTA ANA 19H-28 Newcomb I Anderson I McCormick SECTION 6: POTENTIAL FOR HEAD RECOVERY AT MWD CONNECTIONS 21 12 ftahp sec 62.4 lbs 0.746 kW sec x 178 ft x 550 ft lbs x ft3 x 83.5%mech.eff.x 95%elect. eff x hp =143 kW This assumes the same mechanical efficiency as found for the 12 -inch turbine for the 8 CFS flow rate. This turbine is likely to be a 14 or 16 -inch unit. In the case of SA -6, the anticipated full load hours of operation are expected to be 5,915 hours per year, so the anticipated energy generation is 845,901 kWh per year. The monetary value for this electricity based on the RES -BCT arrangement with the Generation portion of TOU- GS-1-LG rate schedule is $55,131 per year. The value of the generated electricity is approximately $0.065 per kWh. Should the City sign up with SCE through the NEMA program, the electricity would be worth approximately $0.145 per kWh, more than double the RES -BCT savings. The City would need to enter discussions with SCE and possibly apply for an interconnection to determine which rate will apply to this project. The projected cost to purchase and install the new hydro -turbine is $1,072,174. This involves the purchase of the new turbine generator set with electrical panel and controls, the construction of a new vault below the sidewalk to house the turbine and switchgear, the connection with SCE including a new transformer to accept the power, and integration with the existing SCADA controls. Newcomb I Anderson I McCormick 19H-29 CITY OF SANTA ANA 22 job No. 2669.01 Water Systems Alternative Energy Feasibility Study SECTION 7: POTENTIAL FOR SOLAR POWER GENERATION AT PUMP STATIONS AND CITY YAR® There are several city -owned and operated locations that have the potential for the addition of solar PV. These sites include Garthe station, South station, West station, East station, Cambridge station, and the City Yard. The following table lists the existing conditions of these locations. After completing site -walks to get a close inspection of solar installation potential, preliminary designs were made to determine the anticipated rate tariff, total system size, annual performance projections, and relative load off -set for each site. A summary of this information can be seen in the following table. Garthe Station TOU-PA-3-E 500 Garthe Station 1,530,219 TOU-PA-3-B South Station 77,362 TOU-PA-2-B West Station 2,861,684 TOU-8-B East Station 802,416 TOU-PA-3-A Cambridge Station 526,805 TOU-PA-3-13 City Yard 884,323 TOU-GS-3-B After completing site -walks to get a close inspection of solar installation potential, preliminary designs were made to determine the anticipated rate tariff, total system size, annual performance projections, and relative load off -set for each site. A summary of this information can be seen in the following table. Garthe Station TOU-PA-3-E 500 Annual Energy 894,325 .. • 1 58% South Station TCU -PA -2-1) 44 75,170 97% West Station TOU-8-E 230 422,617 15% East Station TOU-PA-3-E 220 393,985 49% Cambridge Station I TOU-PA-3-1) 100 184,480 35% City Yard I TOU-GS-3-D 523 869,805 98% Each project would be interconnected to the local electric utility (SCE) through their Net Energy Metering (NEM) program. NEM allows systems to export to the grid during times when the site load is less than the solar PV generation, receiving a credit worth nearly the full retail rate of the energy being exported. The NEM policy does not allow for systems to be installed that would generate more than the site's annual load. It is assumed that the water tank sites would utilize either a ballasted mounting system, or a direct attachment, as there are different types of roofs on the reservoirs. An example of a solar system installed atop a municipal water reservoir is shown here from West Sacramento. (This photograph is from the Sunworks website.) CITY OF SANTA ANA 19H-30 Newcomb i Anderson i McCormick SECTION 7: POTENTIAL FOR SOLAR POWER GENERATION AT PUMPSTATIONS & CITY YARD 23 In the case of the City Yard, a series of carports would be used to reach the desired solar PV output. Note, the designs compiled in this proposal are preliminary, and are not intended for construction; a structural engineer would need to evaluate the site specifics for each design to ensure the safety and security of the systems. During the site walk, some trees were identified as allowable for removal, while others, such as those on adjacent properties, were not allowed to be removed; the preliminary designs have accounted for this information. After evaluating the site's load and solar PV potential, examining the current and expected future rate tariff, the NAM team was able to calculate the financial benefit of these projects, independently and as a portfolio. Although a simple loan and a power purchase agreement were both evaluated, for the purposes of this summary report, the NAM team has focused on the results of the cash -purchase option, since it is the most financially advantageous. The following table shows the sites under consideration for PV, the current and recommended SCE rate schedule to provide the lowest rate with solar power, the size of the proposed system in DC kW (based on the nominal DC rating of the proposed solar modules, and the anticipated construction cost per DC Watt of system capacity. The cost per Watt varies according to the size of the system and the complexity of installation, with a higher cost for parking lot shade structures because of the extra construction materials involved. Newcomb I Anderson I McCormick 19H-31 CITY OF SANTA ANA 24 Job No. 2669.01 Water Systems Alternative Energy Feasibility Study West V349N-017847 SCE TOU-8-1) TOU-8-E 230 $2.75 East V345R-006147 SCE TOU-PA-3-E TOU-PA-3-E 220 $2.75 Cambridge V345N-001335 SCE TOU-PA-3- D TOU-PA-3-D 100 $3.00 City Yard V349N-014832 SCE TOU-GS-3- D TOU-GS-3-D 523 $3.25 These designs were simulated using HelioScope, and industry standard PV simulation program. This program uses a local weather data file and calculates the hourly performance of the system based on the angle of insolation, the air temperature, the wind speed, the intensity of clouds, and so on. The hourly PV output is subtracted from the hourly electric load profile data from SCE to determine the hourly energy use with PV in place. The electric bill is calculated based on how these kWh fall into the On -Peak, Part -Peak, and other bins to calculate 12 monthly bills for the site with and without solar. Site Garthe Generation 894,325 11101iN 1,789 South 75,170 1,708 West 422,617 1,837 East 393,985 1,791 Cambridge 184,480 1,845 City Yard 869,805 1,664 The annual bill savings are included with the system capital cost to evaluate the lifecycle vale of the project and its energy savings. The parameters included in this analysis are listed in the Appendices. The following table summarizes the outcomes of the financial evaluation. Garthe Station Total Installed Cost ($1,404,000) Year -1 Energy Cost Savings $38,165 25 -year Net -Benefit ($148,834) South Station ($194,832) $3,492 ($77,488) West Station ($707,940) $39,780 $635,398 East Station ($677,160) $19,080 ($43,018) Cambridge Station ($334,800) $8,332 ($67,435) City Yard ($1,890,767) $46,325 ($298,129) Total ($5,209,499) $155,174 $494 The sum of all the solar projects has a positive net -benefit over 25 years. However, it is only the Garthe Station and the West Station that have positive net -benefits as.individual sites. Further, it is only the West Station that has a significantly positive net -benefit. The following figures show the preliminary solar layouts at each site, with some initial commentary on some of the challenges that might arise with each design. CITY OF SANTA ANA 19H-32 Newcomb i Anderson I McCormick SECTION 7: POTENTIAL FOR SOLAR POWER GENERATION AT PLIMPSTATIONS & CITY YARD 25 Garthe Station —This array utilizes the roof space of both circular storage tanks, as well as the roof surface of the rectangular reservoir to the northeast. Shading concerns from trees to the south of the building have reduced the amount of available roof space. Since these trees are not on the city's property, they will be difficult to remove. All surfaces account for existing equipment that limit the available space for the installation of solar PV modules. These arrays would likely utilize a ballast mounted system, pending an in-depth structural analysis. Newcomb I Anderson I McCormick 19H-33 CITY OF SANTA ANA 26 .lob No. 2669.01 Water Systems Alternative Energy Feasibility Study South Station — This array utilizes the roof space of both storage tanks. All surfaces account for existing equipment that limit the available space for the installation of solar PV modules. These arrays would likely utilize a ballast mounted system, pending a structural analysis. CITY OF SANTA ANA 19H-34 Newcomb I Anderson I McCormick SECTION 7: POTENTIAL FOR SOLAR POWER GENERATION AT PLIMPSTATIONS & CITY YARD 27 West —This array utilizes the roof space of the single storage tank, while taking into account existing equipment that limits the available space for the installation of solar PV modules. This array would likely utilize a ballast mounted system, pending a structural analysis. Newcomb I Anderson I McCormick 19H-35 CITY OF SANTA ANA SECTION 7: POTENTIAL FOR SOLAR POWER GENERATION AT PLIMPSTATIONS & CITY YARD 29 Cambridge — This array utilizes the roof space of the single storage tank, while taking into account existing equipment that limits the available space for the installation of solar PV modules. It is assumed that the trees causing shading from the south west will be removed by the city to increase the available space. This array would likely utilize a ballast mounted system, pending an in-depth structural analysis. Newcomb I Anderson I McCormick 19H-37 CITY OF SANTA ANA OHel IN It 1k. £rI' t'„• ..