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Home My WebLink About; Maerkle Reservoir; Pressure Control Hydroelectric Facility at Maerkle Reservoir; 2015-02-02Engineers...Working Wonders With Water' Carlsbad Municipal Water District TECHNICAL MEMORANDUM PRESSURE CONTROL HYDROELECTRIC FACILITY AT MAERKLE RESERVOIR REVISED FINAL April 2010 2 700 Ygnacio Valley Road • Suile 3O0 • Walnut Creek, California 94598 pwy/Carolio/Documenls/Client/CA/Caflsbad/8362A10/Oeliver3bles/Carlsl)3d_TM(RevisedFinal) 1925) 932-1710 FAX (925) 930-0208 Carlsbad Municipal Water District PRESSURE CONTROL HYDROELECTRIC FACILITY AT MAERKLE RESERVOIR TECHNICAL MEMORANDUM TABLE OF CONTENTS I. 0 EXECUTIVE SUMMARY 1 1.1 Design Head and Flow 1 1.2 Turbine Type and Facility 2 1.3 Results and Recommendations 2 2.0 BACKGROUND AND INTRODUCTION 3 3.0 TURBINE DESIGN HEAD AND FLOW 3 3.1 Turbine Head 3 3.2 Desalination Feed 6 3.3 Turbine Flow 6 4.0 HYDROELECTRIC TURBINE 10 4.1 Turbine Technology Background 10 4.2 Recommended Turbine Type 12 4.3 Emerging Hydroelectric Turbine Technology 16 5.0 FLOW CONTROL 16 5.1 Existing Reservoir Flow Control 16 5.2 Proposed Flow Control with Turbine 18 6.0 HYDROELECTRIC TURBINE BUILDING 23 6.1 New Building Location 23 6.2 Building Size and Type 23 6.3 Noise 25 6.4 Ventilation 25 7.0 ALTERNATIVES 25 8.0 ELECTRICAL AND INSTRUMENTATION CONSIDERATIONS 27 8.1 Generatorand Electrical Equipment 27 8.2 Controls 27 8.3 Interconnection Standards 28 8.4 Interconnection Details 28 8.5 Customer Generator Rate Options 30 9.0 COST ESTIMATE 31 10.0 ECONOMIC ANALYSIS 32 10.1 NPV Assumptions 32 10.2 Economic Analysis Results 33 10.3 Time of Use 33 10.4 CEQA and Permitting 35 10.5 Consultation Process 35 10.6 Application 36 II. 0 RECOMMENDATIONS AND CONCLUSION 36 April 2010 pw.//Carollo/[}ocuments/Client'CA/Carlsbad/8362A10/Deliverables/Cartsbad_TM (RevisedFinal) LIST OF APPENDICES A - Maerkle Reservoir Site Plan B - Turbine Data Sheets C - SDG&E Rate Tariff D - Prefabricated Concrete Building Product Data E - Preliminary Cost Estimates F - Economic Analysis G - FERC Filing Information H-AB 2466 Information I - CanyonHydro Installation List and Phone Survey LIST OF TABLES Table 1 Pressure Reducing Station Pressures 4 Table 2 Connection 3 Historical Flow Data Statistics 10 Table 3 Allowable Flow and Head Variation for Various Turbine Technologies 11 Table 4 Typical Best Efficiency for Various Turbine Technologies 12 Table 5 Turbine Manufacturers Comparison 15 Table 6 Hydroelectric Turbine Alternatives 26 Table 7 Hydroelectric Turbine Alternative Cost Estimates 32 Table 8 NPV Assumptions 33 Table 9 Results of Economic Analysis 34 Table 10 FERC Consultation Process - Relevant Agencies 36 Table 11 Recommended Alternative 37 LIST OF FIGURES Figure 1 Connection 3 Historical Flow Data 7 Figure 2 Turbine Availability Chart 8 Figure 3 Turbine Annual Electricity Production Versus Flow 9 Figure 4 Turbine Flow and Head Ranges 13 Figure 5 Existing Reservoir Flow Diagram 17 Figure 6 Proposed Reservoir Flow Diagram 19 Figure 7 Hydroelectric Turbine Flow Diagram 20 Figure 8 Hydroelectric Turbine Yard Piping 22 Figure 9 Turbine Building Layout 24 Figure 10 Hydroelectric Turbine Electrical Connection 29 April 2010 pw//Carollo/OocumenIs/Qienl/CA/Carisba(yB362A10/Deliverab!es/Carisbad_TM (RevisedFinal) Carlsbad Municipal Water District PRESSURE CONTROL HYDROELECTRIC FACILITY AT MAERKLE RESERVOIR 1.0 EXECUTIVE SUMMARY The Carlsbad Municipal Water District (CMWD), a subsidiary district ofthe City of Carlsbad gets a portion of its imported water from San Diego County Water Authority's (SDCWA) Tri-Agencies Pipeline Connection No. 3 (TAP3). The pressure in the Tri-Agencies Pipeline is relatively high compared to the pressure needed to fill the 10 million gallon (MG) Maerkle Reservoir and 200 MG Maerkie Dam storage reservoir. Currently, the CMWD sustains the pressure of TAP3 at a constant pressure at 178 pounds per square inch (psig). The pressure is reduced to approximately 20 psig through a multi-stage pressure sustaining/reducing station. The stored energy that is in the high-pressure water is not captured when the pressure is reduced with pressure-sustaining valves (PSVs). The CMWD desires to recover this energy by installing the Pressure Control Hydroelectric Facility (PCHF) in parallel with the multi-stage pressure sustaining/reducing station. The CMWD is considering the installation ofthe PCHF to help it meet two goals: to reduce the amount of electricity that it purchases from San Diego Gas and Electnc (SDG&E), and to reduce its carbon footprint by recovering this valuable renewable energy. The purpose of this report is to estimate the feasibility of installing the PCHF from an engineering and financial standpoint. This technical memorandum will also serve as a preliminary design report to layout the basis of design for a potential PCHF. 1.1 Design Head and Flow The turbine design head and flow were determined to properly size the turbine. The turbine would be installed downstream of the SDCWA TAP 3 connection and downstream of the first pressure sustaining valve in the vault, PSV-MD-1. The hydraulic grade line (HGL) downstream of PSV-MD-1 is maintained at 839 feet. The last PSV in the vault maintains a HGL of 530. This HGL is to allow a high enough hydraulic grade line for the flow to get to the 10 MG Maerkle Reservoir and to the 200 MG Maerkle Dam storage reservoir. Therefore, the available turbine head is 309 feet (839-530). However, 300 feet was used as the design head to account for head loss in the inlet and outlet turbine piping. The possibility of adjusting PSV-MD-1 to a higher pressure should be investigated since a higher set point pressure will allow for a higher head across the PCHF thus allowing for a greater power generation potential. The historical flow rates for 2006 through 2008 were analyzed to determine the ideal turbine capacity. A turbine availability curve was created which indicates the percent of the year that the turbine could operate based on a given turbine capacity. To further determine the April 2010 pw://Carolio/Documer>ts/Client/CA/Carlsbad/8362A10/Deliverables/Carlsbad_TM (RevisedFinal) ideal turbine capacity, a curve was created which calculates the electricity produced per year based on the capacity of the turbine. The ideal flow rate, which would maximize electricity production, is between 6 and 7 cubic feet per second (cfs). 1.2 Turbine Type and Facility There are several hydroelectric turbine types. However, because of the flow and head available for this installation, the reverse pump type turbine is recommended. Currently only one manufacturer offers turbines for the design flow and head that is required for the Maerkle Reservoir. This manufacturer, CanyonHydro, offers complete turbine packages, which utilize Cornell turbines and include electrical panels, generator, and controls. Six CanyonHydro models ranging from 2.2 cfs to 11 cfs were used to develop alternatives for the project. As a result, 16 alternatives were developed which include single turbines and turbines in parallel. Additionally, several flow options and two rate tariffs were utilized in the economic analysis. In addition, an emerging technology from a Nonwegian manufacturer, Zeropex, was reviewed. The technology involves using a reverse pump rotary lobe type configuration. The technology acts essentially as a pressure reducing or sustaining valve. Although unproven, it is recommended to investigate this technology further if the project moves forward. An economic analysis was performed for this potential technology. It is listed as Alternative No. 17. The turbine facility would consist of an 18 ft by 18 ft prefabricated concrete building which would house the turbine along with electrical gear and controls. Piping would lead from upstream of PSV-MD-2 at an existing blind flange to connect to the turbine. The outlet of the turbine would be routed to reconnect with the existing flow downstream of the PSV vault. Flow to the reservoirs and users would remain unchanged. 1.3 Results and Recommendations As a result of the economic analysis. Alternative No. 4 was selected. The results of the economic analysis for Alternative No. 4 are listed below: Flow: 6.75 cfs. Maximum Power produced: 135 kilowatts (kW). Annual Electricity Production: 832,812 killowatt hours (kWhrs). Project Cost: $1,120,000. 20-year Net Present Value: $410,000. NPV Payback Period: 14.7 years. Based on the payback period of 14.7 years and 20-year net present value of $410,000, it is ecommended to move forward with the project; with Alternative No. 4 as the recommended April 2010 pw.//Garo!lo/Documents/ClienfCA/Carlsbad/8362A10/Deliverables/Carlsbad_TM (RevisedFinal) alternative. Additionally, to allow for future flexibility to accept greater flow ranges, it is recommended to allow for the future installation of a smaller turbine in parallel with the 6.75 cfs turbine that would be installed as part of Alternative No. 4. As the project moves forward Alternative 17 should be further investigated as it potentially offers operational flexibility not available by traditional hydro-turbine installation as well as significantly higher electrical energy production and the resulting better NPV. 2.0 BACKGROUND AND INTRODUCTION The Carlsbad Municipal Water District (CMWD), a subsidiary district of the City of Carlsbad gets a portion of its imported water from San Diego County Water Authority's (SDCWA) Tri-Agencies Pipeline Connection No. 3 (TAP3). The pressure in the Tri-Agencies Pipeline is relatively high compared to the pressure needed to fill the 10 million gallon (MG) Maerkle Reservoir and 200 MG Maerkle Dam storage reservoir. Currently, the CMWD sustains the pressure of TAP3 at between 155 psig and 178 psig and then reduces the pressure to approximately 20 psig through a multi-stage pressure sustaining/reducing station. The stored energy that is in the high-pressure water is not captured when the pressure is reduced with pressure-sustaining valves (PSVs). The CMWD desires to recover this energy by installing the Pressure Control Hydroelectric Facility (PCHF) in parallel with the multi- stage pressure sustaining/reducing station. Appendix A shows a site plan of this infrastructure. The CMWD is considering the installation of the PCHF to help it meet two goals: to reduce the amount of electricity that it purchases from San Diego Gas and Electric (SDG&E), and to reduce its carbon footprint by recovering this valuable renewable energy. The purpose of this report is to estimate the feasibility of installing the PCHF from an engineering and financial standpoint. This technical memorandum will also serve as a preliminary design report to layout the basis of design for a potential PCHF. 3.0 TURBINE DESIGN HEAD AND FLOW 3.1 Turbine Head Existing pressure data was gathered by the CMWD staff and by field observations by Carollo Engineers. Table 1 below lists the elevation ofthe piping, pressure gauges, gauge readings, and the HGL. Also listed, is the original HGL from the record drawings, dated 1991 by Luke-Dudek Civil Engineers, Inc. The record drawing HGL's did not match our calculated values based on the pressure gauge readings. The pressure gauge readings were assumed to be correct. The SDCWA TAP 3 flow meter and control valve reduce the hydraulic grade line (HGL) from a higher HGL (record drawings state as 983) to 873 feet. The existing multi-stage pressure sustaining/reducing station reduces the pressure from a HGL of 873 feet to an April 2010 3 pw,/;Carollo/[)ocumenls/Clienl/CA/Car1sbad/B362A10/Deliverables/Carlsbad_TM (RevisedFinal) Table 1 Pressure Reducing Station Pressures Pressure Control Hydroelectric Facility at Maerkle Reservoir Carlsbad Municipal Water District No. Location Description Pipe Elevation (ft) Gauge Elevation*^^ (ft) Gauge Pressure (psig) HGL (ft) Record Drawing HGL (ft) 1 Upstream of TAPS N/A N/A 230*^' N/A 983*^' 2 Upstream of PSV-MD-1 479 480 170 873 930 3 Upstream of PSV-MD-2 479 481 155 839 830 4 Upstream of PSV-MD-3 479 481 89 687 580 5 Downstream of PSV-MD-3 479 480 21.5 530 540 Notes: (1) Estimated. (2) As reported by CMWD staff. (3) Shown on the record drawings as the low end of the current operating range. HGL of 530 feet, via two pressure sustaining valves and one combination pressure reducing and sustaining valve. The first pressure sustaining valve, PSV-MD-1, maintains an upstream HGL of 873 feet to allow the upstream TAP 3 flow meter and control valve to function properly and to provide control capability to SDCWA. To assure that the TAP 3 flow control station will not require any modifications and that SDCWA will maintain flow control capability, the hydroelectric turbine will need to operate in the lower HGL of 839 feet downstream of the PSV-MD-1. The second PSV, PSV-MD-2, maintains this upstream HGL of 339 feet. The last pressure reducing and pressure sustaining valve, PSV-MD-3, maintains a downstream HGL of 530 feet This is to allow a high enough hydraulic grade line for the flow to get to the 10 MG Maerkle Reservoir and to the 200 MG Maerkle Dam storage reservoir. However, the 10 MG Maerkle Reservoir requires the highest HGL, which is set by the maximum water surface elevation in the reservoir, set at 514 feet. Therefore, the total usable turbine head is 309 feet (839-530). A turbine design head of 300 feet was used for sizing the turbine. The additional 9 feet will account for any pipe friction and minor losses in the system. The turbine was sized to operate at slightly higher and lower design heads. Any incrementally higher head will result in more flow and more power produced by the turbine. 