�' to ?, �+, ` ` lJ� Ll” = 'J 1' P `` 4•_ 61 r h -�FM•!fl'I�!i J ^aye i i �I II �T �� [1.�� ' I ' i 1 j�� N' }�1�,4�ifj-Japl ' y����p_# II f il,'I �'6,1 � 9 �.kl I .+%^I .Wf'• • }RR*� �� 'v ��/" eLLk. ! Ii Is I! l J., Ir fI . .j )< a ,Y, ! .1.... APPENDICES APPENDICES APPENDIX A - HISTORICAL ELECTRICITY PURCHASES APPENDIX B - 2017 MASTER WATER PLAN APPENDIX C - EXISTING BYRON JACKSON HYDRO TURBINE APPENDIX D -TURBINE PROPOSALS APPENDIX E - PLANT OPERATING RECORDS APPENDIX F - MONTHLY PRODUCTION REPORTS APPENDIX G - TURBINE COST ESTIMATES APPENDIX H - SOLAR MODEL PARAMETERS 31 Newcomb I Anderson I McCormick 19H-39 CITY OF SANTA ANA 19H-40 APPENDIX A: HISTORICAL ELECTRICITY PURCHASES APPENDIX A HISTORICAL ELECTRICITY PURCHASES A-1 Newcomb I Anderson [ McCormick 19H-41 CITY OF SANTA ANA 19H-42 a` N� r b Q Q N N ID m O IO n W 1D T N M N N n n T m N M m .+ornm Pnb emPotimom .+nN m vrvioae N erirPnleao.-iamn�'".mim n y v°iim�riry O r1 m P N m n T O N b N N N U r'I N M e1 H e'I e'I 'I 10 m N em n n N O OI N m ti C P n m N O O N N e r m e T N 1 T N Yl OI O OI N ti O N V VI r b m m o n D n moonolPo .minnn mm man olni+vQon00me."im N 'Ib mme envov o .+m .P+om Lq Z `"Nrv"�mmn�mnm movnmlrommmn'"nmmlboon'�Ivil N n M 1O m n N n m b T n r Q ID Imll T N O m � OW P T b � lnV ePV � T Oml '1 n W ImVI N W N O P Ori OI m m b N h P n n I(Of b N m n b m N fl O fl r IO fl N N m T fl m P O O H m 10 P 10 r M 1O m m Q r N O Q b P O n 0 Q Op m N b n P H Q H W Nn N nNmmm mm.+mvonm omlon�Io v m O .Ni e T ro m T T o v n.v+nn.b+o�mmemlmil lPrl micmmoe.n+In n.ni vPlovnwm� ti W W m n H T T T ti b b N P O� maenomrnnmm�mo�nonenmmv'^i�n40eomnm.rio ry gimme Nem.vmPnann.y o.+ nmr.� „rvb.+ �, ri fi of ti o? 'm ao Tvia T vmi eI e� ry r n O P O m m m '1 r e N N ti O b m n Q T Q eP1 m M M N O b O n w ONI O r VI V H 0 Q H n ti O O Q � i m h m ti m 1� p ln/1 N Q'1 e1 e1 e1 e1 e1 p b M N m m O ITl1 mn T m N Q H Q O O v'i n 0 em'I N N N 40 ry T 4NO b d .-iri vieso vv; -1 6 6 e.: oumi '� ry P Pm m Imo n N O Q M n 1mD '1 T OOI N eb1 W b O N O N N b VPI m n IO IR ubl N O I� fmY '1 n N P N Q m O b e e1 'I m m R r N F F IO N VI m ' '1 Oi O 10 I/1 'Imo' m '1 aP O N N m Q m b O b N n O N M N O n T N n O W O N n T n eN1 q N 0 10 O ti H b N b m T 1� H m n m e T m Q VI m H m Q m N ¢ y a d d N a Z >' z ° «z3a �,y �In3z z z z mz ma3vv� z"I` z menNomnmNmonmev.n.mnn onom mirvmol�il ti N e1 N ei e1 N n ti m N 'I n N 'I P N ti r N N b N T 'I n 'I P ID C T N O m O m O N N m T P n mO m m C T b C P O V m O q o.+n n NPmq In .n .I .vm n 9 o Tm m m n.+ggmq aq $ dNN vvdvblo lm�ooA do 3 O T n r TT n P W M n N N N n N N N 1 Oi N N ry n Q m n m m n n m ary b b b m m m m T m m m m m T o g n q vvl n m m w v � m o o .+ o -? P a m o 0 0 0 o m o0 0 0 0 0 0 0 0 0 0' 0 0 0 '" IV 1f1 P 0 0 o o 0 0 0 o b 0 o q q o 0 0 0 0 0 0 0 0 0 q g q o M m m m m m m of m m m m m m m m m m m m m m m m In m m nI m m N T T ay m Cd0 W — d d m a 3 3 3 c ' N a Go paperless at www.sce.com/ebilling. It's fast, easy and secure. WTI SOUTHERN CALIFORNIAP.O.P.O. BOX 300 Lmj E D I I Rosemead, CA 91772.0001 An EDISON INTERNATIONALS Company vAmv.sce.com SANTA ANA, CITY OF I Page 3 of 74 For.billing and service inquiries call 1=800-990-7788, Customer account 2-24-876-4649 For emergency services call 24 hrs a day, 7 days a week 220'S DAISY AVE 2,,SAANTA ANA, CA 92703-4334 Date bill.prepared: Aug 9'16 f'`i15 I I io r 4 2l to 2.1 .;a i Your account summary IW11-1 t-5gj i5a5 ' '32 -- Previous Balance $217,421.81 APPROVED FOR PAYMENT Wire credit adjustment -$217,421.81 Q Balance forward $0.00 Your new charges $182,126.66 habil Saba . . 0'j Total amount you owe by Aug 29 '16 $182,126.66 • Summary of your billing detail Service account Service address Billing period Your rate New charges 3-021-7437-93 2315 N BRISTOL ST Jul 5'16 to Aug 316 TOU-PA-3-A $355.67 SANTA ANA, CA 3-025-3286-49 723 W WALNUT Jul 5'16 to Aug 316 TOU-PA-3-B $14,200.79 SANTA ANA, CA 3-029-9837-84 907 3/4 N FLOWER ST MET01 Jun 1716 to Jul 1916 TOU-PA-3-B $11,004.52 SANTA ANA, CA 3-035-8796-80 11013/4 S BRISTOL ST Jul 5'16 to Aug 316 TOU-GS-1-A $34.01 SANTA ANA, CA CAMBRIDGE PS 2736 N CAMBRIDGE ST Jul 1 '16 to Aug 2'16 TOU-PA-3-B $8,364.64 3-011-0573-83 SANTA ANA, CA CAMBRIDGE RESERVOIR SITE 2736 N CAMBRIDGE ST Jul 1 '16 to Aug 216 TOU-GS-1-A $177.83 LIGHT SANTA ANA, CA 3-001-3273-34 CROOKE PS & WELL 27 & 28 730 W MEMORY LN Jul 5'16 to Aug 316 TOU-8-6 $26,717.13 3.001-3273-42 SANTA ANA, CA EAST PS & WELL 26 1730 S SANTA FE ST t/ Jun 1316 to Jul 13'16 TOU-PA-3-A $8,879.63 3-001-3274-19 SANTA ANA. CA (Continued on next page) Please return the payment stub below with your payment and make your check payable to Southern California Edison. (14.574) Tear here It you want to pay in person, call 1.800.747-8908 for locations, or you can pay online at www.sce.com. Tear here -- -- - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - ft - - m - - - - - - - - - - - - - - - - -- souaIM cwrowmu Customer account 2-24-876-4649 E D I S O N' Please write this number on your check. Make your check payable to Southern California Edison. 'EDISON INTER Ar/DWL-C-r-, STMT 08092016 P4 Iltltlrrlllllllllllrrltlrlllllrrrltlllllllrlllltrltlllrllllllllll SANTA ANA, CITY OF ATTENTION NABIL SABA 220 S DAISY AVE SANTA ANA, CA 92703-4334 Amount due by Aug 29'16 $182,126.66 Amount enclosed $ g z 12 P.O. BOX 300 ROSEMEAD, CA 91772-0001 24 876 4649 DOOfjlgy pC OOOD00018212666018212666 Contact Information Customer service numbers General Services (U.S & Canada) 1.800.655-0555 Account Balance & Extensions 1-800.950-2356 Emergency Services 8 Defaces 1.8 0.611-1911 California Alternate Rates for Enemy (CARE) 1.800-0475620 Electric Industry Reswcturin9 _... _._._.__. 1.800.799-4723 Energy Theft HMine 1-800-127-3901 Hearing & Speech Impaired (TTY) 1.800.352-8580 Important information Rotating outages A Totaling outage is a controlled electric outage that lasts approximately one hour for a group of circuits, which is used during electric system emergency conditions to avoid widespread or uncontrolled blackouts. Each SCE customer is assigned a rotating outage group, shown on the upper part of the SCE bill. If your rotating outage group begins with the letters A, M. R, S, or X, you are subject to retailing outages. If It begins with N or Exempt, you are not. Your totaling outage group may change at any time. For mom information, and to see which retailing outage groups am likely to be called In the event of a system emergency, visit www.sce.Com or call 1-8005554555. Options for paying your bill On-line www.sce.com or Electronic Fund Transfer Chinese / r1r)t Mall -in Check or Money order 1.800-528-3051 In Person Authorized payment locations 1.800.747.8908 Phone OuickCheck 1.800.950-2356 Credit Card-VIsafMasterCard• 1.800-254-4123 Debit Card-ACCEL/NYCE/Pulse/Star• 1-800.254-4123 -The CrediUDebil card payment options are not available for payment of commercial services or security deposits for cammercial services. You may call us for electronic payment options, to make payment arrangements, or for Information on agencies to assist you in bill payment. It service has been disconnected, on the day of the service reconnection, be sure all appliances and other electric devices am turned o8. For additional home safely lips, visit www.sce.Com/safety or you may call SCE Customer Service at 1-800555.4555. Past due bilis Your bill was prepared on August 9, 2016. Your bill is due when you receive It and becomes past due 19 days after the date the bill was prepared. You will have 15 days at your new address to pay a bill tram a prior address before your service will be terminated. SCE does not terminate residential service for non-payment of bills for otherclasses of service. Terninadon of electric service requires a Service Connection charge. It you am a residential customer, and claim an inability to pay and payment arrangements Have not been extended to you by SCE pursuant to SCE's riled tariffs, you may contact the California Public Utilities Commission (CPUC). Rules and rates SCE's rules and rates are available in full at www.sce.Com or upon request. SANTA ANA, CITY OF I Page 4 of 74 Multicultural services Cambodian 1191 1-000.843.1309 Chinese / r1r)t 1-800-843-8343 Korean / £RPI 1.800-528-3051 Vietnamese/Tung wet - 1.800-3273031 Spanish l Espanol 1-800441.2233 Correspondence: Southern California Edison (SCE) P. O. Box 6400, Rancho Cucamonga, CA 91729-0400 Late Payment Charge (LPC) A late payment charge of 0.8% will be applied to the total unpaid balance on your account if full payment is not received by the due date on this bill (except for CARE and slate agency accounts). Disputed bills If you think your bill is Incorrect, call us and speak with a customer service representative, or if necessary, with a manager. If you feel unsatisfied with the result of such discussion(s), contact the CPUC, Consumer Affairs Branch by mail at 505 Van Ness, Room 2003, San Francisco, CA 94102; or at www.cpucca.gov, 1.800549.7570, TTY: 1-800-229-6846. Include a copy of your bill, why you believe SCE did not follow its rules and rates, and a check or money order made out to the CPUC for the disputed amount. You must pay the drsputed amount, or send it to the CPUC, before the past -due date to avoid disconnection. The CPUC accepts payment only for matters relating directly to bill accuracy. While the CPUC is investigating your Complaint, you must pay any new SCE bills that became due. Electronic Fund Transfers (EFT) When you provide a check as payment, you authorize us either to use information from your check to make a one-time electronic fund transfer from your account or to process the payment as a check transaction. When we use information from your check to make an electronic fund transfer, funds may be withdrawn from your account as soon as the same day we receive your payment. You will not receive your check back tram your financial institution, but the transaction will appear on your financial Institution statement. If you do not wish to authorize an electronic fund transfer, please call the 800 number on the front of your bill. Definitions • DWR Bond Charge: Bonds issued by the Department of Water Resources (DWR) to cover the cast of buying power for customers during the energy crisis are being repaid through this charge. • SCE Generation: These charges recover energy procurement and generation costs for that portion of your energy provided by SCE. Beginning April 11, 2010, pursuant to CPUC Decision 10-03-022, Direct Amass (OA) is again open to all non-residential customers, subject to annual limits during a four year phase-in period, and absolute limits following the phase-in. All residential customers currently returning to Bundled Service may not elect to return to DA service. • CA Climate Credit: Credit tram slate effort to fight climate change. Applied monthly to eligible businesses and semi-annually to residents. To change your contact information or enroll in SCE's payment option, complete the form below and return it in the enclosed envelope. Change of mailing address: 2-24-876-4649 i STREETd _STREET NAME — "— 2 -APARTMENT H j i ... ._ _ iCITY - STATE ! LP CODE i I I i I TELEPHONE p �E-MAIL ADDRESS Direct Payment (Automatic Debit) Enrollment: 2-24-876-4649 1 hereby authorize SCE and my financial institution to automatically deduct my monthly payment tram the checking account as shown on my enclosed check, len Calendar days after my bill is mailed. Signature Data To change your checking account information or to be removed tram the Direct Payment program please call SCE at 1-800-655-4555. ® Energy Assistance Fund (EAF): I want to help people pay their energy bill through EAF. For Info visit wvnw.sce.com/eaf or call (800) 205-8596. Round -up my hill to next whole dollar amount For EA F Add this amount for EA F S Select one box only and sign below for EAR Month only Month Month One 19H-45 �1 One Month LJ only Go paperless at www.sce.com/ebilling. It's fast, easy and secure. riSOUTHERN CALIFORNIA EDISON� An EDISON INTERNATIONALm Company SANTA ANA, CITY OF I Page 5 of 74 Summary of'your billing; detall',(continuedj; .STATION SANTA ANA; CA YHV 7 OV 1 01% vv rvlamivn I rcw .' v oa„ �•, 6 w-aw 3-020700-93 SANTA ANA CA „�U � - n00 mA r 17TW QT .lun R•16 m.1u18'.16.' TOU-GS-1-A $47.77 3-0224131-75 SANTA ANA CA V ' ' - PRV-2 399 314 E 17TH ST Jul 8'16 to Aug 816_ T_ OU -GS -1-A $49.09 3-0224131-75 SANTA ANA CA PRV-3 1345 314 N GRAND AVE Jul 6'16 to Aug 4'16 TOU-GS-1-A $52.31 3-000-6921-16 SEGRSRTROM SEWAGE LIFT SANTA ANA, OA 2903 S BRISTOL ST Jun 23'16 to Jul 25'16 TOU-PA-2-B $664.41 STATION SANTA ANA, CA JJul 5'16 to Aug 316 TOU-PA-3-8 $10,873.35 3-OD2-3158-73 SANTA ANA CA SOUTH PS 1727 ALTON PKWY WP /Jun 17'16 to Jul 1916 TOU-PA-2-B $1,598.50 3-008-2244-21 SANTA ANA CA WATER WELL 1301 N MABURY ST J Jun 17'16 to Jul 19'16 TOU-PA-3-B $2,569.11 3-029-798640 SANTA ANA CA WELL 16 650 W FLOWER B Jun 13'16 to Jul 1316 TOU-PA-2-A $2,346.58 3-001-3274-64 SANTA ANA CA Jul 1 '16 to Aug 1 '16 MISC-CHARGES $14.47 WELL 24 1800 W 22ND ST Jun 1316 to Jul 13'16 TOU-PA-2-A $2,635.39 3-001-3274-37 SANTA ANA CA WELL 29 101 S FLOWER PMP / Jun 15'16 to Jul 15'16 TOU-PA-2-A $150.71 3-000-8776-20 SANTA ANA CA WELL 31 1815 E CHESTNUT AVE Jul 5'16 to Aug 3'16 TOU-PA-3-B $10,825.53 3-001-3269-95 SANTA ANA CA WELL 32 2801 N WESTWOOD Jul 1 '16 to Aug 2'16 TOU-GS-1-A $79.73 3-000-6323-10 SANTA ANA CA WELL 35 1718 N SYDNEY WELL JJul 5'16 to Aug 316 TOU-PA-3-8 $10,873.35 3-010-7630-01 SANTA ANA CA WELL 36 2415 N BRISTOL ST Jun 30'16 to Aug 1 '16 TOU-PA-2-B $9,064.10 3-000-5824-85 SANTA ANA, CA WELL 37 2007 W MCFADDEN AVE Jul 516 to Aug 3'16 TOU-PA3-13 $13,073.27 3-010-7672-94 WELL SANTA ANA CA WELL 39 2401 N BRISTOL ST Jul 1 '16 to Aug 1 '16 MISC-CHARGES $14.47 $182,126.66 19H-46 APPENDIX B: 2017 MASTER WATER PLAN I1»4Of01E41. 2017 MASTER WATER PLAN Ml Newcomb I Anderson I McCormick 19H-47 CITY OF SANTA ANA 19H-48 City of Santa Ana 2017 Water Master Plan Table 4 - Summary of Demands and Peaking Factors NAM >>> Average Maximum Peak Hour Day Day Average Average Peak Hour Peak Hour Demand Annual Use Time Horizon Demand Demand (million (gal/yr) Flow Flow Flow Flow (million (million (gal/hr) (gal/min) (gal/hr) (gal/min) gal/day) gal/day) gal day) Existing 33.5 45.2 65.3 12,227,500,000 1,395,833 23,264 2,720,833 45,347 Near Term 34.9 47.1 68 12,738,500,000 1,454,167 24,236 2,833,333 47,222 Buildout (2040) 35.5 47.9 69.1 12,957,500,000 1,479,167 24,653 2,879,167 47,986 365 33,500,000 gallon/day 33.5 MGD 19H-49 City of Santa Ana 2017 Water Master Plan Table 6 - Groundwater Well Summary 19H-50 Static Design Design Well Well Pumps Power Pumping Capacity Depth Head Capacity No. To (hp) Depth (ft) (mgd) (ft) (ft) (gpm) 16 Walnut 150 83 108 2.16 228 2,000 18 John Garthe 150 - - 3.29 212 2,000 20 West 150 92 115 4.35 161 3,000 21 West 150 93 113 4.16 160 3,000 24 John Garthe 150 127 203 1.85 279 1,800 26 East 125 127 - 3.00 246 2,500 27 Crooke 300 189 298 3.97 370 2,500 28 System 350 180 264 3.62 400 2,500 29 Walnut 200 152 218 3.65 246 2,500 30 John Garthe 150 91 118 4.35 165 3,000 31 System 350 177 246 3.98 408 3,000 32 John Garthe 300 126 - 3.22 315 2,775 33 Walnut 250 148 227 4.10 280 2,800 34 south 125 115 194 2.18 425 2,500 35 System 350 130 165 3.17 305 3,000 36 John Garthe 250 155 194 5.18 210 3,600 37 System 350 119 137 3.31 330 3,000 38 System 350 221 322 2.16 425 2,500 39 John Garthe 250 153 194 4.32 250 3,000 40 System 400 192 278 3.71 200 2,575 41 System 450 155 201 4.32 350 3,000 TOTAL 5,300 74.05 56,550 = 51,424 = 81 gpm mgd 19H-50 City of Santa Ana 2017 Water Master Plan Table it - Metropolitan Water District Connections MWD Connection SA -1 SA -2 SA -3 SA -4 SA -5 SA -6 SA -7 TOTAL Name Bristol First McFadden Warner Alton Santa Clara Red Hill Normal Design Operating CNumber Capacity (mgd)y of Valves Valve Type (mgd) Notes 5.17 6.46 2 FCV Has hydro. Nee 5.17 9.69 1 FCV 5.17 6.46 1 FCV 4.85 6.46 1 FCV 4.85 12.93 1 Out of Service Being Upgraded 7.76 12.93 3 FCV 4.85 32.31 2 FCV Being moved by 37.82 87.24 = 26,264 60,583 gpm gpm 19H-51 ds work. Caltrans City of Santa Ana 2017 Water Master Plan Table 12 - Storage Reservoir Facilities Capacity Reservoir Number Facility Tank Type (million of Tanks Zone gal) Cambridge Concrete 1.3 1 High Cooke Concrete 6.0 1 High East Steel 6.0 1 Low Elevated Tank Steel 1.0 1 Low John Garthe Concrete 15.8 3 Low South Concrete 6.0 1 Low Walnut Concrete 7.0 1 Low West Steel 6.0 1 Low TOTAL 49.1 Bottom Elevation Diameter (ft) 188.8 Variable 157.6 Variable 76.2 180 NA 60 100 277 35.7 219 79.8 Variable 66.9 180 19H-52 Height 17.2 21 31.5 131 35 Possible PV 22 22 32 Possible PV City of Santa Ana 2017 Water Master Plan Table 16 - Booster Pump Summary 105 MGD 19H-53 Average Design Power(h DesigHead Station Pump No. Motor Capacity Capacity (n (gpm) (gpm) Cambridge 1 Electric 75 1,481 150 1,650 Cambridge 2 Electric 75 1,436 150 1,650 Cambridge 3 Electric 75 1,526 150 1,650 Crooke 1 Electric 150 2,783 185 2,700 Crooke 2 Electric 150 2,693 185 2,700 Crooke 3 Electric 150 2,738 185 2,700 East 1 Electric 125 2,648 175 2,300 East 2 Electric 125 2,603 175 2,300 John Garthe 1 Electric 150 2,693 180 1,760 John Garthe 2 Electric 150 3,097 183 2,590 John Garthe 3 Electric 150 3,007 183 2,590 John Garthe 4 Electric 200 4,264 183 3,560 John Garthe 5 Electric 200 3,590 183 4,270 John Garthe 6 Gas 250 4,982 South 1 Electric 125 2,244 212 2,000 South 2 Electric 125 2,244 212 2,000 Walnut 1 Electric 200 3,501 200 3,100 Walnut 2 Electric 200 3,501 200 3,100 Walnut 3 Electric 200 3,456 200 3,100 Walnut 4 Electric 150 2,738 200 2,400 Walnut 5 Electric 100 1,750 200 1,400 West 1 Electric 200 2,513 170 2,800 West 2 Electric 200 2,289 170 2,800 West 3 Electric 200 2,289 170 2,800 West 4 Electric 150 4,488 176 3,700 West 5 Electric 100 2,020 170 2,100 TOTAL 3,975 72,574 63,720 105 MGD 19H-53 APPENDIXC: EXISTING BYRON JACKSON HYDRO TURBINE APPENDIX C EXISTING BYRON JACKSON HYDRO TURBINE C-1 Newcomb I Anderson I McCormick 19H-54 CITY OF SANTA ANA Elf. Nov. 1985 Third Edition BWlrjl W ntenl Donal, If1CPump- TABLE i, SHEET 2 Hydro turbines shall be furnished with the following metallurgy: Byron ' Section 2-191 JacksonProducts Page 2-191-13 PART DESCRIPTION ASTM NUMBER COMMON TERMS Inlet Elbow — Head A-53 Fabricated Steel . A-48 Cast Iron Column A-53 Fabricated Steel Shaft — Main A-582 400 Series Stainless Steel Bearing — Column B-271 Lead Bronze Bearing — Main B-271 Lead Bronze Case — Main A-48 Cast iron Wicket Gate A-148 CA -958 Ni -Aluminum Bronze Ring — Gate Operating B-271 Bronze A-276 400 Series Stainless Steel Cover — Gate Mechanism A-48 Cast Iron Stem — Wicket Gate A-582 400 Series Stainless Steel Runner 8-148 CA -958/ Ni -Aluminum Bronze or A-743 300 Series Stainless Steel Case — Runner 8-148 CA -958 Ni -Aluminum Bronze or A-743 300 Series Stainless Steel Cone — Runner B-148 CA -958 Ni -Aluminum Bronze Split Ring — Runner A-479 400 Series Stainless Steel Key — Runner A-276 300 Series Stainless Steel A-582 400 Series Stainless Steel Lever — Wicket Gate A-743 400 Series Stainless Steel Draft Tube A-53 Fabricated Steel 19H-56 • Section 2.191Byron 8 / pp, M911P IMemational, Inc. Jackson® Effective June 1986 Page 2-191-4.8 pwp Division Products BYRON JACKSON TKW HYDRO TURBINE • PRELIMINARY OUTLINE -BELOW GRADE PULL-OUT DESIGN B. CTR. (SQUARE) SQUAB NOZZLES SIZE , A.S.A. RATING RATED FLOW NET HEAD -FT K W OUTPUT TURBINE RPM TURBINE WT LBS. GENERATOR WT LBS. BARREL WT LBS. USER: DRAWN BY DATE PROP. NO. LOCATION: -57 DRAWING TITLE: 19 Section 2-191 /% Byron Page 2-191-0.4 I11riA B/ID�@rnational, I= Jacksons Jacksons EIL May 1985 OUTLINE DIMENSIONS - INCHES TURBINE A R C 0 E R GI Jr I L M Ns P Q U W X y he SIZE 1•STG COMP. ADO PER STG. K -DEGREES 0 45 90 135 8 RL 35'/4 31 3314 '4 % 30 40 14 12 24 30 16 16 32 34 h i'A % 24 17 12 5 B M 41 ti 37 3914 1 '4 30 65 19 12 28 36 16 19 38 40 % 1'h 'A 24 19 12 5 8 H 41'7. 