3.1.1 Optimizing Available Head There is a potential to gain additional head for the turbine by increasing the PSV setting of PSV-MD-2. This setting is occasionally adjusted by CMWD staff to achieve certain flow rates. However, as noted previously, upon field inspection it was set to approximately 155 psig. During detailed design it is recommended to optimize this setting to allow for the highest pressure without compromising the functionality of the pressure sustaining/ reduction station. However, if the setting on PSV-MD-2 were increased by 10 pounds per April 2010 pw://Carollo/[)ocumenls/Client/CAyCarlsbad/8362A10/DelivefabIes/Carlsbad_TM (RevisedFinal) square inch (psi) to a total of 165 psig (HGL = 930 feet), this would allow for 23.1 additional feet of turbine head and would result in 11 kW of additional power production from the turbine at 6.75 cfs of flow. 3.1.2 Energistics Report A study and subsequent report entitled Carlsbad Connection 3 Hydroelectric Feasibility Study was performed by Energistics, Inc. (Energistics) and dated February 25, 2009. The Energistics report's objective was to determine if there was a potential for installing hydroelectric facilities in CMWD's distribution system and was meant as a screening report. It is likely that Energistics did not have the detailed information about flows, pressure and flow control strategies available for review during preparation of the report. The Energistics' report executive summary lists the maximum power from the turbines as 350 kW. Using actual available equipment the highest power production without changing the existing flow control strategy is 203 kW. The Energistics report lists a potential annual electricity production of 2,024,565 kWhrs while using actual available equipment this is approximately 1,000,000 kWhrs. To explain the apparent discrepancies between this report and the Energistics report it is important to note the following: • Power production: The Energistics report executive summary lists the overall power that can be recovered as 350 kW. However, the maximum as stated in Appendix E of the Energistics report is 90 kW, 52 kW and 107 kW for locations 3, 3A and 3B for a total of 249 kW. Therefore, it appears that the executive summary's power listing is a typographical error. • Available pressure: The Energistics report assumes that the pressure in the SDCWA Aqueduct is available for capture by a hydroelectric turbine. This is referred to as Location No. 3. However, this report assumes that this was not available due to the fact that CMWD does not own the TAP3 connection that would have to be bypassed to capture this pressure. Additionally, in discussions with CMWD staff it was learned that SDCWA requires pressure downstream of TAP 3 of 170 psig for the TAP3 flow control valve to function properly. Therefore, this report does not assume that the pressure from 170 psig to 155 psig is available for capture as was assumed by the Energistics report (Location 3B). Also, the Energistics report assumes that the downstream pressure from PSV-MD-3 is 15 psig (Location 3B). Based on field pressure gauge readings, this pressure is 21.5 psig. Ail total, these pressure discrepancies amount to a total of 66.5 psig or 154 feet of turbine head is not available for capture. • Design flows: The Energistics report assumed that the turbine could pass varying flow rates to match daily changes in flow. However, due to the reverse pump type turbine technology that would be used for this project, this would not be possible. Actual historical flows where used to determine a turbine availability percentage. This led to April 2010 pw://Carollo/Documents/Client/CA/Carlsbad/8362A10/Delivefables;Carlsbad_TM (RevisedFinal) a reduction of turbine operating hours in Carollo's report as compared to the Energistics report. The Energistics report assumed a lower flow rate of 4 cfs for location 3B while this report assumed that there would be one constant daily flow rate. 3.2 Desalination Feed Construction will begin shortly on a 50 million gallons per day (mgd) desalination plant near the Encina power plant located in Carlsbad. This desalination plant will feed water to the Maerkle Reservoir through a proposed pipeline. It will not tie into the existing piping upstream of PSV-MD-1. The desalination feed will meet the existing HGL in TAP 3 and so will not lower the available pressure. Therefore, since the proposed turbine will be downstream of PSV-MD-1, the desalination feed will not affect the design or operation of a potential hydroelectric facility. 3.3 Turbine Flow Figure 1 presents historical average daily flow rates from 2006 to 2008 were analyzed to determine the ideal turbine flow rate. The average daily flow rate varies significantly from day to day. Data from January 2008 to May 2008 was excluded because during this period, the reservoir was out of service due to repairs and upgrades performed under the Maerkle Reservoir Floating Cover Inspection, Cleaning, Repair, and Rainwater System Upgrade, Project No. 5005. Figure 1 shows that from January 2006 to January 2008, excluding the repairs and upgrades period, the predominant supply flow ranged between 6 cfs to 10 cfs. Figure 2 presents the percent of time a given flow rate was available for power generation. The turbine can operate and produce power when the reservoir flow rate is greater than or equal to the capacity of the turbine. For flows greater than the turbine capacity, the extra flow can simply bypass the turbine through the PSV station. As an example, a turbine with a capacity of 10 cfs would only be available to produce power for less than 10 percent of the year while a turbine with a capacity of 8 cfs would be available to produce power for 60 percent of the year. To maximize the amount of power available from the historical average daily flows, an analysis was performed to see how turbine capacity selection related to electricity production. Electricity production is a function ofthe percent available, turbine efficiency, flow and head. Therefore, the flow rate which has the maximum annual electricity production would be the ideal turbine design capacity. However, this would only account for the maximum annual electricity produced and would not take into account capital cost and net present value analysis. Figure 3 shows the percent availability and also the annual electricity produced. From this figure, the optimum flow rate is between 6 and 7 cfs. Additionally, it should be noted that this analysis assumes that future flows will be equal to the previous three years and that there is very little variation in flows from one year to another. The average flow and standard deviation for the previous three years is shown in April 2010 6 pw.//Carollo/Docunients/Client/CA/Carlsbad/8362A10/Deliverables;Caflsbad_TM (RevisedFinal) O • • 1 1 • * • 00 o I u o 00 o c 3 (sp) 5M0|d £ UO|P3UU03 SIS 111 X ™ g O 0) 2 I c o o £ 01 (/) 0) o o CO o o o o o o d o o to I u. c .3 CO o o § c o O 0) l_ 3 (A tA (U Table 2. Table 2 shows a relative stability in flow rates over the last three years. The PSV station and piping was originally built to accommodate a future maximum flow of 20 cfs. Therefore, sizing the turbine based on previous flow rates seems reasonable. Table 2 Connection 3 Historical Flow Data Statistics Pressure Control Hydroelectric Facility at Maerkle Reservoir Carlsbad Municipal Water District Year Units Average Daily Flow Standard Deviation 2006 cfs 7.84 2.3 2007 cfs 7.83 2.7 2008 cfs 7.74 2.6 Currently, CMWD can change the flow rate to the reservoirs three times per day: 8:00 am, 2:00 pm and 8:00 pm. The previous analysis is based on average daily flow rates. It assumes that the flow rate would be constant over the entire day. 4.0 HYDROELECTRIC TURBINE 4.1 Turbine Technology Background Depending on the flow rate and the head available for energy recovery, there are four established types of hydroelectric turbines available: • Pelton. • Francis. • Reverse Pump. • Kaplan (axial). Each of these turbine types utilizes either pressure or velocity to generate energy. The Pelton turbines utilize velocity to generate power while the Francis and Reverse Pump turbines utilize pressure to generate electric power and are intended for medium/high head applications. Kaplan turbines utilize pressure to generate power and are intended for tow head applications. Pelton turbines must discharge to open chambers thus they are not typically suitable for in~conduit applications. Although the ranges of available head does limit which energy recovery technologies that could be considered there is some overtap in capabilities. In addition to design flow and design head, the selection of the right turbine should also consider flow range, head range, rotational speed (runaway speed), efficiency, cavitation April 2010 10 pw.//Cafoilo/DocLimenl5/Client/CA/Carl3bad^8362A10/Delrverables/Carlsbad_TM (RevisedFinal) (downstream head conditions) and cost. Table 3 shows the ability for each of the technologies listed above to accept a range of flow and head. Table 3 Allowable Flow and Head Variation for Various Turbine Technologies Pressure Control Hydroelectric Facility at Maerkle Reservoir Carlsbad Municipal Water District Turbine Type Acceptance of Flow Variation Acceptance of Head Variation^^' Pelton High Low Francis Medium Low Reverse Pump Low Low Kaplan (double regulated) High High Kaplan (single regulated) High Medium Note: (1) High indicates that the turbine can operate over a wide range of flows. Low indicates the turbine cannot operate over a wide range of flows. Runaway speed is defined as the speed that the turbine will attain if load rejection occurred. Load rejection is simply the loss of torque on the turbine shaft from the generator. Load rejection could be caused by a power outage in the grid feeding the facility. Therefore, runaway speed represents the speed that the turbine would attain if power were lost to the turbine and before the inlet valve closes. With no electrical load on the turbine from the generator, the turbine would increase in speed until it reached its runaway speed. There is a runaway speed curve for each turbine model. The flow rate through the turbine decreases during runaway conditions due to the centrifugal forces ofthe runner. Although runaway speed is used to design the turbine correctly, runaway would have little or no affect on the Maerkle Reservoir system. If power is tost to the grid, the turbine will not be able to put electricity on to the grid or locally. When this loss of grid power occurs, the turbine will momentarily increase speed towards a maximum speed referred to as runaway speed. As soon as power is lost, the inlet valve will begin to close by spring or weight. This is not instantaneous to prevent water hammer. It is during this closure period (approximately 30 seconds) that the turbine will reach runaway speed. Once the inlet valve is closed, the turbine slows down and stops. The flow that continues through the turbine during the inlet valve closure period will be absorbed by the reservoir. Therefore, there are no further impacts to the surrounding reservoir system. When load rejection occurs, there is a sudden reduction in flow rate. This can cause a surge in the piping system if this is not designed for. Flow Science will be performing an analysis on the proposed hydroelectric system during detailed design to determine the severity of the surge effects. Their analysis could result in the addition of pressure relief valves to protect the piping system from damage. April 2010 pw://Carollo/DMuments/ClienI/CWCarisbad/8362A10/Delivefables/Carlsbad_TM (RevisedFinal) 11 The Zeropex unit will reach ainaway speed during a load rejection. However, it will increase flow to up to two times the flow rate before load rejection rather than decrease in flow. If load rejection were to occur, a signal would be sent to the inlet valve (not supplied by Zeropex) which would slowly begin to shut base'd on spring or hydraulic closure. The closing speed will be addressed during detailed design by Carollo and by Flow Science in their analysis of potential surge. It is estimated that the valve would close in approximately 30 seconds. During the time it would take the valve to close, flow would pass through the Zeropex unit to the reservoir. If the Zeropex unit were accepting a maximum flow of 10 cfs, during runaway (and while the inlet valve was closing) it could pass 20 cfs. This equates to a volume of 4,488 gallons. As the valve is closing, the pressure in the upstream piping would begin to increase. As the pressure increases, the PSVs will open to maintain the upstream pressure. Flow will go through the existing PSV facility as it currently does. In many ways, the efficiency of a turbine is similar to the centrifugal pumps that the water industry (and the CMWD) operates and maintains on a daily basis. Operating a turbine at its best efficiency point minimizes vibration and results in longer bearing life. Simiiarty, the efficiency of a turbine decreases as you move away from the best efficiency point. The best efficiency of each turbine type ranges from 85 to 94 percent with the impulse type turbines (Pelton) and reverse pumps having lower efficiencies. Table 4 shows the typical best efficiency of each type of turbine. The best efficiency represents the maximum best efficiency point for this type of turbine and does not mean that every turbine model in this turbine category will operate at this efficiency. Additionally, the efficiency will decrease as the operating point moves away from the best efficiency point. Table 4 is meant to show the general differences in efficiency in the various turbine types. Figure 4 shows the range of flow and head that applies to each turbine technology. Table 4 Typical Best Efficiency for Various Turbine Technologies Pressure Control Hydroelectric Facility at Maerkle Reservoir Carlsbad Municipal Water District Turbine Type Best Efficiency Pelton Francis Reverse Pumps Kaplan 89% 94% 85% 91% 4.2 Recommended Turbine Type Based on the design flow and head conditions, a reverse pump type hydroelectric turbine is recommended because of its lower cost, small footprint, and ease of operation. Figure 4 shows that the only other possibilities would be the Francis turbine or the Pelton. However, the Pelton is not viable because it requires atmospheric pressure on the downstream side. The Francis turbine would be cost prohibitive at flow rates below 20 cfs. Below 7 cfs. April 2010 pw://CaroHo/[)ocumenls/Client/CA/Carlsbad/8362A10/Del!verables/Carlsbad_TM (RevisedFinal) 12 ^(JA/SJMAA>I) uoipnpojd A)i3M)39l3 lenuuv o o o cT o CN o 8 o o o o o o OO o o o o o (0 o o o o' o o o o o' o CNi Turbine Percent Available •Annual Electricity Production — , 1 1 1 1 1 Turbine Percent Available •Annual Electricity Production — Turbine Percent Available •Annual Electricity Production — // Turbine Percent Available •Annual Electricity Production — 7 Turbine Percent Available •Annual Electricity Production — / 1 \ \ • o o o o o in o o o o CO o o CN o o o o d ^ u o o o o 00 o o o o (d o o id o o CO CN o o u n a 5 c !S .3 O 0) o 00 o o CD o m o o CO o CN 8|qe||eAV luaojad eujqjni in c w 3 i CO 2 ^ .c O CL §?8 « o c cn 3 C il OC •o ra « X •o c ra i <A Q CD 2 5 c 1 > ra c u- = „ 2 X c o o £ 3 to s> Q. Francis turbines are not available. The reverse pump, as its name implies, is very similar to a traditional centrifugal pump. However, instead of an impeller to generate head and flow there is a runner, which captures this energy and turns it into torque. The runner is shaped differently than an impeller to capture the hydraulic energy rather than produce it. The runner shape is the same for both the reverse pump and the Francis turbine. However, the inlet guide vanes on the Francis turbine, which allow it to produce variations in flow, make it significantiy higher in cost than the reverse pump turbine. The generator for the typical reverse pump turbine installation is a standard induction motor operating above its synchronous speed. The reverse pump requires a hydraulic or motorized butterfly valve on the inlet to the turbine. This valve is necessary to shut down flow to and through the turbine in case of load rejection, low flow, or low or high head condition. The turbine control panel monitors the voltage and amperage produced by the turbine as well as the speed of the turbine. It will then close this inlet valve on loss of grid power, over current, over/under voltage, over/under frequency and over/under turbine speed. There are three known manufacturers for this technology; CanyonHydro, KSB and Flowserve. Only CanyonHydro was able to size units for this project's potential flow and head conditions. CanyonHydro uses a Cornell turbine in its package. The flow rates were too low for Flowserve and KSB's turbine models. Turbine models were selected with capacities ranging from 2.2 cfs to 11 cfs based on actual available units. Table 5 compares the selected turbine models. These models and combination of models were then utilized to create a list of alternatives for the economic analysis. The Cornell turbine uses an end-suction pump casing. There are several sizes available with a turbine head of approximately 300 feet. A cut sheet of this reverse pump type turbine along with performance curves are shown in Appendix B. The point where the total turbine head of 300 feet and the turbine curve intersect represents the operating point and the corresponding flow. Power can then be determined from the power curve. Runaway speed can be read from the runaway speed curve for the design turbine head of 300 ft. 4.2.1 Reverse Pump Turbine Operation and Maintenance The operation and maintenance associated with a reverse pump turbine is very similar to that of a pump. Mainly, the turbine and generator require bearing and seal service at regular intervals. The turbines may require realignment after several years of service. A survey of existing turbine owners was conducted to verify actual turbine maintenance requirements for similar installations. Three turbine owners were contacted. Only one had a maintenance contract and it was with a local consultant; they plan to do their own maintenance after the first year of operation. The other two owners perform service with in-house staff as these systems are very similar to pumping systems currently maintained by their staff. During detailed design, maintenance contract companies will be contacted. Maintenance training will be provided by the turbine manufacturer. April 2010 14 pw://Carollo;Documenls/Client/CA/Carlsbad/8362A10/DelwerabtesyCarlsbad_TM (RevisedFinal) o tn 0) 0) 0) m m I* 0 to ^ tA UL U 1 O (0 ._ *-Q-i; « E O Q oi! oS (ft u 3 X CO O o -^ ra 2: o c C O 3 « O S ^ 0) "O OT ,A 3 S. re I- Q. O = 1 .Q <1) lO 3 "3 •EE ^ 0) m • T3 o 3 H .EE 3 "3 3 o o z "oi CO T3 O .EE <D CN 3 "3 3 o gz (A C 3 O X cu O t_ Q) N 00 OO ro ^ Too 00:-" Q CO CO O O <D CO c -o .0 CO o o CO III I S -I 9 c 73 o ^. UJ ^ ro to c — -I—• O o o CD O ^ 0 <^ CO 10 Xi .9 CO o CO O O Q) 9- CO I- -o .2 UJ ^ CO CO (D a? 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CU ro CJ -1—' ro sz +-* 0) o CL Q) O C C CU oi" cu c "2 ii -pi OJ w £ CD "O »-u ^ c ro 0)1 o o- o "O cu Oi ra "O T3 (D E CO CQ cn CO UJ og CO April 2010 pw://CaroIlo/Documents/Client/CA/Carlsbad/8362A10/Oeliverables/Carlsbad_TM{RevtsedRnal) 15 4.2.2 Installation List and Phone Survey A phone survey was conducted to determine the maintenance required, operation and to determine any issues with the installation, if any, of similar turbine installations. Three turbine owners were contacted and the results from this survey were positive. The general consensus was that the turbines operation is very simple and reliable and that there is minimal maintenance required. Detailed descriptions of the phone survey are contained in Appendix I. 4.3 Emerging Hydroelectric Turbine Technology An additional manufacturer, Zeropex, was also contacted. Zeropex is a Norvi'egian company. The Zeropex turbine is unique because it utilizes a positive displacement, rotary lobe type reverse pump. Additionally, it can act as a pressure-sustaining valve to maintain a set pressure up or downstream. It can also act as a flow control device to maintain a desired flow. The unit is able to modulate its speed utilizing VFD controls to maintain pressure or flow. The unit has the ability to accept varying flow rates in contrast to other turbines which typically pass a set amount of flow. The unit functions similar to the existing pressure sustaining valves. As a result this technology has the ability to replace upstream PSV-MD-1 since it can maintain a constant upstream pressure. This would allow the capture of 34 feet of additional turbine head. The technology, although promising, is very new and emerging. There are no installations in the United States and a limited amount in Europe. However, a U.S. installation is scheduled for startup in late Spring 2010. A preliminary proposal and product information for the Zeropex turbine is located in Appendix B. An additional benefit of this technology include offering simplified interconnection requirements to connect to the local utility. This technology utilizes an inverter to convert the power to AC power. This effectively decouples the generator from the utility. As a result the equipment can be pre-approved by the utility significantly reducing the costs and time associated with obtaining an interconnection agreement. Due to the lack of experience, the turbine was not considered as a recommended alternative at this point. However, an economic analysis was performed and is listed as Alternative No. 17 as a comparison. It is recommended, should the project move forward, to further consider this technology. 5.0 FLOW CONTROL 5.1 Existing Reservoir Flow Control A partial existing flow schematic of the Maerkle Reservoir is shown in Figure 5. In the normal configuration, SDCWA's TAP 3 controls the flow rate to the amount requested by CMWD. Currently CMWD can request a flow rate change three times per day: 8:00 am, 2:00 pm, and 8:00 pm. The control valve at TAP 3 then modulates to obtain the requested April 2010 16 pw://Carollo/Documenls/Client/CA;Carlsbad/8362A10/[)eiivetables/Carisbad_TM (RevisedFtnal) From Chlorine Dioxide Eductor To Chlorine Dioxide Eductor To Onsite Irrigation To House 2 Hi III « D To Reservoir Washdown c 8 2 W 9) flow rate. Downstream of TAP 3 the pressure is then reduced at the PSV station (shown enclosed with dashed lines), which contains two PSVs, and one combination PRV/PSV. After the first PSV, PSV-MD-1, a portion of the flow {typically up to 1,350 gpm or 3 cfs) is diverted to provide high-pressure water for the chlorine dioxide eductor, carrier water for chlorine dioxide, washdown water for the Maerkle Dam storage reservoir cover, onsite irrigation and potable water to the reservoir keeper's adjacent house. The chlorine dioxide is added to the Maerkle Dam storage reservoir. The carrier water also acts to turnover the Maerkle Dam storage reservoir. Another 4-inch tap downstream of PSV-MD-1 provides Maerkle Reservoir washdown water, fire hydrant water and for irrigating an adjacent farm. The carrier water pressure is required only to be high enough to get the flow into the Maerkle Dam storage reservoir. However, the onsite irrigation, house, 6-inch reservoir washdown and chlorine dioxide eductor, alt need a higher pressure. The carrier water is monitored by a magnetic flow meter and manually controlled via a 12-inch butterfly valve. The pressure is reduced through PSVs and the manual control valve and flows to the 200 MG Maerkle Dam storage reservoir. The manual control valve is opened (or closed) until the flow meter displays the desired flow. Once the correct flow rate is displayed, the valve does not have to be adjusted again. Any additional flow, which does not go to Maerkle Dam storage reservoir, flows through the two remaining PSVs in the PSV station (vault) and goes to the 10 MG Maerkle Reservoir. This is the normal flow configuration; however, CMWD has several other flow scenarios, which it utilizes depending on the season, day, or emergency situations. Some of these scenarios involve flow bypassing the Maerkle Reservoir and flowing directly to the Maerkle Dam storage reservoir. 5.2 Proposed Flow Control with Turbine Piping, valves, and connections would be set up to maintain not only the normal flow configuration but also all other flow configurations. Figures 6 and 7 show schematics of the proposed configuration. Under this configuration, flow would enter the PSV station (vault) as it currently does. However, after the first PSV, PSV-MD-1, the rated flow of the turbine would bypass the remaining two PSVs and flow through the turbine, creating power. After the flow discharges through the turbine it would connect into both the 42-inch MD line and the 10-inch HE line. The pressure in the 10-inch HE line would be less than it is now. This reduced pressure may require that the existing manual flow control valve be replaced with an automatic flow control valve of a smaller size. The new automatic flow control valve would have a flow controller which would modulate the valve based on the flow meter signal until the desired flow was reached. During detailed design it would need to be verified that there was enough upstream pressure to adequately control fiow. However, this does not seem to be a problem as the upstream pressure at the fiow control valve will be approximately 29 feet of head not including headless. April 2010 18 pw://t::arollo/Documents/aient/CA/Carlsbad/8362A10yDeliverables/Carlsbad_TM (RevisedFinal) o •o c g CC O) 1 a> c O TD C (0 (U w =3 o X % iS 0 "O 'x o a cu 11 O CO f f o z o z> Q UJ From Chlorine Dioxide Eductor I <n OO 2^ .12 -151X3 (U > > 15 CO > > -o c a> 0) to Q. O O t5 = = CO CO II II O O z z CO Q. D) § ^ •g ^ (0 .9-o) Q- D) Q. O (A ^ (/> X <D X 0) C 0) I I I 2 c o O 0) L. 3 U> (A 0) H O Z (O f o Ul UJ > o cc Ul E U • Ul UJ O E S Q. ill i ^1 _i I z I D S Feed water for the two water users, reservoir washdown and the chlorine dioxide eductor, however, would no longer be provided from the 10-inch HE line, since it wilt now be at a lower pressure. Instead, a new 6-inch line would be routed from the PRV station to provide water for these users. The exact location of the tap would be determined during detailed design. Additional flow, above 1,350 gpm, would flow from the turbine discharge to the 42-inch MD line and continue to the 10 MG Maerkle Reservoir as it does currenfly, through the PSV station. When the turbine is out of service or when Tap 3 fiows are below the capacity of the turbine, all fiow would then fiow through the existing PSV station (vault) and through PSV-MD-1, as it currently does. From there, the high-pressure users would branch off. After the last PSV, PSV-MD-3, the 1,350 gpm of carrier water would split off and transfer to the 10-inch HE line. All other fiow continues to the 10 MG Maerkle Reservoir. During conditions when the Tap 3 fiow rate is higher than the turbine rated flow, the pressure upstream of the turbine will rise, causing the two PSVs in the existing PRV station (vault) to open and allow this addifional flow to bypass the turbine. During conditions when the Tap 3 fiow rate is lower than the turbine rated flow, the pressure upstream of the turbine will decrease. This will cause the turbine to move back on its flow-head curve. As the power produced continues to lower, the speed will slow down slightly. This will trigger the turbine to shut down. As the turbine moves back on its flow- head curve, it would be operating at lower and lower efficiencies. This would in turn lead to more wear on the turbine (similar to a pump). To prevent this, the flow signal from the SDCWA's flow meter could be monitored through CMWD's SCADA system. When the fiow rate from SDCWA becomes lower than the turbine capacity, a signal could shut down the turbine. Flow would then bypass the turbine and go through the exisfing PSV stafion as it currently does. All other fiow control configurations will be possible with the new hydroelectric facility installed. Figure 8 shows the potential yard piping configuration based on the previously discussed flow configuration. 5.2.1 Optional Flow Control Option An optional low flow control strategy could be adopted to maximize the turbine availability and thus the amount of electricity produced. During periods when the requested reservoir daily fiow rate was below that of the turbine capacity or when electrical buyback rates were highest, the fiow rate could be set at a higher rate. The fiow and turbine would be cycled on and off to reach the desired average daily fiow. For example, if a daily average fiow rate of 2.7 cfs was desired and the turbine was rated for 5.4 cfs, water could be supplied for 12 hours at 5.4 cfs. This would average out to the desired 2.7 cfs average daily fiow rate. Alternatives for the economic analysis were developed which utilize this low fiow control option to demonstrate its potential effect. April 2010 21 pw//Carotlo/Docu[i(ents/Client/CA/Carlsba(l/8362A1CV[)eliverables/Carlsbad_TM (RevisedFinal) CO CT.fc t5 « 0) ra X o O 0) (A 0) O Lf) C/3 OJ "5 E e a. < 6.0 HYDROELECTRIC TURBINE BUILDING The turbine and associated electrical equipment would need to be housed in a building to protect it, prevent corrosion, allow for maintenance in a controlled environment, reduce noise, and provide for a longer lasting facility. The existing pressure sustaining station vault has parallel piping, which could be used to install the turbine. However, installing the turbine inside the exisfing vault has several disadvantages: • The vault is only accessible through a ladder. This would not be ideal for maintenance work. • There is limited space available in the exisfing vault; therefore, there may not be adequate space for maintenance access. • The parallel line was constructed to allow for installation of additional PSVs in the future. This would allow CMWD to allow more flow into the reservoirs. Installing the turbine here would limit the amount of flow when the turbine is out of service. • An electrical building would still be required. • There is a potential for flooding in the vault. Installing the turbine in the existing vault was not considered further because of these disadvantages. 6.1 New Building Location Construcfing a new building for the hydroelectric turbine would allow for adequate space around the turbine and would allow for the existing PSV station to accept addifional flow in the future. The recommended location for a new building would be across the road from the existing PSV station (vault) as shown on Figure 7. This allows for simple connections to the exisfing piping. 