37 3914 1 U. 30 70 19 14 29 36 20 21 38 40 '12 1'A '4 28 23 16 5 10H 66 66 54'h 1 Y. 'A 30 84 24 174 37 48 26 25 52 54 3'. 1'A rA 35 27 17 6 12H 72 72 60'4 1'A rA 30 101 29 20 40 54 30 30 58 60 V. 11A 'h 40 34 22 7 15M 72 72 604 1Y. rA 30 115 33 20 40 54 30 30 58 60 3/. 1'h % 40 34 22 7 15 H 79 79 70 1'h 1% 30 120 33 2314 44 60 36 35 64 66 35 1% 1'4 47 38 26 9 17 H 94 94 83 14: 1'h 36 142 42 27 53 72 42 42 76 80 1 1% 1% 54 46 31 11 21 H 108 108 97 1% 114 36 165 47 31' 60 84 50 49 90 92 1 13'i 135 63 55 38 15 25 H 124 124 110 2 1% 36 198 66 37'4 67 96 60 59 102 104 1 2'A 135 74 66 46 17 NOZZLE ADAPTATION DIMENSIONS' AA Min. = L + 5 (N -CA) AS Min. = L + 3 (N -DA) AE Min. = 6 (N -CA) AF Min. = 4 (N -DA) NOTES: (1) Barrel length may be increased it necessary for extra -deep nozzle setting. (2) "F" dimension is the typical minimum generator stand height. Applications requiring oversize turbine shafting or special wicket gate operators may require additional height. (3) Standard barrel nozzles are sized for moderate fluid approach velocity to provide efficient and quiet operation. Where required, separate spool adapters or integral welded adapters may be specified. (4) Specify "Byron Jackson To Supply" or "By Others'. (5) Standard nozzles have 150 Ib. or 125 Ib. standard A.S.A. raised face flanges.. (6) Nozzles rated greater than 150 Ib. may require greater elevation difference. Inlet nozzle elevation is always equal to or above discharge nozzle elevation. (7) 250 lb. or 3001b. nozzle flanges require additional base -lo -nozzle clearance. (8) Contact B.J. Engineering Department for special installation I mounting design. BARREL INSTALLATION AND MOUNTING CONSIDERATIONS Pullout barrels can be permanently embedded in concrete, or they can be bolted to a baseplate. Each means of installation has certain advantages over the other. The embedded barrel will result in quieter operation due to the sound damping effect of the concrete and soil. For speed or ease of installation, the flange -mount barrel can be provided. A separate qq//ss��yyl t�� a8I�t@bolts, and flange mounting hardware will also be furnished. Installation of the baseplate will be performed by others; The basipOlmial '�, ing flange mating surfaces are machined flat and after the baseplate has been properly levelled and grouted, the turbine barrel is simply lowered into place. With either type of pullout barrel installation, the barrel may be left in olace. leavinn the rnnnprrpn hman ;f h.—. nprp==arn fn rpmnvp rhp hnhlna fnr maintenance. 4 • Sectlon 2-191 Byron /` /,, BW/IP Intemationai, Inc Jackson° Eff. May 1985 Page 2-191-20.4 Pump Division Products BYRON JACKSON HYDRO TURBINE STYLE DB ABOVE GR �1�BOUT DESIGN is 0 Eff. May 1985��(!i BWAP Intemational, Inc. /,12/1 PunpDivision INLET Byron Section 2-191 P ro�ts Page 2-191-4.3 BYRON JACKSON TYPE TKW STYLE DB PULLOUT PRELIMINARY OUTLINE DIMENSIONS BASIC OUTLINE NOZZLE ORIENTATION INLET N DEGREES CC OR CCW FROM INLET IBCN. INLET 1 N m11L DI N. NOZZLE ROTATION INET0ISCM. INLET CUBTONE0. 1 TO PBCIFY I 018 M. OFFSET DISCHARGE ELEVATION AT IGVFROM INLET OPTIONAL PIPING/NOZZLE ADAPTATION I INLET BIBLK CA --, A I DA 1 I ' INTEGRAL TYPICAL METHODS OF BARREL INSTALLATION ABOVE BABE NOZZLES EMBEDDED BARREL ANO ANCHOR MUG W J mN. `if v DIA. ,. ABOVE BABE NOZZLES EMBEDDED BARREL On E min.0101rt Q DIA. AE I AFF IML II I IBCN. LA OA I SPOOL PIECE] 19H-60 ABOVE BASE NOZZLES FLANGE -MOUNT BARBEL BELOW BASE NOZZLES EMBEDDED BARREL AND ANCHOR RING BELOW BASE NOZZLES INDUCED BARREL BELOW BASE NOZZLES FLANOE-MOUNT BARREL OPTIONAL BASEPLATE/MOUNTING FLANGE SQUARE 0A8EPLATE FOR BARREL DIAMETERS TRRU, /9 W. G�D HOLES IN BEPLATE —B eaT-8 SOLE DIA B-E NOLEB IN BARREL MOUNT.: FLANGE BOLT.. BLL 'JCTAGONAL BASEPLATE I BARRELS AB CIA. AND UP 19H-61 APPENDIX D: TURBINE PROPOSALS APPENDIX D TURBINE PROPOSALS D-1 Newcomb I Anderson I McCormick 19H-62 CITY OF SANTA ANA 19H-63 k((oC*a*�nyon / HucJro August 17, 2018 Michael KJ Anderson PE, VP Newcomb I Anderson I McCormick 201 Mission Street, Suite 2000, San Francisco, CA 94105 Dear Mr. Anderson, Thank you for your correspondence regarding the hydroelectric projects you are evaluating in California at the SA -6 Santa Clara location. We appreciate the opportunity to work with you to offer the best possible Canyon Hydro equipment package for this site and application. Based on your correspondence we are offering an equipment package utilizing an In -Line Turbine optimized to pass 12.0 CFS at 90-120 PSI net head. Under these conditions maximum expected system production will be 225 kW using the equipment package described below. The turbine will pass up to 18.7 CFS at 120 PSI net head with an expected maximum output of 351 kW. (1) Soar ILT16-33-11.25 Variable Flow Hydro Turbine, 1800 RPM, adjustable wicket gates (1) US Motors Vertical Shaft, 500 HP, 1800 rpm, 480 VAC, 60 Hz, 3 ph., induction generator (1) 16" Hydraulically Actuated Turbine Inlet Valve (1) HPU to support wicket gate and inlet valve actuation with accumulator sized to close wicket gates and inlet valve in the event of power grid failure (double fail-safe) (1) Switchgear and controls panels to parallel the generator with the local electrical utility grid and provide protective relays to utility grid standards for a project of this size. Specific utility requirements may change the scope of the switchgear/controls package offered and pricing may be affected. A one -line diagram and equipment list will be submitted for local electrical utility review and approval prior to proceeding with panel manufacture. Budget estimate system price, as described......................................................$541,000.00 The equipment package offered will be custom designed to meet the particular requirements of the site and project as explained through our discussions. As the project progresses and requirements are determined, we will be pleased to refine our budget estimate or offer a firm quotation. Budget estimates are offered for planning purposes only but are typically within 10% of a firm quotation for the same equipment package. Normal Terms 15% to begin final design 30% to begin manufacture following final design approval 25% mid -project 20% upon notice of readiness to ship 10% upon successful start-up or 90 days from readiness, whichever is first Normal Delivery 32-40 weeks from design approval and receipt of payments Delivery FOB Deming, Washington (crated for shipment) In addition to equipment supply, Canyon Hydro also offers equipment installation services by our in-house field crews who are highly experienced with the unique requirements of hydroelectric equipment. Canyon Hydro— the water power division of Canyon Industt�lue Heron Lane • P.O. Box 36 • Deming WA 98244 360.592-5552 • Fax: 360.592.2235 • em A: u i onhydro.com • www.canyonhydro.com (nyon (2, Va Hydro Commonly start-up, commissioning and training services are of value following installation. For a project of this type we can typically send a single technician who is capable of covering the mechanical and electrical portions of the equipment package. If start-up, commissioning and training assistance is of interest we suggest budgeting $8,000-$10,000 for a qualified Canyon Hydro technician. I look forward to working with you to ensure our equipment package meets all the requirements of the site and project. Please contact me as questions arise or as additional project information becomes available. Sincerely, Ryan Maloney Canyon Hydro- the water power division of Canyon Indust'Ik�i�r�(�.elue Heron Lane • P.O. Box 36 • Deming WA 98244 360.592-5552 • Fax: 360.592.2235 • email: urbmt canyonhydro.com • www.canyonhydro.com I �n I� [•n QW ii 0� z 0 o z Zu PER Z O ZD ry N O U Uf O LL F- O 19H-66 LU J > 0 O LL O 04 z W = m W No > IL IL � o Q U � z< J z = Q Z O = z � ::E o J o Q O o N OQ N 000000 19H-66 0 N � U r N 1-" U 1 � M o �o a r N C J o N N c C 0 0 0 ® U C G ° J �Jaad) PoaH ON III I III 'I � I I III'' w o �• j I I I 1J . _I_ II �__ I �_ _ _ !!I'��_I I_�_i•i�l �I_� I � � I- !�� '�� '• : I! I I! i I l l lily I� _! I I I I I •� — I I I I 1 (_ /gPDdD� u61sa4 X I —mo l� DluDi 9'tlS 1 U mo au m wnwixD — 17 y _— - ••�• i ! • _— 1_�, •1•. _I _L�I�_ � Id Iq 1 W_ IIf ,•i•• I !' I, ! I I I I ��- � III- i � I• I ' � , -I I �-�- o � IIT I I II �'!