6.2 Building Size and Type In order to minimize costs, a prefabricated concrete building could be installed. A cutsheet of this prefabricated concrete building is contained in Appendix D. The prefabricated concrete building would need access door(s), lighting, electrical and HVAC. Figure 9 shows a possible configuration of the proposed building, piping, hydroelectric turbine and electrical equipment. The building would require approximately 18 feet by 18 feet footprint. A split level concrete slab base would be provided on which the building could be attached. The walls of the prefabricated concrete building would typically be 4-inches thick. The base concrete base slab would have 8-inch thick walls on which the building would be supported. The building would be attached to the slab walls with angle brackets and anchor bolts. April 2010 23 pw://Cardlo/Doci!ments;Client/CA/Carlsbad/8362A10/Deliverables/Car!sbad_TM (RevisedFinal) Ul • 9 ii Ul 3 a. One end of the angle bracket is cast into the precast wall and the other end is anchored to the slab with anchor bolts. The slab would have two elevations to facilitate installation in the proposed location. A standard size door would allow access into the upper level where the electrical equipment would be located. Stairs would allow access to the lower elevation. The lower elevation would be approximately 3 feet below the upper section. The turbine would be located in this area. In this way, the electrical gear would be protected from any potential drainage water from the turbine or during maintenance. An emergency drain would be provided in the lower area to prevent any potential flooding of the electrical gear. A 10-foot wide rollup door would be provided to access and remove the turbine or electrical gear because of spatial requirements of the opening. 6.3 Noise Noise is an issue for this installation because of the close proximity of the Ocean Hills Country Club residential development and the reservoir caretaker's house. The building will help to reduce the amount of noise from the turbine. Acoustical louvers could be installed to limit the noise, which escapes through the ventilation system. Acousfical sound attenuation panels would be installed on the inside walls of the building to lessen the intensity ofthe sound. The noise from the turbine generator has been reported by turbine owners as being less than or equal to the noise of a similar sized pump. 6.4 Ventilation Ventilation would need to be provided, as both the electrical equipment and the generator would produce heat. A wall or roof exhaust fan would be installed to provide this venfilafion. Louvers would allow supply air into the building. 7.0 ALTERNATIVES The six turbine models selected previously were used to create 16 alternatives. The hydroelectric turbine alternatives to be used in the economic analysis are shown in Table 6. For each alternative the turbine quantity, fiow rate, and size are listed. These alternatives were selected based on available turbine models except for the 10 and 12 cfs alternatives. These are not based on actual turbine models, however were included to show how larger capacity turbines would affect the economics of the project. The Zeropex turbine is also listed as Alternative No. 17. However, at this point it is not considered a recommended alternative as described previously. April 2010 25 pw;//Cardlo/[)()cijments/Clienl/CA/Carisbad/8362A10/[)eliverabl6s/Carlsbad_TM (RevisedFinal) Table 6 Hydroelectric Turbine Alternatives Pressure Control Hydroelectric Facility at Maerkle Reservoir Carisbad Municipal Water Distnct Alt. No. Turbine 1 Turbine 2 Flow Flow Total Max Power (kW) Flow Rate Strategy 1 5.4 100 Utilizes exisfing flow strategy. 2 2.2 36 Utilizes existing flow strategy. 3 3.6 68 Utilizes existing fiow strategy. 4 6.75 135 Utilizes existing flow strategy. 5 7.75 157 Utilizes existing flow strategy. 6 3.6 136 Utilizes existing fiow strategy. 7 5.4 3.6 168 Utilizes existing fiow strategy. 8 6.75 3.6 203 Utilizes existing flow strategy. 9 7.75 2.2 196 Utilizes existing flow strategy. 10 7.75 157 Utilizes optional flow control strategy'^'. 11 3.6 3.6 136 Ufilizes optional flow control strategy*^'. 12 11 223 Utilizes optional flow control strategy'^*. 13 6.75 3.6 203 Utilizes optional flow control strategy'^'. 14 7.75 2.2 196 Utilizes optional flow control strategy'^'. 15 10 203 Utilizes opfiona! flow control strategy*^'. Not an actual turbine size. 16 12 243 Utilizes optional flow control strategy'^^ Not an actual turbine size. 17 0-10 213 Utilizes existing flow strategy and Zeropex unit to parallel PSVs. Note: (1) See section 5.2.1 for discussion of optional fiow control strategy. April 2010 pw//(;arollo/Documents'Client/CA/Carlsbad/8362A10/Deliverables/Carlsbad_TM (RevisedFinal) 26 8.0 ELECTRICAL AND INSTRUMENTATION CONSIDERATIONS 8.1 Generatorand Electrical Equipment In order to generate power and apply it onto the main electrical grid or to use on site, specific electrical equipment would be required. A generator would convert the mechanical energy of the turbine into electricity. The turbine manufacturer would typically provide the generator. There are two types of generators that can be used: synchronous and induction type. Synchronous generators can operate when not connected tothe main electrical grid. Inducfion generators draw their reactive power from the grid. Induction generators are essentially a squirrel cage motor with the rotor operating af speeds higher than the magnetic field (synchronous speed). Unlike the synchronous generators, they cannot run when they are disconnected from the grid. They are cheaper and typically used when they are an insignificant part of the overall system load. An induction generator is recommended for this installation. Additionally, electrical utilities prefer that the use an induction type generator for safety reasons. An inductor generator cannot feed power to the grid during loss of power. Therefore, when working on electrical lines during a power outage, SDG&E would not have to worry about disconnecting the turbine first. Switchgear, controls, breaker, local disconnects, and emergency stop station would be required, in addition to the generator. These items are typically supplied by the turbine supplier in one main control panel as a part of the turbine package. A quote for the turbine, which lists the equipment provided in the package, is shown in Appendix B. 8.2 Controls To start the turbine manually, the TURBINE AVAILABLE light must be displayed. The control panel will display this light if several conditions are met to determine if the turbine can operate. These conditions include the correct current, voltage, and frequency from the grid. A pressure differential transmitter would be installed to measure the turbine head available. This signal along with a signal from the Tap 3 flow meter would be sent through SCADA. The control system would then be setup to determine if first, the fiowrate was higher than the turbine flow rate and second, that the turbine differential head was adequate for operating the turbine. If both of these conditions were true, a TURBINE AVAILABLE signal is displayed locally and remotely through SCADA. The operator must then press the TURBINE ON button to start the turbine. When this occurs, the inlet valve starts to open. This generally takes about 30 seconds. As the valve is opening, the turbine is exposed to a greater pressure and fiow. It then begins to rotate. When the turbine speed approaches and then exceeds the synchronous speed of the generator, the turbine switchgear closes and the generator is connected to the grid. At this point electricity is generated and applied to the grid or used locally. April 2010 27 pw:/^Caroltart)ocumenls/Client/CA/Carlsbad/8362A10/Deliverables/CarlsbaOM (RevisedFinat) The turbine can operate automatically. Once the turbine is set to auto, it waits for the TURBINE AVAILABLE signal. Once this is displayed, the turi^ine starts as described previously. If the turbine shuts down for any reason, it will try to restart itself after an adjustable fime delay and once the TURBINE AVAILABLE signal is displayed. The turbine control panel monitors the speed of the turbine and will shut down on a high speed. Additionally, voltage, amperage, and frequency are monitored. The turbine will shut down on high/low voltage, amperage, or frequency. The control panel shuts down the turbine by disconnecting the generator from the grid and closing the inlet valve. A remote signal would be sent that would let operations know that the turbine had failed immediately through SCADA. If power is lost to the grid, the turbine will not be able to put electricity on to the grid or locally. When this loss of grid power occurs, the turbine will momentarily increase speed towards a maximum speed referred to as runaway speed. As soon as power is lost, the inlet valve will begin to close by spring or weight. This is not instantaneous to prevent water hammer. It is during this closure period that the turbine will reach runaway speed. Once the inlet valve is closed, the turbine slows down and stops. There are no further impacts to the surrounding system. If additional flow is requested, which is more than the turbine is passing; the pressure upstream ofthe turbine will begin to increase. As it increases, the exisfing PSV valves inside the exisfing vault will modulate to lower the upstream pressure, as they currenfly do. This will allow the addifional flow to pass through the PSV vault line. Sudden pressure increases would cause the turbine to increase amperage, thus activating a high amperage condition and shutting down the turbine. 8.3 Interconnection Standards The State of California has adopted a standard set of interconnection, operating, and metering requirements for distributed energy resources entitled Rule 21. This dictates how the power can be applied to SDG&E's electrical grid. The electrical intercx)nnect for this project would need to satisfy the requirements of Rule 21. SDG&E also requires that the plans be submitted to them for review along with a review fee of $800. Depending on the comments from the review, an additional review may be required. This also requires an additional $600 review fee. 8.4 Interconnection Details The hydroelectric turbine system would be connected into the existing power system as shown in Figure 10. The hydroelectric generator vyould be connected to a 480-volt, 3-phase distribution panelboard (DP-PCHF) located in the PCHF Turbine Building. In addition to the hydroelectric generator, DP-PCHF would also provide a connection fo a 208/120-volt panelboard for lighting, receptacles, and any HVAC loads in the PCHF Turbine Building. April 2010 28 pw//Carollo/[)ocuinents/Client/CA/Carlsba<l/8362A10/Delivefables/Cartsbad_TM (RevisedFinal) z t P (3 < is Power generated by the PCHF would be transmitted to the existing Maerkle Pump Station through an underground connection between DP-PCHF, located in the PCHF Turbine Building, and a new circuit breaker installed in the existing 480-volt motor control center at the pump station. The underground connection would consist of two parallel runs of 480-volt conductors sized to minimize voltage drop and losses between the interconnection point and the PCHF. To minimize construction cost, it is anticipated that the conductors will be installed in Schedule 40 PVC conduit in a sand-bedded duct bank. The exisfing conduits along this same route are too small to use for this service. Additionally, a communications connection between the exisfing Maerkle Pump Stafion SCADA system and the PCHF would be provided. This would consist of cable installed in the same underground duct bank containing the power conductors, and could be used to remotely monitor the PCHF. Turbine available, run and fail status would typically be monitored remotely. In addition to the new circuit breaker installed in the existing motor control center, the existing utility metering equipment at the Maerkle Pump Station may need to be replaced; coordination with SDG&E during final design will be required to determine the extent ofthe metering equipment modifications. In discussions with SDG&E staff, the only utility provided equipment would be the electrical meter at a cost of approximately $1,000. 8.5 Customer Generator Rate Options SDG&E offers several options for either using the power, selling this generated power, or a combination of both. Chris Brown with SDG&E was contacted to discuss the various rate options available to CMWD. Once the type of technology, location, and CMWD's organization type (local government) was reviewed, there were only two options available to CMWD with only one currenfly being available. The applicable tariffs along with a brief description of each is presented below. 8.5.1 Schedule Water Tariff SDG&E ofi'ers a specific tariff for water and wastewater agencies to allow them to sell power back to the grid from renewable energy sources. This tariff is referred to as SCH-WATER. Under this tariff, the renewable power generated can be used on site with the excess sold back to SDG&E at predetermined rates. These rates are established annually and are referred to as the Market Price Referent (MPR). The rates for projects starting in the year 2011 would be $0.08843/kWhr for a 10-year contract. The price is adjusted for time of day and year based on the Time of Day (TOD) factors. However, for a constantly operating generator such as this hydroelectric turbine, the rate averages to be $0.08/kWhr. The MPR rates as well as TOD factors are shown in Appendix C. Under this tariff, all renewable energy credits (REC's) generated for the electricity sold back to the grid would be owned by SDG&E. CMWD would retain ownership of all REC's generated for power used on site at the Maerkle Reservoir. April 2010 30 pw://Carollofl)ociHnenls;Clienl/CA/Carlsbad/8362A10/Deliverables/C:ar!sbad_TM (RevisedFinal) 8.5.2 AB 2466 Tariff Cun-ently, SDG&E does not offer a tariff, which covers Assembly Bill 2466. Assembly Bill 2466 allows for renewable energy producers to produce electricity at one-meter location and use this as credit at another owned meter location. This is commonly referred to as wheeling. However, with this tariff there would not be any wheeling fees associated. A tariff from AB 2466 would allow CMWD to use the excess electricity generated at the Maerkle Reservoir as a credit on their electricity bill at another location. The excess electricity generated at the hydroelectric facility would become bill credits, which would be applied to the monthly bill of the benefiting facility. Any unused bill credits carry over to the next month. However, after a 12 month predefined period, any unused bill credits are set to zero. This tariff would provide the largest economic advantage. This is because the rates at which CMWD purchases electricity are higher than the rates at which they could sell power through the SCH WATER tariff. In addition to this, any REC's generated would be owned by CMWD. SDG&E staff has reported that this tariff is currently in draft form and expected to be issued sometime in spring of 2010, although this was not certain. It is not certain also, whether water agencies would be included although they are currently included in the draft tariff. Additional informafion on this tariff is contained in the Appendix H. In order to assure compliance, CMWD would need to verify that CMWD's organizational legal status was applicable to the tariff. 8.5.3 Recommended Tariff The recommended tariff and only tariff available is the SCHEDULE WATER tariff. However, if the AB 2466 tariff were implemented before the construction of a hydroelectric facility, it would be recommended to pursue this tariff. 9.0 COST ESTIMATE Cost estimates were prepared for Alternative Nos. 1 and 2 based on the assumptions listed below and from the vendor quotes for the turbines. For the additional alternatives, the cost estimate was increased (or decreased) to account for the differences in the alternatives. The cost estimates are listed below in Table 7. More detailed cost breakdowns for each Alternative are shown in Appendix E. • The building and piping would be the same for either alternative. • The building would bean18ftx18ft precast concrete building with 10 ft wide rollup door. • Turbine costs include the budget quote for the turbine plus installation costs and cost to provide UL listed control panel. April 2010 31 pw://Carol(o/DocumenIs/Client/CA/Carlsbad/8362A10/Deliwerables/Carld)ad_TM (RevisedFinal) Table 7 Hydroelectric Turbine Alternative Cost Estimates Pressure Control Hydroelectric Facility at Maerkle Reservoir Carlsbad Municipal Water District Alt. No. Turbine 1 Flow Turbine 2 Flow Estimated Project Cost ($ million) 1 5.4 -$1.09 2 2.2 -$1.06 3 3.6 ~ $1.06 4 6.75 -$1.12 5 7.75 ~ $1.12 6 3.6 3.6 $1.29 7 5.4 3.6 $1.34 8 6.75 3.6 $1.34 9 7.75 2.2 $1.29 10 7.75 -$1.12 11 3.6 3.6 $1.29 12 11 ~ $1.15 13 6.75 3.6 $1.34 14 7.75 2.2 $1.29 15 10 -$1.13 16 12 -$1.16 17 0-5 0-5 $1.51 10.0 ECONOMIC ANALYSIS A net present value (NPV) analysis was used to determine the payback period of the project based on a wide range of factors. The NPV is the current worth of a series of future revenues and costs based on a discount rate plus the capital cost of the project. 10.1 NPV Assumptions Table 8 lists the assumpfions for the NPV analysis. These assumptions represent the factors that impact the length of the payback period for the project. April 2010 pw;//Carollo/DocumentsyClienUCA/Carisbad/8362A10/Deliverables/Carisbad_TM (RevisedFinal) 32 Table 8 NPV Assumptions Pressure Control Hydroelectric Facility at Maerkle Reservoir Carlsbad Municipal Water District Assumptions Units Values Turbine Operation and Maintenance Cost $/kWhr 0.01 Turbine Out of Service % 5 Turbine Flov/Available*^* % Varies'^' Discount Rate % 4.5 Inflation Rate (O&M)*^^ % 3 Electricity Offset^^' kWhrs 165,000 Credit for Electricity Offset*^' $ 29,000 Inflation Rate (Electrical Rates and REC's) % 5 REC Value $/kWhr 0.04 Notes: (1) Turbine availability differed for each turbine flow rate. Figure No. 2 was utilized to develop the availability for each alternative. (2) Based on 2009 partial year electrical bill and extrapolated for 12 months. 10.2 Economic Analysis Results The results of the economic analysis are shown in Table 9. Table 9 lists the number of turbines, the fiow rate of each, the total maximum power from the facility, the annual expected electricity production, the project cost, 20-year net present value, and the payback based on the net present value. Additionally, for several alternafives, the AB 2466 tariff was used to demonstrate the affect of this potential tariff on the economics of the project. As Table 9 indicates, the two best alternatives with respect to economics and without changing the current fiow strategy would be Alternative Nos. 4 and 9. Alternative No. 4 utilizes one 6.75 cfs unit while Alternative No. 9 would utilize one 7.75 cfs and one 2.2 cfs unit. Alternative No. 9 allows the smaller turbine to take advantage of the periods when flow is too low for a larger unit. See Appendix F for addifional informafion. 10.3 Time of Use The economic analysis assumed that the turbine would operate consistently throughout the day and did not account for the low flow control option discussed in Section 5.2.1. The SCHEDULE WATER tariff provides for a higher payment during certain times ofthe year and certain hours of the day referred to as time of use (TOU). Therefore, if the low flow control option was ufilized, the turbine could also be run during peak hours of the day to maximize the electrical revenue. This is reflected in Alternative Nos. 10 through 16. Maximizing the peak rate schedule can significantly reduce the payback period. However, if Poseidon Resources required only one flow change per day for their desalination water, time of use would not be feasible, as it would require a minimum of two flow rate changes per day. April 2010 pw.//Caroilo/[)ocuments/Clien1/CA;Cari5bad/8362A10/Deliverables/Carisbad_TM (RevisedFinal) 33 o t (A O Dl 0 0) (a (0 o u. u o i W O Q o o .9-5 2 o O +; •= O S O (D -o 1 S £ !5 0:0.0 Oi 0) (0 (- RI L-.Q (0 >» fl) re >» Q. ^ 0) w o >*> 1= CM Z E 0^0 CL O E re 3 C C < x: re o Q. ^ (D CM II II O z cn to o o o IT) 00 in CNJ to 06 CO CO CD in 10 CD in 10 (s5 CO CD CD CO CD CO CO CD oi CO CO CO O) 10 CM 00 C35 in 0 01 00 >o LO 1^ CD 0 T— to CO CM CM CM 0 10 CO CO CO CO CM cn CD CM 0 CM CM CD CO 0 CD CD CD 0 0 CD CM 0 0 (b 0 T— CD CM 69 69 69 69 60 69 eo 60 60 69 to CD O CO O CD CD CM m < iri CD to y> CM CM O) 1- CM CO CO 05 CM CM O) t- CM in CO O) CM t/> V> (/^ if^ CO CM CD 0 T— S-LO cn , Oi CO CO 1 ^ CM_ CO in ' co" in CM' CM' in T— CO CM CO CO CO o> CO CM in CO 00 o> Ol CO CO CO CD in CO in CO CO CD CD CM CD < CM CM CD CO tn CD CM CO in CD 03 CD CO CD CO in CO CO CD CO o CM CD CD CO CO in 00 CD CD CM QD < CO CO to 69 tf> to y> CO CD CD CM CO CM 01 CO t— in CD CO CO CM CM CO o CM CD CD CO O CM in tn in in CD CD CO CO CD CO CD CM CO CM in in CD 1^ Csl CO CD in CO CO CD CD x— CM CM CD 0 CO Oi 0 h-00 CD CD CD CO ^_ 0 0 CjT CD' CD co' CM' h-' CD' 0 T— CD CO CM CO CO in 0 CM 0 CO CO CO CO CO CO CO CM CD (D 0 0 0 0 D D D C C C c C C 0) 0 0 0 > > > > > > > 0) CD 0 0 0 ^ ^ ^ jx: CO CD CD CD CD CD CO CD CD CD <a 0 0 0 a CL CL CL Q-CL CL CD <D 0 (D 0 0 0 N N N N N N N E E E £ E E E X x 'x X x x CD CD CD CD CD CD CD E E E E E E E 0 0 0 0 0 0 0 H l-1-l_-\~ H CM in CO CO CM c D X 0 CL e 0 c X 0 Q. O i_ 0 N O O O o CO April 2010 pw://Cafo(fo/Docimen(s/aienlCA/Car(sba(f8362AtO/Defiverables/Car(sbad_TM (RewsedFinal) 34 — —- —4— 10.4 CEQA and Permitting A review of the project needs to be completed in conformance with the California Environmental Quality Act (CEQA). In addition to the permits that are typically required for water treatment plant construction, a hydroelectric turbine facility would also need to get approval from the Federal Energy Regulatory Commission (FERC). The application for approval must be processed through the Hydroelectric Project Licensing Process. There are three different scenarios for Small Hydro/Low Impact Projects, refer to Appendix G for a brochure on the process: • License. • 5 Megawatt Exemption. • Conduit Exemption. The Conduit Exemption is the easy and fastest scenario for approval. In order to get a Conduit Exempfion the project must meet the following requirements: • Must use a conduit that was constructed for a non-hydropower use. • The utility must own the proposed powerhouse and land. • Generation must be before the final point of discharge. FERC was contacted and the potential Carisbad project was discussed with them. Robert Bell (located in Washington, D.C.) is the contact for Conduit Exemptions and his e-mail is RBell@ferc.gov. Projects can be bid without a FERC permit but they cannot be constructed. He indicated that this project would qualify for the conduit exemption based on the project information provided to him. 10.5 Consultation Process The first part of obtaining a conduit exemption permit is the three-stage consultation process. Consultation must occur with all relevant state, federal and local agencies. Table 10 is a preliminary list of relevant agencies for this projecL However, this could change as the project evolves. Each agency must be notified or a good faith effort made to contact them, of the potential project and supplied with preliminary application materials. The agency will have fime to submit comments and/or input on the project. Additionally, after 30 days (and no more than 60 days) from when all agencies were sent notification, a public meefing will be held for all interested parties. Within 60 days from the meefing, all relevant agencies must submit comments or forego the consultation stage. If all agencies are satisfied or provide no comments, the FERC application process can move forward. If not, then additional consultation stages are conducted with those agencies. Typically, conduit exemption projects on potable water do not require additional consultafion stages. April 2010 35 pw://Carrflo/&ocuments/Client/CA/Carl5ba(i/8362A10/Delivefables/Carlsbad_TM (RevisedFinal) Table 10 FERC Consultation Process - Relevant Agencies Pressure Control Hydroelectric Facility at Maerkle Reservoir Carlsbad Municipal Water District Relevant Agencies Advisory Council on Historic Preservation, Western Office of Federal Agency Programs California Department of Conservation California Department of Fish and Game, South Coast Region California Department of Parks and Recreation California Department of Parks and Recreation, Office of Historic Preservation California Department of Water Resources, Southern District California Public Ufilities Commission California State Water Resources Control Board Federal Emergency Management Agency National Marine Fisheries Service National Park Service U.S. Environmental Protection Agency U.S. Army Corps of Engineers U.S. Department of Agriculture, Forest Service U.S. Department of Interior, Bureau of Indian Affairs U.S. Department of Interior, Bureau of Land Management U.S. Department of Interior, Bureau of Reclamation U.S. Fish and Wildlife Service Advisory Council on Historic Preservation, Western Office of Federal Agency Programs 10.6 Application Upon completion of the consultation process and completion of the contract documents for the project, the FERC conduit exemption permit application must be completed and submitted. FERC's review process can take from 8 to 10 months for a conduit exemption. Additionally, a state Water Quality Certificafion or waiver must be applied for and obtained. 11.0 RECOMMENDATIONS AND CONCLUSION Installing a Pressure Control Hydroelectric Facility parallel to the existing pressure reducing station at the Maerkle Reservoir location via Alternative No. 4 appears feasible in respect to engineering and economic considerations. Addifionally, it is recommended to leave space and piping connections for a possible future turbine. The future turbine could be a 3.6 cfs or 2.2 cfs unit that would enable CMWD to generate at a broader range of flows. The net present value (NPV) payback period is estimated to be 14.7 years. It appears that the NPV April 2010 pw:/;Cardlo/Documenls/Client/CA/Car!sbad/8362A10/Deliverables/Carisbad_TM (RevisedFinal) 36 payback period could be reduced to 8 years if a tariff based on AB 2466 is issued in the spring of 2010. Table 11 summarizes the recommended alternafive. Table 11 Recommended Alternative Pressure Control Hydroelectric Facility at Maerkle Reservoir Carlsbad Municipal Water District Criteria Units Alternative No. 4 Flow cfs 6,75 Power Produced kW 135 Electricity Produced per Year kWhrs 832,812 Project Cost $ $1,120,000 Net Present Value (NPV) $ $410,000 NPV Payback Period years 14.7 Alternative No. 17 is based on emerging technology, which is yet to be proven. However, its benefits, especially its ability to act as a pressure reducing or sustaining valve warrant that it be further investigated and monitored during detailed design. April 2010 pw://CaroliofDocuments/Client/CAyCarlsbad/8362A10/Deliverables/Caflsbad_TM (RevisedFinal) 37 Technical Memorandum APPENDIX A - MAERKLE RESERVOIR SITE PLAN April 2010 pw://Carollo/OocumenlsyClie(it/CA/Carlsbati;8362A10/Deliverables/Car1sbad_TM [RevisedFinal) Pressure Control Hydroelectric Facility SITE PLAN Technical Memorandum APPENDIX B - TURBINE DATA SHEETS April 2010 pw;//Carollo/Dix:umenl5/ClientJCA/Carlsbad/8362A10/Deliverables/Cai1sbad_TM (RevisedFinal) Canyon Hydro Nove mber 13, 2009 Mr. Christopher Crotwell Carollo Engineers 704-598-0918 Ext. 228 ccrotwell@carollo.com Dear Mr. Crotwell, Thank you for the oppor tunity to offer equipment for the Carisbad MWD Project. As always we welcome the opportunity to work with you. From your correspondence, we understand th e site offers a dynamic head of 300 feet with a variable system fiow. For the purpose of this estimate we are considering a flow rates of 3 cfs and 6 cfs. Option #1 Cornell model 4TR3 turbine which will pass 2.2 cfs at a dynamic head of 300 feet with an expected system producfion of 36 KW. Please see our equipment package descripfion below. (1) Cornell 4TR3 turbine, CIB Fitted, wJ mech. seal, horizontal orientation (1) US Motors, 44 KW, 480 VAC, 60 Hz, 1800 RPM, 3 ph., ODP, inducfion generator. (1) 8" Bray/Rotork lug-style butterfly valve, hydraulic open/spring closure (1) Rex Omega direct drive couplings (1) Custom 120 VAC, hydraulic power unit (1) Custom structural steel equipment mounting skid (1) Custom 8" X 4" flanged inlet cone reducer (1) Custom 6" X 8" flanged outlet cone increaser (1) Switchgear/controls panel to parallel the g enerator with the utility grid and provide protective relays to North American utility grid standards for a project this size. Esfimated system cost, as described $63,000.00 Option #2 Cornell 5TR2 turbine which will pa ss 5.40 cfs at a dynamic head of 300 feet with an expected system production 100 KW. Please see our equipment package description below. (1) Cornell 5TR2 turbine, CIB Fitted, w/ mech. seal, horizontal orientafion (1) US Motors, 150 HP, 480 VAC, 60 Hz, 1200 RPM, 3 ph., ODP, inducfion generator. (1) 10" Bray/Rotork lug-style butterfly valve, hydraulic open/spring closure (1) Rex Omega direct drive couplings (1) Custom 120 VAC, hydraulic power unit (1) Custom structural steel equipment mounting skid (1) Custom 10" X 5" fianged inlet cone reducer (1) Custom 8" X 10" flanged outlet cone increaser (1) Switchgear/controls panel to parallel the g enerator with the utility grid and provide protective relays to North American utility grid standards for a project this size. Esfimated system cost, as described $84,645.00 Canyon Hydro- the water power division of Canyon Industries, inc. • 5500 Blue Heron Lane • PO, Box 36 • Deming WA 98244 