••. � 'i ' I I-rI 'Ij••'I',IIII�rtj� ;, � •"1 IIII IIIi�II _I—_ I I I I •�_, _ I I I �1 � � )_ I _ _ M!oDdDo 6upmadp IDuuory aDp oluoS 9-VS _1 � � I I I I I • I I I I I I I I�• o I �� � a6mantl ClOZ - -L_ IIrrI � I � I l � I� 1 S 9•VS .1 i I I i ;••� � •r. I i 1 I I-I� I I I� IIII I� ITIS I�I n'�rl 1 � I mold au!gmd wnwlu!W II�IIi���Iz 19H-67 �I� 19H-67 (rCanyon �J Hydro August 17, 2018 Michael KJ Anderson PE, VP Newcomb I Anderson I McCormick 201 Mission Street, Suite 2000, San Francisco, CA 94105 Dear Mr. Anderson, Thank you for your correspondence regarding the hydroelectric projects you are evaluating in California at the SA -1 Bristol and SA -3 McFadden locations. We appreciate the opportunity to work with you to offer the best possible Canyon Hydro equipment package for this site and application. Based on your correspondence we are offering an equipment package utilizing an In -Line Turbine optimized to pass 8.0 CFS at 90-120 PSI net head. Under these conditions maximum expected system production will be 145 kW using the equipment package described below. The turbine will pass your full specified design capacity of 10.0 CFS at 120 PSI net head with an expected maximum output of 183kW. (1) Soar ILT12-33-9.0 Variable Flow Hydro Turbine, 1800 RPM, adjustable wicket gates (1) US Motors Vertical Shaft, 250 HP, 1800 rpm, 480 VAC, 60 Hz, 3 ph., induction generator (1) 12" Electrically Actuated Turbine Inlet Valve (1) HPU to support wicket gate actuation with accumulator sized to close wicket gates in the event of power grid failure (fail-safe) (1) Switchgear and controls panels to parallel the generator with the local electrical utility grid and provide protective relays to utility grid standards for a project of this size. Specific utility requirements may change the scope of the switchgear/controls package offered and pricing may be affected. A one -line diagram and equipment list will be submitted for local electrical utility review and approval prior to proceeding with panel manufacture. Budget estimate system price, as described......................................................$261,000.00 The equipment package offered will be custom designed to meet the particular requirements of the site and project as explained through our discussions. As the project progresses and requirements are determined, we will be pleased to refine our budget estimate or offer a firm quotation. Budget estimates are offered for planning purposes only but are typically within 10% of a firm quotation for the same equipment package. Normal Terms 15% to begin final design 30% to begin manufacture following final design approval 25% mid -project 20% upon notice of readiness to ship 10% upon successful start-up or 90 days from readiness, whichever is first Normal Delivery 20-28 weeks from design approval and receipt of payments Delivery FOB Deming, Washington (crated for shipment) In addition to equipment supply, Canyon Hydro also offers equipment installation services by our in-house field crews who are highly experienced with the unique requirements of hydroelectric equipment. Canyon Hydro- the water power division of Canyon Indus a Blue Heron Lane • P.O. Box 36 • Deming WA 98244 360.592-5552 • Fax: 360.592.2235 • emai.turbines nyonhydro.com • www.canyonhydm.com C nyon Hydro Commonly start-up, commissioning and training services are of value following installation. For a project of this type we can typically send a single technician who is capable of covering the mechanical and electrical portions of the equipment package. If start-up, commissioning and training assistance is of interest we suggest budgeting $8,000-$10,000 for a qualified Canyon Hydro technician. I look forward to working with you to ensure our equipment package meets all the requirements of the site and project. Please contact me as questions arise or as additional project information becomes available. Sincerely, VY Ryan Maloney Canyon Hydro- the water power division of Canyon Indust����Blue Heron Lane • P.O. Box 36 • Deming WA 98244 360.592-5552 • Fax: 360.592.2235 • em il. u es ca onhydro.00m • www.canyonhydro.com I 0 O t N M v M � o 0 COD = (Do D c 0 0 v 0 N O LL C L U } }j. G 3 M M N N I ' � I _I_ _ •.I_I I -- I •�� � � •4•,� I A!iootlo� u61sap � � II i •, � •`�Llgodo� 6upo,ado ti Iow,oN � �•.L. I E -VS 8 PVS a6many Lf OL I II � im,•�,I a6o,enV LIOL uappoioW E-tlS 1- Z al �I I � O �, (laad) PoaH ON 19H-72 I I _3 _ I I 19H-72 '�. 4n 1Jij • c 6�x I . L K �1 1 N `t 6i GILKES BUDGET OFFER FOR THE SUPPLY OF HYDRO ELECTRIC EQUIPMENT Client: Newcomb Anderson McCormick — Michael Anderson Project Name: California Pump/Vault Hydroelectric Project Gilkes Reference No: DW-MA-CAvault-Nov13-2018 Date: Tuesday, 13 November 2018 Gilbert Gilkes & Gordon Ltd Canal Head North, Kendal, Cumbria LA9 76Z, England North American contact details; Darren Wager - d.wager@gilkes.com 19H-74 Attn: Michael Anderson California Pump/Vault Hydroelectric Project Dear Mike, Thank you for your interest in the supply of Gilkes equipment. Please find herein our budget offer for the supply of hydroelectric equipment for the above project located in California. Based on the head and flow data for the two turbines provided in your email of August 21st, 2018, we have arrived at the turbine offerings and project solution detailed in this budget quote. We have included for a standard electrical controls and switchgear package that would be designed for a 480V system and would terminate at the LV side of the generator switchgear. As this project develops further, we would be more than happy to provide you with a more comprehensive offer tailored to your specific requirements. We trust you find this revised budget offer of interest. Should you have any questions or require any further information please do not hesitate to contact me and I will assist accordingly. Yours Sincerely, Darren Wager Sales Director—Gilkes Hydro Hydro Gilbert Gilkes & Gordon Ltd. Mobile: +1(253) - 318-0005 Email: d.wager@gilkes.com 19H-75 The Gilkes Package A Gilkes equipment package is comprehensive and exclusive of hidden extras; • All factory assemblies which are stripped down for shipment are witness marked and colour coded to assist on site assembly. • All major sub -contracted equipment is sourced from established suppliers from our approved supplier list. These sub -contractors have proved to be high quality, reliable suppliers with a technical appreciation and experience of small hydro generation projects. • Gilkes packing methods are customised to suit the requirements dictated by the project location and access to the project site. Equipment can be packed for long periods of storage. • Gilkes engineers provide expert on-site installation & commissioning services. • Operating Manuals are included. • A Gilkes project team is assigned to engineer the contract from start to finish and customer "single line" contact is organised through a contract engineer. • The delivery schedule is handled by Gilkes Product Control Department and all sub- contractors are closely monitored to ensure "on time" delivery of all equipment. You will note from the above that Gilkes do not only offer a manufacturing service but a complete specialised service comprising of rugged quality equipment along with the experienced technical engineering backup and installation expertise required. We have found from many years' experience that in the long term quality is an important requirement for small hydro plants to ensure optimum reliability and minimum maintenance costs. Gilkes' Engineering Expertise Every hydro project supplied by Gilkes is subject to the attentions of a team of highly qualified engineers including a contract manager, degree qualified mechanical engineer, draughtsperson and the sales engineer whom you will be dealing with throughout the tender stage. We believe that this approach ensures that your needs are fully understood by the whole of Gilkes and ensures that 19H-76 projects proceed smoothly and on time with the minimum of project management and/or engineering design/consultancy services. In our experience it is always better to design for, rather than close our minds to, possible failure modes. We therefore accept that it is necessary for turbines to reach full run -away speed safely and have generators supplied to us tested at full run -away speed to ensure that no damage will occur. Some suppliers use lower cost generators which will handle 130% or 140% of normal speed and hope to be able to shut their turbines down before the turbine has accelerated to full run -away and accept that if the machine does ever reach full run -away the generator will be damaged. Gilkes experience is that full run -away is usually reached in less than 5 seconds and is therefore extremely difficult to avoid. 