360.592-B5S2 • Fax. 360.592.2235 • emaii: tufbines@canyonhycfro.eom • www.canyonhydro.com Each equipment package will be custom designed to your specific site requirements. As the project progresses and these r equirements are defined , we will be pleased to offer a Preli minary Design Specification and a firm quotation. Budget esfimates are offered for planning purposes but are typically within 15% of a firm quotation for the same equipment package scope. Estimated price FOB Deming, Washington (crated for shipment) Delivery: 16 weeks from receipt of drawing approval and release for manufacture payment Proposed Terms: 15% down payment to prepare final design and submittal drawings 35% payment on approval of submittal drawings and release for manufacture 25% mid-contract payment (8 weeks from release lo manufacture) Balance due prior to shipment We took fo rward to assist ing you as this pr oject progr esses. Plea se contact me when additional information will be helpful or as questions arise. Sincerely, Eric Melander Canyon Hydro-the water power division of Canyon industries, Inc. • 5500 Blue Heron Lane • P.O. Box 36 • Deming WA 98244 360.592-5552 • Fax; 360,592.2235 • email: tutb!nes@canyonhydro,com • www.canyonhydro.conri c: . o PER CENT EFFICIENCY NPDH FT. o o o o CM O .O O O •o CO UJ I-3 z cc LU 0. w z o _l < o CO D o •o CD o •o o o CM 2 o o w oe O X < -I & O a. < a. o w a. 3 a. Ml z O 34 PER CENT EFFICIENCY NPDH FT. o o IX) CO o o o CO o o in C\J o o o CNJ o o in o o o tu Z IX UJ a. (fi z o < o w o a. ex. < O CO o o CO > LU 2 o H O ID LU H < X o cc CL Q. < LU < Z CO O lU o Z Q — LU O m is 4# ^ Hydro February 1, 2010 Mr. Christopher Crotwell Carollo Engineers 704-598-0918 Ext. 228 ccrotwell@carollo.com Dear Mr. Crotwell, Thank you for the updated information on the Carlsbad MWD Project. As always we welcome the opportunity to work with you. From your latest correspondence, we understand the site offers a dynamic head of 300 feet with a desired fiow rate between 6 cfs and 7 cfs. For these conditions we offer the equipment package described below. (1) Cornell 6TR3 hydro turbine, CIB Fitted, w/ mech. seal, horizontal orientation (1) US Motors, 149 KW, 480 VAC, 60 Hz, 1800 RPM, 3 ph., ODP, induction generator. (1)12" Bray/Rotork lug-style butterfly valve, hydraulic open/spring closure (1) Rex Omega direct drive coupling system (1) Custom 120 VAC, hydraulic power unit (1) Custom structural steel equipment mounfing skid (1) Custom 12" X 6" flanged inlet cone reducer (1) Custom 8" X 12" fianged oufiet cone increaser (1) Switchgear/controls panel to parallel the generator with the utility grid and pr ovide protective relays to North American utility grid standards for a project this size. Esfimated system cost, as described $95,145.00 The model 6TR3 turbine is rated to pass 6.75 cfs at a dynamic head of 300 feet. Expected system producfion using the equipment package described above will be 135 KW, under design conditions. The turbine will require a flow rate of 6.75 cfs to become operational. The equipment package will not generate power below a site flow rate of 6.75 cfs. The equipment package offered will be custom designed to the specific requirements of the site. As the project progresses and these requirements are defined, we will be pleased to offer a Preliminary Design Specification and a firm quotation. Budget esfimates are offered for planning purposes but are typically within 15% of a firm quotation for the same equipment package scope. Estimated price FOB Deming, Washington (crated for shipment) Delivery: 16 weeks from receipt of drawing approval and release for manufacture payment Proposed Terms: 15% down payment to prepare final design and submittal drawings 35% payment on approval of submittal drawings and release for manufacture 25% mid-contract payment (8 weeks from release to manufacture) Balance due prior to shipment We look forward to discussing this project further and welcome any questions you may have. Sincerely, Eric Melander Canyon Hydro-the water power division of Canyon Industries, Inc. • 5500 Blue Heron Lane • PO. Box 36 • Deming WA 98244 360.592-5552 • Fax 360.592.2235 • email: tufbines@canyonhydro.com • www.canyonhydfO.com Z CO O i " LU j PER CENT EFFICIENCY NPDH FT. o o o o CO o o in CM o .o o CM O O LO UJ 3 Z CC UJ a (/> z o _] -J < « 3 o o o o o in o o lil as O •> a X 2 & o D. • >- Z < D. o w o. Id Z fifi O . I q o i £ : UJ PER CENT EFFICIENCY NPDH FT. o O O in o CO o o o CO o CJ lO CM ^ O 10 TURBINE OUTPUT KW o O CO o CO o o o CO 8 g g § CO CO CO o o .o o .o in CO o .o o CO o .o in CM o o o CM o .o in o CO CO o CO o CD CM O CM o CM CM UJ l-3 Z 1 CC UJ Q. z o < (5 CO 3 z O u a. i I s IM z g 48 PER CENT EFFICIENCY NPDH FT. o o o o .o o m o o o o o o CO o o o CM o o o UJ 3 z OC UJ Q. tfl z o -I -I < O </} 3 X O P z z < a. o o. X 111 z O 49 Zeropex AS QUOTATION Client Carollo Site Carlsbad Quote type Budgetary quote Zeropex Contact Sven Anden Phone + 1 (248) 644 0011 e-mail sa(5)xeroDex.com Doc. No QT35-3 Doc. Title Carollo - Carlsbad Rev. 3 Issue date 2010-02-05 Alias Doc Name Author TAE;DC;PRO Create date Reviewed Review date Approved TAE Approve date Project No SALES Project Name Zeropex sales project 2010-02-05 2010-02-05 2010-02-05 ^zeropex QT35-3 - Carollo - Carlsbad version 3 Contents 1 Introduction 3 1.1 Customer value 4 2 System overview 5 2.1 Turbine unit 5 2.2 Control panel 5 2.3 Interfaces 5 3 Scope and Specifications 7 3.1 Interfaces 7 3.2 Options 8 3.3 Alternatives 8 4 Technical information 9 4.1 Efficiency calculations 10 5 Exceptions and clarifications 10 5.1 Clarifications 10 5.2 Exclusions 11 6 Terms of payment 12 7 General terms for Sale of Products and Services 13 8 Contact information 16 Page 2 of 16 Zeropex AS, Gamle Algardsvei 170, 4325 Sandnes, Norway, Phone +47 930 29 610. www. Zeropex.coni QT35-3 - Carollo - Carlsbad version 3 1 Introduction Zeropex AS is pleased to present our proposal for the above referenced project. We recommend our patented Difgen turbine technology with micro generation which is a complete solution for simple installation and commissioning. One (1), Difgen systems, each consisting of two (2) turbines and one (1) generator and control cubicle, will fit the requirements ofthe project. The system is unique as it delivers energy as conventional turbines but with the advantage of controlling water pressure. Alternatively, the Difgen can easily be configured to manage water flow rate. The Difgen can even be used in pumping applications when required as an option. This comprehensive set of features permits the engineering of a smart grid water system. In short, the Difgen does what a modulating PRV can do, and much more. The Difgen components conform to water quality standards. Excess differential energy is released as electric power for export to the grid or for local consumption. Each generator produces 30-250 kW and is robust in design and of an industrial standard. The system has the advantages of low maintenance with predictable energy output. No manual intervention is required during the operation and the system has fally automatic operation and is failsafe. Our unique Difgen power turbine with pressure reduction capability offers the following features: High efficiency over a wide range of flows Rapid ROI and income generation Adaptive Pressure and Flow Control Predicable Electricity Generation Built-in flow measurement Designed to meet all relevant standards The system can be used to pump water when required (optional) The system can be used as a UPS when conditions allow (optional) ^7Prnnpy Page 3 of 16 Zeropex AS, Gamle Algardsvei 170,4325 Sandnes, Norway, Phone +47 930 29 610. www. Zeropex.com QT35-3 - Carollo - Carlsbad version 3 1.1 Customer value Based on input from the actual site, received from the customer, the following calculation is an indication of the value proposition. Flow 4,36 rngd average ' 4 Flow max 5,40 ' rrig^" • > Head 130 Gravity (constant) Efficiency percent Production in kW 125.97, kW Production in kW max 156.02 kW Price per kW 0.11 USD Yearly production 1 103 505 kWh Yearly revenue USD Equipment investment 350 000 USD Payback 2.94 years IRR 45^3* NPV 1 098 765 USD WACC 4,00 % Cost per kW 0,013 USD The calculation is based on the foliowing assumptions: Cost of capital: 4% Life time: 20 years Value of generated power: 0,108 USD/kWh 7PronPx Page 4 of 16 Zeropex AS, Gamle Algardsvei 170,4325 Sandnes, Norway. Phone +47 930 29 610. www. Zeropex.com QT35-3 - Carollo - Carisbad version 3 2 System overview The Difgen is delivered as a complete pressure and flow control system with electrical power generation. It comprises a turbine with generator and a control cabinet. The interfaces are pipe flanges, grid connection and control system communication (optional). 2.1 Turbine unit The turbine and generator is delivered skid mounted. The base solution is a direct drive horizontal skid, but it can also be delivered stacked (belt driven) or direct drive vertical (both of these are optional). The turbine comes with standard flanges in both ends, in a straight line. The design of the turbine is optimized to maximize energy recovery from the intended pressure drop incurred. The efficiency is high over a large window of flow rates. Maintenance is lube oil replacement at regular intervals, and inspection ofthe turbine lobes ever 1-2 years. 2.2 Control panel The Difgen is delivered with all control and power electronics in a control panel. The system can control the turbine in the foltowing modes: • As a pressure control unit (upstream or downstream) by measuring pressure and adjusting speed (RPM) and load. • As a flow controller, by running at a specific speed • Against a pre-set level in a tank (optional) • Pumping (optional) in forward or reverse The set points for the various modes can be changed as often as required for optimum operation of the plant. Alarm and warnings are raised according to predetermined limits and include e.g. - Pressure loss - Grid failure - High temperatures - Sensor failure - Water ingress The system is designed for fail safe operation, and can control an external valve. However, the arrangement of valves, bypasses, etc will vary from site to site, and is the responsibility of the client. 2.3 Interfaces The control cabinet comes with a number of analog and discrete inputs/outputs for interfacing with client equipment or I/O. Page 5 of 16 7P PO n PX Zeropex AS, Gamle Algardsvei 170,4325 Sandnes, Norway, Phone +47 930 29 610. www. Zeropexxom QT35-3 - Carollo - Carisbad version 3 To interface with plant control systems or SCADA system, the Difgen can be delivered with a range of field buses (Profibus, Modbus, etc). A Web option for monitoring is optional. The cabinet is delivered with terminals for grid connection (sections 240/480/690V +/- regional parameters - 50/60Hz). Protection against islanding operation in case of grid outages is included based on voltage and frequency limits. Alarms and warnings are communicated through the above interfaces, or they can optionally be forwarded via SMS or e-mail. Page 6 of 16 Q ^ y zeropex AS, Gamle Algardsvei 170,4325 Sandnes, Norway, Phone +47 930 29 610. www. Zeropex.com QT35-3 - Carollo - Carisbad version 3 3 Scope and Specifications The following Products shall be supplied by Supplier: Qty Unit Ea Ea Product Difgen Duplo DG-18-18 Power electronics Description Pressure management system with two turbines, including generator, frames, and drive system 220V, 60 Hz grid connection 3.1 Interfaces Interface Description Comments flanges towards interfacing pipes ANSI DN 14^ voltage towards Purchaser's power grid 440/690V/60HZ To be agreed. Up to 70QV is included in price specific reguirements for foundStidpi,fc)r the installation site ' •• Total weight is approx 1000 •<poun(is:-''' electrical interfaces towards the Purchaser's control system (preferably a "Communications bus") Not included water flqv^i^fid pressure condilaonSJD: M^5c.i2Qp m3/h Max 15 baf housing pressure mx 146 psi: diff. pressure 'I'i " ' ^7Pmnpy Page 7 of 16 Zeropex AS, Gamle Algardsvei 170, 4325 Sandnes, Norway, Phone +47 930 29 610. www. Zeropex.coni QT35-3 - Carollo - Carisbad version 3 3.2 Options Item Qty Unit Product Description Included 1 1 Ea Islanding kit Will ensure continuous operation during No Ea Islanding kit power outages 2 1 Ea GPU - General No Ea Protection Unit No 3 1 Ea NEMA-protection No 3.3 Alternatives Item Qty Unit Product Description Unit price 7Pmnpx Page 8 of 16 Zeropex AS, Gamle Algardsvei 170,4325 Sandnes, Norway, Phone +47 930 29 610. www. Zeropex.com QT35-3 - Carollo - Carisbad version 3 4 Technical information Difgen DG18-18 are proposed for this application, as this provides the best combination of flow throughput, efficiency and flexibility. Dimensional drawings is for one turbine and generator, all figures are in metric units: Hut und Patifeder nach DIN6885 BI T keyway and key act to DIN6885 sheet I Abmessungen / Dimensions Baureihe: VX186QD series: VX186QD Achtung / Attention Plotzbedait fur WariirngsEtfbeiten W-1000 mm min , 1500 mm empfohlen space required for maintenance work W-1000 mm mm . 1500 mm recommended I C c e c zernnpy Page 9 of 16 Zeropes AS, Gamle Algardsvei 170,4325 Sandnes, Nonvay, Phone +47 930 2 9 610. www. Zeropex.coni QT35-3 - Carollo - Carisbad version 3 4.1 Efficiency calculations Based on input from the customer, the chart below is an indication of power production to be expected from the installation. 100 90 80 ^ 70 5 i 60 o a. "S u E 50 KI O 0) E •a 40 S m e> i 30 20 10 / 90 80 70 60 50 ^ >. u c 40 I 0) 30 20 10 -generated po'.ver lor puitp 184QD@ ^0 bar volume fki'-v at operating point 1288 rrf/h = SO fs gi 624 rrtn"-1) nininumvolumefki^v (216m'/h = SOI's @456min'-1 and 966 r^Ti) -rreximim volume tlo.v (360 nV;h = 100 Is @ 793inn' 1) - efficiency 20 40 60 80 volume flow (l/s) 100 120 140 The information in this document is indicative, and Zeropex cannot take on any responsibility for the actual performance. 5 Exceptions and clarifications The quote is based on the following assumptions: • The cabling connecting the site to the power grid is of sufficient quality and capacity • The turbine is designed to be exposed to water. The generator is not designed for exposure to water. If this is an issue, Zeropex will revert with a different set-up, where both parts are water intrusion protected. • The control electronics must be placed in a dry room. 5.1 Clarifications TPrnnPY Page 10 of 16 Zeropex AS, Gamle Algardsvei 170,4325 Sandnes, Norway, Phone +47 930 29 610. www. Zeropex.com QT35-3 - Carollo - Carisbad version 3 • Unless included in our Scope of Supply Section, start-up service, training, supervision, etc. is not included in this quotation. If these services are required, they are available at prevailing rates plus all expenses portal-to-portal. 5.2 Exclusions ' • Installation and site cabling excluded unless included in our scope of supply. * • No piping, valves, fittings, wiring, anchor bolts, etc. are included other than those i listed. ; i t t 4 I \ A « 0 % 0 J e e c t e • e e Page 11 of 16 _ pi CJ V Zeropex AS, Gamle Algardsvei 170,4325 Sandnes, Norway, Pbone +47 930 29 610. www. Zeropex.com QT35-3 - Carollo - Carisbad version 3 6 Terms of payment Currency is USS. Total Net Price: Price is valid for Taxes: Delivery: Delivery time: Supplier wairanty: $350,000 90 days Prices are exclusive of any and all sales taxes FOB shipment address, not including installation. 16 weeks from time of order, excluding holidays 12 months from delivery date that unit is free from defects in materials, workmanship and design and conforms to specifications Payment terms; 50% with order, 40% at delivery and 10% after 30 days. •7PrnnPY Page 12 of 16 Zeropex AS, Gamle Algardsvei 170,4325 Sandnes, Norway, Pbone +47 930 29610. www. Zeropejccom QT35-3 - Carollo - Carisbad version 3 7 General terms for Sale of Products and Services 1 APPLICATION The following General Terms shall apply for all Contracts entered into between Purchaser and Supplier for sale of Products and Services, unless othenwise specifically agreed. These General Terms shall also apply for future business transactions between Supplier and Purchaser, even if they are not referred to or enclosed in the individual future case(s). 2 DEFINITIONS "Supplier" means Zeropex AS and its subsidiaries at any time. "Force Majeure" means an event defined as Force Majeure in the ICC Publication no 650. "General Terms" means these General Terms for Sale of Products and Services forming an integral part of the Contract to which it relates. "Products" means the products together with pertaining materials, equipment and documentation to be delivered by Supplier to Purchaser pursuant to the Contract. "Purchase Price" means the total price ofthe Contract, as ohginally set out or later amended. The Purchase Price may include both lump sum elements and reimbursable elements. "Contract" means any agreement reached between the Purchaser and Supplier for provision of Products or Services. "Purchaser" means the legal entity purchasing Products or Services from the Supplier pursuant to the Contract. "Services" means services set forth in the Contract to be provided by the Supplier lo the Purchaser pursuant to the Contract. 3 DEUVERY Unless othenwise set forth in the relevant Contract, delivery of the Products shaii be made EXW, (in accordance with INCOTERMS 2000) Supplier's manufacturing site. The delivery date(s) shall be as set forth in the in the Contract. The Products shall be delivered properly packed and marked in accordance with the requirements in the Contract. 4 LAWS AND REGULATIONS Purchaser is responsible for having all the relevant licenses in place for installing and operating the Products and for generating power on the basis of the Products. Purchaser shall at its own cost and risk abide by all laws, regulations and licenses applicable to its operation of the Products. 5 PURCHASER'S INFORMATION Supplier shall be entitled lo gain access to operational data for the purpose of assessing any claims regarding ihe Products and for the purpose of optimization of the Products' performance and maintenance. Purchaser shall be responsible for the correctness and sufficiency of all information provided by the Purchaser to Supplier in relation to the Contract. 6 VARIATIONS Purchaser has the right to order variations in quality, quantity or time of delivery of the Products and Services, provided that such variations do not exceed what the parties could reasonably expect when the Contract was entered into. Variations shall be requested by Purchaser in writing. Supplier shall within 10 business days by written notice confirm any effects on the Purchase Price, time of delivery and technical specifications. All adjustments to the Purchase Price shall correspond to the pricing method and principles applied in the Contract, and otherwise be at a reasonable level. Supplier shall be entitled to request adjustments in the Purchase Price or delivery date{s) should either of these be affected for reasons which Supplier is not responsible. The final variation shall be approved by Purchaser in writing. TERMS OF PAYMENT c: eii: III e: c <««ii Page 13 of 16 Zeropex AS, Gamle Algardsvei 170,4325 Sandnes, Norway, Phone +47 930 2 9 610. www. Zeropex.com (jenerai i erms Tor Kale or t-Toaucis and aervices - rev. uctoDer ^uuy Unless othen/vise specifically set out in the Contract, Purchaser shall pay all Invoices within 14 days from date of invoice. Purchaser may withhold any disputed amounts, provided that Purchaser shall pay undisputed amounts of partly disputed invoices. Supplier shall be entitled to interest on overdue payments calculated in accordance with the applicable rate pursuant to the Norwegian Interest on Overdue Payments Act (no. 100/1976). Al! prices are exclusive of value added taxes (VAT) unless otherwise specified in the Contract. 8 DEFECTS AND GUARANTEES Supplier guarantees for a period of 12 months from the date of delivery that the Products conform to the specifications in the Contract and are free of fault in material, workmanship and design. Purchaser shall examine the Products upon delivery. If any defects are found, Purchaser shall notify Supplier thereof in writing immediately thereafter. Supplier Is liable for a defect only if Purchaser has given such notice immediately after it discovered or ought to have discovered such defect. Supplier is not liable defects notified of after ihe expiry of the guarantee period. If the Products are found to be defective during the guarantee period. Supplier shall within reasonable time at its own cost repair or replace (at its option) at Supplier's facilities, and Supplier shall not be liable for any labour to remove or reinstall the Products or replaced parts, or for any transportation costs. Any repaired or replaced parts of the Products shall be guaranteed by Supplier for a renewed period with the same duration as the original guarantee. However, the total guarantee period shall not exceed 18 months from delivery of the Products. Products which Supplier determines to have been subjected to abuse, improper use, or use in contradiction to Supplier's manuals, will not be entitled to the benefits of any guarantee by Supplier. Supplier only guarantees work performed by it self. Faulty Services shall be re-performed at Supplier's own cost during the same installation operation. The rights and remedies expressly set out in Articles 8 and 10 are the sole remedies available to Purchaser in the event of defects in the Products and Services. 9 DELAY If delivery of the Products has not taken place on the date(s) of delivery set out in the Contract, for reasons which Supplier is responsible. Purchaser has the right to claim liquidated damages to an anrount equal to 0.5% of the value of the item in delay per day until delivery occurs. Supplier's cumulative liability for liquidated damages is limited to 5% of the value of the item in delay, and shall together with Article 10 be the sole remedy available to Purchaser upon delay in delivery of Products or Services. 10 TERMINATION DUE TO SUPPLIER'S DEFAULT Purchaser has the right to terminate the Contract with immediate effect by giving written notice to Supplier if Supplier becomes insolvent or is in material breach of its obligations under the Contract. 11 INTELLECTUAL PROPERTY RIGHTS Intellectual property such as drawings, specifications, software, data-media and other technical or commercial information or documentation provided by Supplier to Purchaser, pertaining to the Product or otherwise, shall remain the property of Supplier. Supplier shall grant to Purchaser a limited non- exclusive, royalty-free, non-assignable right to use Supplier's Intellectual property for the strict purpose of use, operation and maintenance of the Products as set forth in the Contract. 12 FORCE MAJEURE Neither of the Parties shal! be considered to be in default in performance of its obligations under the Contract to the extent such performance has been prevented by Force Majeure. The Party invoking Force Majeure shal! notify the other Party in writing without delay on the intervention and on the cessation of such circumstance. 13 INDEMNITY - LIMITATIONS OF LIABILITY The Parties shall mutually indemnify and hold each other harmless from and against; (i) all loss or damage to their respective property; (ii) injury to or death of their respective personnel; and (iii) its own consequential or indirect losses (such as but not limited to loss of production, costs or loss caused by reduced power generation or Page 14 tienerai i erms tor sale ot Kroauas and services - rev. uctotier ifuu9 pollution), that may arise in connection with the Contract. This shall apply Irrespective of how the loss or damage is caused, save upon gross negligence or wilful misconduct by the indemnified Party. Each Party shall be liable for any third party damages and losses caused by him, and he shall indemnify the other Party accordingly. Subject to the first paragraph of this Article 13 and applicable mandatory law. Purchaser shall however indemnify and hold Supplier harmless from any loss or damage caused by the Products in their life time. Supplier's liability for breach of Contract shall be limited to 100% of the value of the Contract, provided, however, such that Supplier's aggregate liability in no event shall exceed NOK 1 million. 15 CONFIDENTIALITY 14 TITLE TO PRODUCTS - RISK Title to the Products shal! pass to Purchaser when the Purchase Price has been paid in full. Supplier shall in respect of the Products retain any right of security for unpaid purchases as applying under Section 3-14 et seq. of the Norwegian Mortgages and Pledges Act (act no. 2/1980). Risk for loss of or damages to the Products shall pass from Supplier to Purchaser upon delivery as set forth in Article 3 hereof. All commercial and technical information, such as professional secrets, specifications, descriptions, procedures, models, operational data etc. pertaining to a party (the Disclosing Party) which the other party have gained access to in connection with the Contract, shall be treated as confidential and shall not be disclosed to any third party without the prior written consent of the Disclosing Party. Such consent shall not be unreasonably withheld. Such information must not be duplicated and may not be used other than as expressly permitted by the Contract. Subject to the provisions of Article 13, Purchaser shall be liable for any losses suffered by Supplier as a consequence of breach of this Article 15. Neither Party may disclose information about the signing, termination or content of contracts between the Parties without the prior written consent from the other Party. 16 ASSIGNMENT Supplier may assign its rights and obligations under the Contract, wholly or partly, to any third party, subject to giving Purchaser prior written notice thereof. 17 GOVERNING LAW AND DISPUTES The Contract shall be governed by and construed in accordance with the laws of Norway. Any disputes that may arise from the Contract shall be subject to the exclusive jurisdiction of the Norwegian courts, with Stavanger city court as agreed venue. \ 0 « I « c c e c c f: tJ Cl t:! c:i Cl Page 15 (jenerai i erms tor bale OT Kroduas and services - rev. uciober zwd 8 Contact information Place Orders and Address Correspondence to: Zeropex AS Head of Business development Per Reidar 0rke Phone +47 909 76 415 Email: pro(gizeropex.com Zeropex AS VP Sales & Marketing North America Sven Anden Phone:+1 (248) 644 0011 Email: sa(gxeropex.com Page 16 0 i_ Q. £ o 0 o Q. 0 i_ CL X cu Q. O Q5 N Ui E o X i a O o o N J2 , , •••• o c n 0 < CQ o o c o o X Q) CL O a3 N % (0 Q. E o I"- V e 3 O < • CD O a o 3 O CD c o o CM •o CD C/) CD O) <^ LJJ 0 C LU . 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CO c o CO c 0 E 0 0 =5 3 CO CO CO CO 2 2 CL Q. vei ea CO '+-' -1—» CL O) c lO i_ E 0 0 -+-» O ro IT) 0 -+-» SI IT) ffe CD $ C3) i_ CO \— CD $ C3) ba X 0) "O 0 ikin CO ro lO CD LO CO CO b h- Q I I I C I I I I t t I X CD Cl O OJ N C C 0) Q ••< • X 0) .. . OK: 0) : i N ^-i 0 i— 3 -+-» O CO CD E O) _g o c o 0 -t—» 0 0 -4—' CD Cl 0 3 "c 3 D) .E x 0 E x: o 3 •o O 0 o Cl 0 XI CD c UJ o CD XI >^ CD Q. tl O CO o >> CD CL < CO Z) .E c _o TO TO to .E to i_ Li_ •••4 CO 0 X CO :| ^ i CD CD % CL Cl "D 1 O ^^^^ E .^i o ^ -s 0 'li g i N Q. I 0 ••1 3 CL Technical Memorandum APPENDIX C - SDG&E RATE TARIFF April 2010 pw:«CafDlta/DocujnentsJCfent/CWCarM«tl'8362A1Q'De)w Revised Cai. P.U.C. Sheet No. 20429-E San Diego Gas & Electric Company San Diego. California Cane ellng Original Cal. P.U.C. Sheet No. 2Q150-E SCHEDULE WATER Sheet 1 WATER AGENCY TARIFF FOR ELIGIBLE RENEWABLES APPLICABILITY Pursuant to Public Utilitie s Code (PU Co de) Se ction 399.20 and Commi ssion De cision 07-0 7-027, this Schedule is optionally available lo customers who meet the definition of an Eligi ble Public Water Agency or Wastewater Agency, as defined in Special Condition (SC) 3a and 3b below, who own and operate an Eligible Renewable Generating Facility, as described in SC 3c, with a total effective generation capacity of not more than 1.5 megawatts (MWs). Service under this Schedule is on a first come, first served basis and shall be closed to new customers once the combined rated generating capacity of Eligible Renewable Generating Facilities within SDG&E's service territory rea ches 2 0.055 MW which is SDG&E's share of the statewide 2 50 MWs, ba sed on the rati o of SDG&E's peak demand tothe total peak demand of all electrical corporations within the State of California, as described in SC 5 below. TERRITORY Within the entire territory served RATES The customer's otherwise applicable tariff shall apply except as follows: SDG&E shall purchase the total output produced by an Eligible Renewable Generating Facility under Option A (Full Buy/Sell) or Option B (Sale of Excess Only) at a rate equal to the Market Referent Price (MPR), as determined bytheCalifo mia Public Utilities Commi ssion pursuant to PU Co de Se ction 3 99.15, that i s applicable on the effective date of the Agreement, subject to th e on -line date and t erm specified i n the Agreement (Form 160-1000). SPECIAL CONDITIONS 1. Agreement: An executed Agreement (Form 160-1000) is required prior to receiving service under this Schedule. 2. Participation in other SDG&E Prcxirams: Customers participating under the provisions of this Schedule may not participate in an y other SDG &E inten-upti ble. Self Generatio n Ince ntive Progra m (SGIP), California Solar Initiative, net energy metering program, or other similar programs. 