19H-77 Scope of Supply —Turbine #1 1 off 250 G100 Francis turbine fitted with a hydraulic actuator on the guide vanes 1 off Set of inlet pipework up to the inlet flange of the main inlet valve (including dismantling joint) 1 off Main inlet valve, butterfly valve, weight to close and hydraulic actuator to open 1 off 60Hz 1200rpm (6 pole), 480V, Induction Generator, with the turbine runner supported on a Gilkes bearing housing connected to the turbine by means of a flexible coupling arrangement 1 off Electrical controls and switchgear package 1 off Installation and Commissioning supervision of Gilkes supplied equipment provided upon request 19H-78 Exclusions We have not included the following items which are required for our equipment or the project in general: • Relay protection study (values from the study will be inserted into our relays). • Secondary injection test at site to prove the results of the protection study. • Any and all activities related to on-line grid connection with the utility. • Any and all power and control cabling for main and auxiliary systems. • Any and all civil works including sealing of cable ducts. • Any and all crane hire and lifting arrangements. • Grounding mat. • Broadband connection/phone line for any remote communication. • HV switchgear. • Hydraulic Control Module • Any and all Building Services. • Any and all activities related to the head level sensing. • Any and all physical Installation activities related to the lifting and positioning of the equipment. • Plant installation and commissioning supervision. • Performance testing. • Any and all site set up, facilities and additional site labour. Extent of Supply The supply of Gilkes plant terminates at the following points: • Turbine inlet -at the upstream face of the main inlet valve. • Turbine discharge — at the draft tube discharge. • Generator—at the generator terminal connectors. • Electrical — at the LV of the generator switchgear 19H-79 Price Schedule —Turbine #1 Item Qty Description Price ($USD Dollars) 1 1 250 G100 Francis Reaction Turbine assembly Included Case Runner Bearing housing Including: Guide Vanes and Linkages Inlet spool pipe, Outlet Bend and Draft Tube Shims and tools 2 1 Main inlet valve Included 3 1 Induction generator Included 4 1 Controls & Switchgear package Included 5 1 Hydraulic Power Unit Included Installation Supervision of Gilkes supplied 6 0 Not Included equipment available upon request Commissioning Supervision of Gilkes supplied 7 0 Not Included equipment available upon request TOTAL BUDGET PRICE —$USD DOLLARS $369,455 All figures are exclusive of local, State, and Federal taxes which will be charged to the customer account where applicable. Import duties and delivery to site is included. This pricing is indicative only and is based on the information made available to us prior to the date of this offer. None of the prices are fixed or firm and will be subject to further review by Gilkes should you wish to proceed with placing an order. Please note that this budget offer is not intended to form a legally binding relationship and Gilkes is not bound to accept purchase orders against this proposal. 19H-80 Payment Terms Unless otherwise agreed, the following representative payment terms apply: - 15% of total contract price with order 25% of total contract price on presentation of the following drawings General arrangement - Foundation details to allow civil works to proceed 25% of total contract price on presentation of runner material certificates. 30% of total contract price on delivery of equipment to ship to site, or on notification of readiness to ship, if site is unable to receive goods. Storage charge can be applied if delivery is delayed by more than 3 months. 5% of total contract price due on Completion of Commissioning, or 4 months after delivery to site, or 6 months after notification of readiness to ship, whichever is the sooner. If Commissioning of Turbine is to be by others then final payment due on shipping. All payments net 30 Days from date of invoice. Estimated delivery We estimate the delivery to site for the equipment offered in our quotation to 48 Working Weeks, DDP Incoterms ® 2010 from receipt of an official order complete with full and final instructions to proceed and on receipt of any initial stage payment. Deliveries offered are indicative only. Firm delivery periods are dependent upon contract start dates, and are subject to Gilkes' factory work loading and major casting availability at the contract start date. Contract timescales commence on receipt of an official order complete with full & final instructions to proceed and initial payment. Firm delivery periods will be reviewed at time of order. General Contract Terms & Conditions Available on request 19H-81 Technical Data —Turbine #1 The technical data given in this quotation, unless specifically guaranteed, will be subject to confirmation in the event of an order. Model No. of Units Mean Diameter of Runner Rated Speed Maximum Overspeed Maximum continuous overspeed period Runner material Shaft orientation Mechanical shaft power at 244.5ft Net Head and 8cfs Flow Turbine efficiency at 244.5ft Net Head and 8cfs Flow Performance Curve 250 G100 Francis Turbine 1 250 mm 1200 rpm 2220 rpm 2 minutes in any 24-hour period CA6NM or equivalent Stainless steel Horizontal 147 kW 88.5 The following performance and efficiency curve are representative of your project's hydraulic conditions and is depicts the turbine's mechanical power (kW) and efficiency (%) as a function of head (ft) and flow (cfs). 19H-82 GFLKE8 250 G100 Francis Turbine Speed 1200 Rpm 300 250 s 200 a� w 5 0 v 150 5 N 7 5 N 100 50 0 300 120 250 100 200 80 CL 150 60 C o U w 100 40 50 20 00 2 4 6 8 10 12 14 160 Flow rate in ftA3/sec Name Head Flow rate Power Efficiency Vent feet ftA3/sec kW percent mm New Duty 244.5 8 147 88.5 13.6 Gilbert Gilkes and Gordon Ltd Approved Kendal, Cumbria, UK. LA9 713Z CA Vault Tel: 01539 720028 Fax: 01539 732110 1914183 Version Number 20 Scope of Supply —Turbine #1 1 off 250 G100 Francis turbine fitted with a hydraulic actuator on the guide vanes 1 off Set of inlet pipework up to the inlet flange of the main inlet valve (including dismantling joint) 1 off Main inlet valve, butterfly valve, weight to close and hydraulic actuator to open 1 off 60Hz 1200rpm (6 pole), 480V, Induction Generator, with the turbine runner supported on a Gilkes bearing housing connected to the turbine by means of a flexible coupling arrangement 1 off Electrical controls and switchgear package 1 off Installation and Commissioning supervision of Gilkes supplied equipment provided upon request 19H-84 Exclusions We have not included the following items which are required for our equipment or the project in general: • Relay protection study (values from the study will be inserted into our relays). • Secondary injection test at site to prove the results of the protection study. • Any and all activities related to on-line grid connection with the utility. • Any and all power and control cabling for main and auxiliary systems. • Any and all civil works including sealing of cable ducts. • Any and all crane hire and lifting arrangements. • Grounding mat. • Broadband connection/phone line for any remote communication. • HV switchgear. • Hydraulic Control Module • Any and all Building Services. • Any and all activities related to the head level sensing. • Any and all physical Installation activities related to the lifting and positioning of the equipment. • Plant installation and commissioning supervision. • Performance testing. • Any and all site set up, facilities and additional site labour. Extent of Supply The supply of Gilkes plant terminates at the following points: • Turbine inlet - at the upstream face of the main inlet valve. • Turbine discharge — at the draft tube discharge. • Generator— at the generator terminal connectors. • Electrical — at the LV of the generator switchgear 19H-85 Price Schedule—Turbine #2 Item Qty Description Price ($USD Dollars) 1 1 300 G100 Francis Reaction Turbine assembly Included Case Runner Bearing housing Including: Guide Vanes and Linkages Inlet spool pipe, Outlet Bend and Draft Tube Shims and tools 2 1 Main inlet valve Included 3 1 Induction generator Included 4 1 Controls & Switchgear package Included 5 1 Hydraulic Power Unit Included Installation Supervision of Gilkes supplied 6 0 Not Included equipment available upon request Commissioning Supervision of Gilkes supplied 7 0 Not Included equipment available upon request TOTAL BUDGET PRICE — $USD DOLLARS $398,919 All figures are exclusive of local, State, and Federal taxes which will be charged to the customer account where applicable. Import duties and delivery to site is included. This pricing is indicative only and is based on the information made available to us prior to the date of this offer. None of the prices are fixed or firm and will be subject to further review by Gilkes should you wish to proceed with placing an order. Please note that this budget offer is not intended to form a legally binding relationship and Gilkes is not bound to accept purchase orders against this proposal. 19H-86 Payment Terms Unless otherwise agreed, the following representative payment terms apply: - 15% of total contract price with order 25% of total contract price on presentation of the following drawings - General arrangement Foundation details to allow civil works to proceed 25% of total contract price on presentation of runner material certificates. 30% of total contract price on delivery of equipment to ship to site, or on notification of readiness to ship, if site is unable to receive goods. Storage charge can be applied if delivery is delayed by more than 3 months. 5% of total contract price due on Completion of Commissioning, or 4 months after delivery to site, or 6 months after notification of readiness to ship, whichever is the sooner. If Commissioning of Turbine is to be by others then final payment due on shipping. All payments net 30 Days from date of invoice. Estimated delivery We estimate the delivery to site for the equipment offered in our quotation to 48 Working Weeks, DDP Incoterms ® 2010 from receipt of an official order complete with full and final instructions to proceed and on receipt of any initial stage payment. Deliveries offered are indicative only. Firm delivery periods are dependent upon contract start dates, and are subject to Gilkes' factory work loading and major casting availability at the contract start date. Contract timescales commence on receipt of an official order complete with full & final instructions to proceed and initial payment. Firm delivery periods will be reviewed at time of order. General Contract Terms & Conditions Available on request 19H-87 Technical Data —Turbine #2 The technical data given in this quotation, unless specifically guaranteed, will be subject to confirmation in the event of an order. Model No. of Units Mean Diameter of Runner Rated Speed Maximum Overspeed Maximum continuous overspeed period Runner material Shaft orientation Mechanical shaft power at 244.5ft Net Head and 8cfs Flow Turbine efficiency at 244.5ft Net Head and 8cfs Flow Performance Curve 300 G100 Francis Turbine 1 300 mm 1200 rpm 2220 rpm 2 minutes in any 24-hour period CA6NM or equivalent Stainless steel Horizontal 162 kW 89.9 The following performance and efficiency curve are representative of your project's hydraulic conditions and is depicts the turbine's mechanical power (kW) and efficiency (%) as a function of head (ft) and flow (cfs). 19H-88 GFLKES 300 G100 Francis Turbine Speed 900 Rpm 200 160 5 0 G120 -o m = 80 40 0 100 250 80 200 60 c a� 150 Y a `y T U n° 40 100 Lu 50 20 0 0 4 8 12 16 200 Flow rate in ftA3/sec Name Head Flow rate Power Efficiency Vent feet ftA3/sec kW percent mm New Duty 177.6 12 162 89.9 20.9 Gilbert Gilkes and Gordon Ltd Approved Kendal, Cumbria, UK. LA9 7BZ CA Vault Tel: 01539 720028 Fax: 01539 732110 19HIJ89 Version Number 20 Turbine Description & Material Specification Runner Material 13/4 Chrome Steel to BSEN10293: 2005 or ASTM A743 CA6NM Single casting, part machined, with hand finished blades. The runner blade profile will be finished using templates to meet the current IEC standards. Dynamic balancing specified to G6.3. OR 13/4 Chrome Steel to BS 3100 425 C1; ASTM 473 541500; A743 CA6N; EN 1.4313 or similar. The runner will be machined from solid forgings and fabricated construction: CNC machined from a fully heat treated forged disc with hand polished buckets. The runner skirt and crown will have adequate metal thickness for machining to facilitate the fitting of loose wear rings should this ever be necessary. 19H-90 Spiral Case Top & Bottom Covers Chamber facings / Cheek Plates Main Shaft Seal (overhung design) Guide Vanes Fixing to the generator shaft will be by keyway, flange connection or hydraulic locking device. Material Ductile Spheroidal Graphite Cast Iron to BSEN1563 Gr: 450/10 Single casting with horizontal inlet. The casting will be complete with hand hole covers, drain outlet, manual valves and all necessary joints, tappings, pipework, brackets and foundation bolts. Material: Ductile Iron ASTM A536 GR 60-45-10 Fitted with self-lubricating bearings for the guide vane shafts. The operating ring cylindrical extension piece will be fitted with a bearing liner in cast leaded gun metal to BS EN1982 CC491K. Material—Stainless Steel to BSEN10293: 2005 or ASTM A743 CA6NM or C95xxx Aluminum Bronze Replaceable wearing chamber facing plates, secured to the turbine top and bottom covers by counter sunk screws. The covers will be fully machined, and fitted with loose stainless steel wear rings and facing plates. Proprietary throttle bush and labyrinth incorporating catchment chamber and pipe. Material 13/4 Chrome Steel to BSEN10293: 2005 or ASTM A743 CA6 N M Single castingwith fully machined spindles, part hand finished blades. The spindles extend through the inlet cover through bronze bushes which are self -lubricated by graphite filled spiral grooves requiring no additional external lubrication. 'C' ring seals prevent any leakage between the spindles and bushes. A PTFE thrust bearing is incorporated for each guide vane. The guide vane levers will be connected to the guide vane by clamping their split bosses on the guide vane drive spindle. This will provide a friction hold to permit slip should a guide vane become 19H-91 jammed by debris. The guide vane levers and spindles are match marked to permit easy resetting should the mechanism be disturbed. The guide vane levers are regulated by the operating ring via an individual link mechanism regulates the guide vane levers. All moving Draft Tulle Fabricated Carbon Steel Plate to BS EN 10025:1993 5275 Tapered pipe with flange suitable for connection to turbine discharge. Dismantling Joint A Viking Johnson flanged dismantling joint is included. The dismantling joint will be located between the turbine inlet pipe and the main inlet valve to assist alignment and disassembly of the turbine inlet pipework for maintenance purposes. Foundation Bolts All necessary foundation bolts plus a generous supply of packing pieces for installation setting up purposes are included. Painting All Components were required will be painted in accordance with Gilkes current standard Paint system. 19H-92 pins are carried in renewable self-lubricating bronze bushes. Guide Vane Material Fabricated Carbon Steel Plate to BSEN 10025 Gr 5275 JR Operating Ring The operating ring will be connected to the turbine guide vane mechanism and operated by an Electric or Hydraulic actuator. Guide Vane The guide vane operator will regulate water flow Operator The operator will be fitted with: - a) End of travel and intermediate limit switches. b) Linear variable displacement transducer. Inlet Pipe Material Fabricated Carbon Steel to BSEN 10025 Gr 5275 JR. The inlet pipe will be flange connected to the turbine case. The plain upstream end will be machined for connection to a flanged dismantling joint, (included in our supply). The inlet pipe will be supplied with 1 off pressure transducer and dial type pressure gauge. Outlet Bend Material Ductile Spheroidal Graphite Cast Iron to BS 1563 450/10 Draft Tulle Fabricated Carbon Steel Plate to BS EN 10025:1993 5275 Tapered pipe with flange suitable for connection to turbine discharge. Dismantling Joint A Viking Johnson flanged dismantling joint is included. The dismantling joint will be located between the turbine inlet pipe and the main inlet valve to assist alignment and disassembly of the turbine inlet pipework for maintenance purposes. Foundation Bolts All necessary foundation bolts plus a generous supply of packing pieces for installation setting up purposes are included. Painting All Components were required will be painted in accordance with Gilkes current standard Paint system. 19H-92 Ole' 1IW 1 -I 11 � i© Io Im G 1 IN V LO LO Ib 10N 0 J ,ll V H J O N > 5< -Lu W J 06£ 'dAl OOY 09 H W Y �0 Q> IL > J � J � Q 0 O LO 0w H IL a>� U I O O � N ❑ O O N P N N N G 1 IN V LO LO Ib 10N 0 J ,ll V H J O N > 5< -Lu W J 06£ 'dAl OOY 09 H W Y �0 Q> IL > J � J � Q 0 O LO 0w H IL a>� U I O b I N Q m H R J z O 10 v 0 V w �v 1La Z n =Owa U.=U- �.vr� v U t2 CC �Qw N =Q F J �wUF )_NQ.0 v) �' vvwine UC (`7 a LO V CV n Ow ¢❑ Z� ¢U a ❑ V o O 0 0 0 VI () P N N R J z O 10 v 0 V w �v 1La Z n =Owa U.=U- �.vr� v U t2 CC �Qw N =Q F J �wUF )_NQ.0 v) �' vvwine UC (`7 a LO V CV n Ow ¢❑ Z� ¢U �o ❑w o� �LL Uz wO OV U¢p S w O ¢z >w ¢ W-0 W O z w< w�'� >?- a U Q OZw w O mQ❑ ��O ❑ 0 ��Q w H ❑w❑u 0 Zww Q O Q UZ> w� NO >Z � ON zw wm m� w K ❑ R J z O 10 v 0 V w �v 1La Z n =Owa U.=U- �.vr� v U t2 CC �Qw N =Q F J �wUF )_NQ.0 v) �' vvwine UC (`7 a LO V CV n APPENDIX E: PLANT OPERATING RECORDS APPENDIX E PLANT OPERATING RECORDS E-1 Newcomb I Anderson I McCormick 19H-96 CITY OF SANTA ANA 19H-97 City of Santa Ana Public Works Agency Water Resources Division Production and Control Section SA -1 Generator Panel Readines MR ib5 I5� 150 138 !305 Sob 560 510 � ®�®. 19V 16,5 ilo 1-19 M 1 9 (Ys Iv5 , - ...., . . tg I ro? 1908 Ijdf47.5 1 $365,`% 1 V 60, i 1%b 51.5 �- M-- M -- r -A { l� y 20 al 27 145 ILId 140 516 505 505 SID 5o5 Sas 515 505 505 1$0 118 110 I'18 Irr05 1r95 ISo IqIZ0 %10 I$o 115 110 Ito% 1408 m7 I88b5. 1 14031 •2 19203.1 rtA aA V -w C�II�L'L•�!�lP.� - • 11.771�R -��R��ll6�al�! �rm���r�rmrm�rr�■r�r��� ��l� -- �riiir�■��rr�r_�ir=�a It,1�7��� •` ��� • i�l�1GL���© ,f.7��Y1�1a�����1��.71p�:w�7� • � �11M mmmm j1j� 3 z� �- I q-5 ib5 I5� 150 138 !305 Sob 560 510 soy 605 505 505 505 505 5,o5 510 19V 16,5 ilo 1-19 M 1 9 (Ys Iv5 Iy 1 5 (4v Igo 1 o l 10 r63 tg I ro? 1908 Ijdf47.5 1 $365,`% 1 V 60, i 1%b 51.5 �- M-- M -- r -A { l� y 20 al 27 145 ILId 140 516 505 505 SID 5o5 Sas 515 505 505 1$0 118 110 I'18 Irr05 1r95 ISo IqIZ0 %10 I$o 115 110 Ito% 1408 m7 I88b5. 1 14031 •2 19203.1 rtA aA V -w 19H -98 111. Vf �9 8.3 PVf, 4.7, Mwt7-F o- ?LV,4- M - SA1 Date Totalizers ChlorineWS.O Comments Location I SCADA Differencl Total Free At wow 66v05*05 &F/;FRB 8 0 h s ,'x'67%6 P �w /' ZZ QT( b g3 6�1 9- - 16,11 SYS 1.6 10.5.4 311111 Y. o iO-lj.q 170 to 2-5 i .22•Y lZ Z to W' l0 7 2 _S L( Z -S-4 'I'�Y53 1.5 /IL 1Z-11 115tg6Nb3 35 6,--b—d1,7 f+– Z•Zr /7533 x/0 3564639 I g 2.-7-0 1-15 SrD6o1 t - �{ • S I Soo 1-12 7 YoT3 �'O � �•2a -17 5672 .- 1-26 %,41 2 3 12S *-0 Pool? 3B I7U7-g9$ 3-H IIVO zArij jz.2 1$22-7 n t SA Log forms 19H-99 m� 0 Cl N cu ca cu 0 U r_ 0 Z .5 0 CD U N N CDca r 4 a • SA1 qj�OWA 19H-103 SA Log forms.xls � SA1 0. 6 i ZDv5 Date Totalizers torine WSO Comments Location SCADA Difference Free K 13 111tj 1827 3 I%S-Z'?-34q Ilk'u (9-7 185 gbgz. = Z 6-1' 7 6�t57o x Z ,P t4 2.3 167 0 b 4'v 0., L �— (�'� l 5'I 8'162-1 e . � IBS oho 24 I.Cl -, -� 0-3 P-17-0 X07 F'z70 cD -2lei 6qq p •lL Z5z D5 7-.y � �- �( 23 I It 2-6 W5 )z.7- 'eve to . Y 19400063 914 P. I'L MS30Q5 kl to.tq 1950o98 -i at+ 10--47 17 531,roo eN It•2 1454647-0 rte u S6 N-3/ l 19H-104 SA Log forms 0 0 0 1 47n- I %P;u zg fL it cq C4 C4 LL IQ p Ir ol 61 1 47n- I %P;u APPENDIX F: MONTHLY PRODUCTION REPORTS APPENDIX F MONTHLY PRODUCTION REPORTS F-1 Newcomb I Anderson I McCormick 19H-106 CITY OF SANTA ANA 19H-107 Nabil's FORMS A- Ground Water Production: A I. Wells Pumped to Res.: Well Production: CF No. (Constant -100) 16 0 fa 3,326,696 20 6,047,949 21 97,928 24 2,048,192 26 5,329,344 27 12,301,565 29 0 30 12,723,584 33 0 34 11,300 36 6,757,760 39 5,493,764 Total; CF 54,138,082 AF 1,242.8 A 2- Wells Pumped to Svstem: 28 8,175,067 31 6,092,008 32 0 35 9,650,250 37 4,252,437 38 118,490 40 0 41 10,205,148 Total; CF 38,493,400 AF 883.7 ..................................... ..................................... A3F:Totali Grnund.Fidd udtiuii;�i:�>ii:�; Station Production: CF Discharge: (Constanh100) West 18,957,695 John G. 18,271,820 Crooke 12,127,300 Cambridge 333,529 East 5,346,280 South 18,970 Walnut 0 Total: CF 55,_055,594 AF 1,263.9 B 2- By -Passed from System: West 0 John G. 0 Crooke 0 Cambridge 361,291 East 0 South 53,847 Walnut 0 Total: CF 415,138 AF 9.5 8 3 -Station Net Production: West 18,957,695 John G. 18,271,820 Crooke 12,127,300 Cambridge -27,762 East 5,346,280 South -34,877 Walnut 0 Total., CF 54,640,456 AF 1,254.4 MWD Production: CF AF Connect. SA 1 400 0.0 SA 2 0 0.0 SA 3 500 0.0 SA 4 0 0.0 SA 5 0 0.0 SA 6 2,410,100 55.3 SA 7 2,402,400 _ 55.2 u- t roU. or the montti: CF AF % �3=Tntal:Water:Frddud€onii:: :::: .... i : : ....:....: ......i ....:: i:::37y44:d)S82 i;l:: Z;?37:0 2i ......... .. �t2co.'udija:f`:�9�:ff6"✓Q 709,792,729 16,296 .......... 125 <:>Sa: ?tMINQii2t iir2i 4;813;40Dtr::'FdU`5 3,320 ::::^;4;9'4:?In E- Prod. Of the Fiscal Year. Fiscal Year Elapsed Days: CF E 1 -Total F.Y. Production: 215 AF % Total: 854,389,329 19,616.0 1Total: Ground -CUP Ground: 709,792,729 16,296 .......... 125 <:>Sa: E- Prod. Of the Fiscal Year. Fiscal Year Elapsed Days: CF E 1 -Total F.Y. Production: 215 AF % Total: 854,389,329 19,616.0 1Total: Ground -CUP Ground: 709,792,729 16,296 83.08% MWD: 144,596,600 3,320 16.92% t z- t.y. cur uremt uue: Credit Due: I 0.0 AF % E 3 -Total F.Y. Production with CUP: E4- Peak Production Time Day Production Pk Day: CF 7/25/2016 5,026,468 Pk Flw CFS 20:12 6/20/2016 87.7 F- Production Reduction Compared to 2013 Calendar Month: AF % 2013 1 2,748.31 18.6% Page l 19H-108 19,616.0 1Total: Ground -CUP 16,296.0 83.08% MWD+CUP 3,320.0 16.92% E4- Peak Production Time Day Production Pk Day: CF 7/25/2016 5,026,468 Pk Flw CFS 20:12 6/20/2016 87.7 F- Production Reduction Compared to 2013 Calendar Month: AF % 2013 1 2,748.31 18.6% Page l 19H-108 APPENDIX G: TURBINE COST ESTIMATES APPENDIX G TURBINE COST ESTIMATES G-1 Newcomb I Anderson I McCormick 19H-109 CITY OF SANTA ANA 19H-110 City of Santa Ana Hydro Turbine Generators Project Cost Estimate SA -1 Replace Turbine Generator with a New Unit Equipment Description Canyon Hydra Saar In Line Turbine 8.0 CFS, 90-120 psi, 183 kW max Includes Soar ILT 12-33-9.0 Variable Flow Hydra Turbine, 1800 rpm, adjustable wicket gates; US Motors Vertical Shaft 250 hp, 480 VAC Induction Generator; 121nch Electrically Actuated Turbine Inlet Valve; HPU to support wicket gate actuation with accumulator sized to close wicket gates in power failure; Switchgear and Control Panels with protective relays to utility grid standards Commisioning Parts, Startup, Site Testing Mechanical/Electrical Building Modifications Construction, EPC Contractor Demolition of Existing Plant (Offsetting with Salvage Value) Salvage Value of Existing In line Turbine Shipping - In Line Turbine Development Costs - Permitting, Interconnection, SCE Balance of Plant Contingency Subtotal Materials +Labor Sales Tax on Materials Contractor Construction Management Contractor C&P Contingency on Construction Contract Design Engineering City Project Management City Construction Support ProjectTotal SA -1 Incentive from SGIP or Average Load Incentive Net Project Cost References 1. Canyon Hydro Proposal 17 Aug 2018 2. NAM Santa Ana Hydro Turbine Cost Extended Bare Bare Labor Bare Material Material Cost Cost per Unit Qty Cost Per Unit($) ($) ($) 1 $ 261,000 $ 261,000 $ - Extended Bare Labor Costs ($) Reference $ 1 0 $ $ $ - 1 1 $ - $ 10,000 $ 10,000 1 0 $ $ $ - 1 $ 10,000 $ 10,000 $ 10,000 $ 10,000 2 1 $ - $ - $ 100,000 $ 100,000 2 1 $ $ $ $ 1 $ $ $ $ 1 $ 5,000 $ 5,000 $ - 2 1 $ - $ 1 $ - $ 5,000 $ 5,000 2 1 $ $ 1 $ 25,000 $ 25,000 $ 2 $ 301,000 $ 125,000 $ 426,000 9.25% $ 27,843 5% $ 21,300 15% $ 63,900 20% $ 85,200 9% $ 38,340 7% $ 29,820 6% $ 25,560 $ 717,963 $ 0.60 /Watt $ 600 /kW 132 kW $ 79,200 $ 638,763 Copyright (c) Newcomb I Anderson I McCormick 2017. All rights reserved19 H -111 11/29/2018 City of Santa Ana Hydro Turbine Generators Project Cost Estimate SA -3 Install New Turbine Generator in a New Vault Equipment Description Canyon Hydro Soar In Line Turbine 8.0 CFS, 90-120 psi, 183 kW max Includes Soar ILT 12-33-9.0 Variable Flow Hydro Turbine, 1800 rpm, adjustable wicket gates; US Motors Vertical Shaft 250 hp, 480 VAC Induction Generator; 12 inch Electrically Actuated Turbine Inlet Valve; HPU to support wicket gate actuation with accumulator sized to close wicket gates In power failure; Switchgear and Control Panels with protective relays to utility grid standards Commisioning Parts, Startup, Site Testing Vault -Excavation, concrete, backfill, lid, sidewalk, landscaping 10'x 30' at $350/sf Mechanical/Electrical Building Modifications Construction, EPC Contractor Demolition of Existing Plant (Offsetting with Salvage Value) Salvage Value of Existing In Une Turbine Shipping - In Line Turbine Development Costs - Permitting, Interconnection, SCE Balance of Plant Contingency Subtotal Materials + Labor Sales Tax on Materials Contractor Construction Management Contractor 0&P Contingency on Construction Contract Design Engineering City Project Management City Construction Support Project Total References 1. Canyon Hydro Proposal 17 Aug 2018 2. NAM Extended Bare Bare labor Bare Material Material Cost Costper Unit Qty Cost Per Unit ($) ($) ($) 1 $ 261,000 $ 261,000 $ - Extended Bare Labor Costs ($) Reference $ 1 0 $ $ $ - 1 $ - $ 10,000 $ 10,000 1 $ 15,000 $ 15,000 $ 20,000 $ 20,000 0 $ $ $ 0 $ $ $ 1 $ 10,000 $ 10,000 $ 10,000 $ 10,000 1 $ - $ - $ 100,000 $ 100,000 1 $ $ $ $ 1 $ $ $ $ 1 $ 51000 $ 5,000 $ - 1 $ $ 1 $ 35,000 $ 35,000 $ 5,000 $ 5,000 1 $ $ - 1 $ 25,000 $ 25,000 $ $ 351,000 $ 145,000 19H-112 $ 496,000 9.25% $ 32,468 5% $ 24,800 15% $ 74,400 20% $ 99,200 9% $ 44,640 7% $ 34,720 6% $ 29,760 $ 835,988 1 1 2 2 City of Santa Ana Hydro Turbine Generators Project Cost Estimate SA -6 Install New Turbine Generator in a New Vault Equipment Description Gilkes 300 G100 Francis Turbine Assembly Includes 300 G300 Francis Reaction Turbine, Case, Runner, Bearing Housing, Guide Vanes and Linkages, Inlet Spool Pipe, Outlet Bend and Draft, Tube, Shims, Main Inlet Valve, Induction Generator, Controls & Switchgear Package, Hydraulic Power Unit. Commisioning Parts, Startup, Site Testing Vault - Excavation, concrete, backfill, lid, sidewalk, landscaping 10'x 10' at $350/sf Mechanical/Electrical Building Modifications Construction, EPC Contractor Demolition of Existing Plant (Offsetting with Salvage Value) Salvage Value of Existing In Line Turbine Shipping - In Line Turbine Development Costs - Permitting, Interconnection, SCE Balance of Plant Contingency Subtotal Materials + Labor Sales Tax on Materials Contractor Construction Management Contractor O&P Contingency on Construction Contract Design Engineering City Project Management City Construction Support Project Total References 1. Canyon Hydro Proposal 17 Aug 2018 2. NAM Extended Bare Bare Labor Extended Bare Material Material Cast Cast per Unit Bare Labor Oty Cost Per Unit ($) ($) ISI Casts ($j Reference 1 $ 398,919 $ 398,919 $ - $ - 1 0 $ $ $ - 1 $ - $ 10,000 $ 10,000 1 $ 15,000 $ 15,000 $ 20,000 $ 20,000 0 $ $ $ 0 $ $ - $ 1 $ 10,000 $ 10,000 $ 10,000 $ 10,000 1 $ - $ - $ 100,000 $ 100,000 1 $ $ $ $ 1 $ $ $ $ 1 $ 5,000 $ 5,000 $ - 1 $ $ 1 $ 35,000 $ 35,000 $ 5,000 $ 5,000 1 $ $ 1 $ 25,000 $ 25,000 $ $ 488,919 $ 145,000 19H-113 $ 633,919 9.25% $ 45,225 5% $ 31,696 15% $ 95,088 20% $ 126,784 9% $ 57,053 7% $ 44,374 6% $ 38,035 Fs --l-,072,1741 1 1 2 2 2 2 2 2 APPENDIX H: SOLAR MODEL PARAMETERS APPENDIX H SOLAR MODEL PARAMETERS H-1 Newcomb I Anderson I McCormick 191-1-114 CITY OF SANTA ANA 19H-115 Solar Model Parameters The sheet contains the parameters used in the financial model. All cells (grey) must be completed. Ownership PPA O&M ProJect Deialls Date 2019 11/30/2018 Auto populates Client City of Santa Ana Linked to OnePager footer Project Name Water Tanks Linked to OnePager Title Project Number 2669 As percentage of upfront costs General Notes 0 Range 0 to 25, 0 represents upfront lump cost. Applies to PPA cash flow. Costs- and Term ons ruc ion, a u, os Calc Method Metric ($/W) Notes PM, Contingency - Ownership 8.00% As percentage of upfront costs Cash Purchase Term (Years) 25 PM, Contingency - PPA 5.00% As percentage of upfront costs PM, Contingency -Term 0 Range 0 to 25, 0 represents upfront lump cost. Applies to PPA cash flow. PPA Term (Years) 25 Typically 20 or 25 years O&M Cost - Escalator (%/yr) 3.0% O&M Cost - Term 25 Range 0 to 25, 0 represents upfront lump cost. Applies to non -PPA cash flow. Simple Loan Term (Years) 25 (previously known as bond term) Assumptions. # of Projects 1 Total number of projects being considered Rating Code 3 From 1 to 3, default to 3 NPV Discount Rate 3.00% Start Month 1 Month of operation/installation Start Year 2019 Basic Interest Rate 4.50% Range 4.5% to 6.5% Utility Rebate 1 Term (Years) 5 19H-116