3. Definitions: The following definitions are applicable to service provided under this Schedule. a. Eligible Public Water Agency-As defined in Water Code Section 12970, means any public corporation, district, political subdivision, or any other agency or authority now or he reafter organized under the laws of this state which develops, stores, distributes or supplies water. b. Eligible Wastewater Agency - Any state, local, or federal agency, as defined in Water Code Section 13625 (b)(1), owning a facility use d in the treatme nt or reclam ation of sewage o r industrial wastes. (Continued) N N 1Cie Issued by Date Filed Feb 22,2008 Advice Ltr. No. 1918-E-A Lee Schavrien Effective Feb 14,2008 Senior Vice President Decision No. Regulatory Affairs Resolution No. E-4137 Revised Cal. P.U.C. Sheet No. 20430-E* San Diego Gas & Electric Company San Diego, Califomia Cane eiing Original Cal. P.U.C. Sheet No. 20151-E SCHEDULE WATER WATER AGENCY TARIFF FOR ELIGIBLE RENEWABLES Sheet 2 SPECIAL CONDITIONS Definitions (Continued) c. Eligible Renewable Generating Facility - A generating facility that is owned and operated by an Eligible Public Water Agency or an Eligible Wastewater Agency which receives distribution service from SDG&E, and where the Eligible Renewable Generating Facility meets al! of the following criteria: (1) Has an effective capacity of not more than 1.5 MWs and the facility is located on property owned or under the control of the public water or wastewater agency. (2) Is interconnected and operates in parallel with the Utility's electric transmission and distribution grid. (3) Is strategically located and interconnected to the Utility's electric transmission system in a manner that optimizes the deliverability of electricity generated at the facility to load centers. (4) Is an eligible renewable energy resource, as defined in Public Utilities Code Section 399.12. Metering Requirements: Cu stomers served o n th is Sched ule shall be separately mete red with SDG&E's m etering to reflect the n et generatio n output am ounts of the Eligible Re newable Generating Facility. Customers shall be responsible fo r all costs associat ed with separately metering the customer's Eligible Renewable Generating Facility output and assctciated station load. All metering required for service on this Schedule shall be installed and maintained in accordance with SDG&E's requirements. Customer Participation: Except a s provided below, customers may participate in acco rdance with this Sched ufe until the sum of all customers' contracted capacity reaches SDG&E's proportionate share of the statewide capacity limit of 250 MW. SDG&E has been allocated 20.055 MW ofthe capacity limit. The sum of all customers' contra cled capacity will be calculated by the summation of all net powe r ratings (in kW) p rovided in Fo rm 160-1000. Shoul d additional customers express interest in this Schedule after SDG&E's share ofthe contract capacity limit is reached, SDG&E will maintain a list of Interested oust omers, ranked in order ofthe date on which they requested service under this Schedul e. Should the cap acity installed fall below 2 0.055 MW, SDG&E will allow thos e customers from the previously described list of int erested customers who remain interested in the tariff the opp ortunity to pa rticipate under this Sc hedule on a first come, first served b asis until the capacity installed plus the contracted capacity taken from the previously described list of inte rested customers equals 20.055. This proce sswill continue until su ch time a s the installed capacity of projects in operation does not exceed 20.055 which is SDG&E's proportionate share of 250 MW. SI 2C21 Advice Ltr. No. 1918-E-A Decision No. Issued by Lee Schavrien Senior Vice President Regulatory Affairs Date Filed Effective Feb 22, 2008 Feb 14, 2008 Resolution No. E-4137 Technical Memorandum APPENDIX D - PREFABRICATED CONCRETE BUILDING PRODUCT DATA April 2010 pw://Cardk)/Documents/ClienUCA/C8rlsbad/8362A10/Deliverables/Carisl3ad_TM (RevisedFinal) Oldcastl^ strength you can count on Shelters Precast toncfete Shelters Up to 600 sf jldcastle shelters are the answer to your most difficult equipment enclosure requirements for wireless, cable and telephone service providers. Made from steel reinforced precast concrete, these enclosures are designed to provide secure housing for your equipment whatever the seismic requirements, floor, roof or wind load. With short lead times and rapid installation on a foundation or gravel base, our shelters are the economical solution to your rapid national deployment enclosure needs. Utilizing both monolithic and panel construction methods, designed for both single and doublewide applications, some configurations include multi-room, stackable and partially buried units. Co-Location Shelters Our shelters are available in a variety of dimensions to fit many co-location options such as private keying, individual cages and security features. They can be factory equipped for immediate use after a quick installation and hook up. Benefits and Design Features O Sizes available up to 600 sf O Rapid national deployment O Multiple exterior and roof O Maintenance-free finish designs available www.oldcastlecomm.com 1-877-434-5463 Oldcastle' strength you can count on Contract Holder © 2007 Oldcaslle Precast Inc. OC104 2/07 OOOO Precast Communications www.oldcastlecomm.com P.O. Box 3250 Phone{602)228-3499 Ctiandler, AZ 85244-3250 Mike.evans@oldcastleprecast.com Date: 02-17-10 Company:Carollo Engineering Address: 9115 Harris Corners Pky. Suite 440 Charlotte, NC Contact: Christoptier Crotwell PE Contact Phone:704-598-0918 Re: Oldcastle t\flodel1818 Precast Concrete Shelter Project:Carisbad Merco Reservoir Location:Carlsbad, CA 92010 Qwofe 32-1197 1818RCS Carlsbad 02-17-10 Dear Christopher. Oldcastle ispleased to provide this quote for our Model 1818 Monolithic Shelter for Carisbad Merco Reservoir Please read the scope and quote carefully only items included on this quote will be provided by Oldcastle. If you would like to include any additional equipment let me know and we will quote it. Let me know if you have any questions. Sincerely, Western Region Sales Oldcastle Precast Communications Enclosures: Scope of Work. Terms and Conditions, Pricing 12004 f g e I. Precast Structure A. Structure Engineering Drawings: • State Approvals; Precast Communications iQuofe 32-1197 I818RCS carisbad 02-771 SCOPE OF WORK - 1818RCS Detailed engineering and drawings provided for all items in this Scope of Wortt. The structural drawings will be stamped by a professional engineer registered in the state of building placement. Oldcastle will receive state approval as required. As such, Oldcastle reserves the right to amend the proposed Scope of Work to comply with any code or regulation required to oblain state approval. • Scope and Pricing Exclusions: The following items are also excluded and need to be provided by others: 1) Site Preparation 2) Foundation 3) Crane services to offload at the job site 4) Soil Report 5) Evaluation of geotechnical survey 6) Attachment to foundations. (Parts and instructions supplied) 7) Grouting / Coating of roof lifting pockets (Parts and instructions supplied) 8) Taxes 9) Freight (unless specified) 10) Local/municipal inspections and appmvls: • site inspections • building permits • zoning approvals Oldcastle is not responsible for determining such local requirements. Oldcastle is not responsible for determining such local requirements. 1. Precast Structure A. Structure Engineering • Drawings: • State Approvals: • Exclusions: Detailed engineering and drawings provided for all items in this Scope of Wori<. The structural drawings will be stamped by a professional engineer registered in the state of building placement. Oldcastle will receive state approval as required. As such, Oldcastle reserves the right to amend the proposed Scope of Woric to comply with any code or regulation required to obtain state approval. Local/municipal inspections and approvals, including site inspections, building permits, and zoning approvals (except as discussed herein) are not included. Oldcastle is not responsible for determining such local requirements. Page 2 of 8 Initial: e Precast Communications {Quote32-1197 ISISRCS carisbad 02-77-4 El B. Precast Concrete Shell • Size (1) 1818 RCS Lightweight Concrete Shelter Outside Dimension - 18'-0" long x 18'-0" Wide x 10'-1" High Finished Inside Dimension -17'-0" Long x 17'-0" Wide x 9'-0" High • Weight: Approximate finished weight: 76,000 pounds (2) pes. @ approx. 38,000 ea. • Specifications: Floor load; 250 PSF Roof load: 65 PSF Wind load: 110 MPH, Exp "C" • Seismic Zone: 50-185%G • Fire Rating: Two hour • Bullet Resistance: UL 752 Level 4 C. Finishes • Exterior Walls; Simulated Exposed aggregate • Interior Walls: None • Insulation: None • Telco Board: None • Floor: None • Roofing: Elastomeric coating D. Doors and Openings • Doors: (1) 3'-0" x 7'-0" 18 gauge steel door with 16 gauge steel frame • Locks: Best lockset with Best Z1 Core • Other Door Hardware: NRP Stainless steel hinges, door closure, door pick plate, door holder, weather strip, aluminum threshold. • Door Hood: Door drip cap - 2 Vi" wide; Door Canopy - 8" x 48" • Roll up Door (1)8' 0' roll up door chain manual operated. • Coax Port: None E. Power • Power Service: None • Disconnect Switch: None; to be supplied by customer • Generator Receptacle: None • Manual Transfer Switch; None • Main Distribution Panel: None • Surge Suppression: None • Convenience Outlets: None • Exterior GFl Outlets: None F. Environmental System • HVAC: None • Controls: None • Thermostat: None G. Alarms • Alarms: None H. Lighting Page 3 of 8 Inrtial: i < tf ll i( li II I! II I! II II II IJ e Precast Communications louote 32-1197 ISIBRCS cansbad 02-iT\ Interior: None Exterior; None Emergency; Noen Switches: None Timer: None Cable Ladder Cable Ladder: None Grounding Ground Bar: None Grounding: None Additional Items Smoke Detector: None Fire Extinguisher: None Log Book: None Tie Down Kit (1) Set First Aid Kit: None Eye Wash Station; None Battery Safety Kit: None Exhaust Fan: None Other: None II. Delivery A. Precast Structure price is quoted FOB Plant B. The delivery price quoted is fo the indicated location only and is only good for 120 days from the date herein C. Delivery to occur on weekdays during normal daylight working hours D. Proper site conditions, including clear access roads and a reasonably level surface, so that vehicles, trucks, and cranes can safely maneuver under their own power. i. All roads, crossing, and load bearing surfaces to be able to accommodate a vehicle with a gross weight up to 160,000 pounds, il. Required turning radius for up to a 70-foot tractor-trailer and up to a 150-ton crane, iil. No overhead power lines, obstructions or overhanging trees that could block the maneuverability of equipment. III. Services A. The following Items are excluded and need to be provided by others I. Overall project management and on-site supervision II. Real estate services iii. Site design and permitting and obtaining building codes iv. Site work, fencing and landscaping V. On-site soils investigation and foundations vi. On-site electrical and mechanical a. Utility transformer (confirmation of phase and type of electrical service), transformer pad / pole, right of way work, boring / street excavation and duct bank work, meter base installation and all final electrical connections b. External grounding systems Page 4 of 8 Initial: e Eg Precast Communications louofe 32-1197 I818RCS carisbad 02-771 c. Sewer and water work, if needed vii. Crane and rigging services and off-loading of the structure viii. Assembly and tie-down of the structure on-site ix. Electronic equipment integration X. On-going repair and maintenance and upgrades B. If needed, Oldcastle can provide some or all of these services as part of a turn-key installation HI. Crane Service: A. Not Included IV. Field Setting Service: A. Not Applicable B. A detailed installation manual will be provided and explained prior to delivery. Page 5 of 8 Initial: Technical Memorandum APPENDIX E - PRELIMINARY COST ESTIMATES April 2010 pw:/;Carollo/[)ocumentsyClrent/CA/Carlst>ad/8362A10/De)iverables/Carisbad_TM (Revised^ PRELIMINARY CONCEPTUAL COST ESTIMATE Hydroelectric Turbine Facility Carlsbad Municipal Water District, Carlsbad, CA CAROLLO PROJECT # 8362A10 FACILITY: Hydroelectric Turtnne Building - At^mative No. 1:2.2 cfs turbine Description Unit Quantity Unit Cost Total Cost General Requiremente Mobilization/Demobilization LS 1 $10,M0.00 $10,000.00 Earthwork Erosion Control LS 1 $2,000.00 $2,000.00 Miscellaneous Sitework LS 1 $5,000.00 $5,000.00 Drainage LS 1 $3,000.00 $3,000.00 Grading/Excavation LS 1 $5,000.00 $5,000.00 Finish Grading LS 1 $2,500.00 $2,500.00 Site Piping & Miscellaneous Yard Piping LS 1 $60,000.00 $60,000.00 Miscellaneous Site Water Lines LF 200 $50.00 $10,000.00 Disinfection & Testing LS 1 $2,000.00 $2,000.00 Concrete Precast Building (16.5 x 16.5) LS 1 $26,875.00 $26,875.00 Base Slab CY 11 $450.00 $5,055.75 Walls CY 15 $550.00 $8,360.00 Walkwavs/Misc/Stairs CY 2 $600.00 $1,200.00 Metals Stnjctural Steel LS 1 $7,500.00 $7,500.00 Handrails & Railings LF 25 $75.00 $1,875.00 Miscellaneous Metals(FRP) LS 1 $3,000.00 $3,000.00 Finisiies Painting LS 1 $500.00 $500.00 Equipment Hydroelectric Turbine EA 1 $78,000.00 $78,000.00 Mechanical Process Piping and Valves( Interior) LS 1 $30,000.00 $30,000.00 HVAC LS 1 $10,000.00 $10,000.00 Electrical Electrical and Instrumentation LS 1 $165,000.00 $165,000 SCADA Connection LS 1 $35,000.00 $35,000 Subtotal $471,866 Contractor Overhead and Profit (15%) $70,780 Subtotal $542,646 Contingency (20%) $108,529 Estimated Capital Cost $650,000 Engineering Less Study $374,426 Owner Reserve for Change Orders (5%) $32,500 TOTAL $ 1,060,000 Carollo Engineers PrelimCostEstimate-Car1sbad.xls 12/7/2009 8362A10 PREUMINARY CONCEPTUAL COST ESTIMATE Hydroelectric Turbine Facility Carlsbad Municipal Water District, Carlsbad, CA CAROLLO PROJECT # 8362A10 FACILITY: Hydroelectric Turbine Building - Alternative No. 2:5.4 turbine Descnption Unit Quantity Unit Cost Total Cost General Requirements Mobilization/Demobilization LS 1 $10,000.00 $10,000.00 Earthwork Erosion Control LS 1 $2,000.00 $2,000.00 Miscellaneous Sitework LS 1 $5,000.00 $5,000.00 Drainage LS 1 $3,000.00 $3,000.00 Grading/Excavation LS 1 $5,000.00 $5,000.00 Finish Grading LS 1 $2,500.00 $2,500.00 Site Piping & Miscellaneous Yard Piping LS 1 $60,000.00 $60,000.00 Miscellaneous Site Water Lines LF 200 $50.00 $10,000.00 Disinfection & Testing LS 1 $2,000.00 $2,000.00 Concrete Precast Building (16.5 x 16.5) LS 1 $26,875.00 $26,875.00 Base Slab CY 11 $450.00 $5,055.75 Walls CY 15 $550.X $8,360.00 Walkways/Misc/Slairs CY 2 $600.00 $1,200.00 Metals Structural Steel LS 1 $7,500.00 $7,500.00 Handrails & Ratlings LF 25 $75.00 $1,875.00 Miscellaneous Metals(FRP) LS 1 $3,000.00 $3,000.00 Finishes Painting LS 1 $500.00 $500.00, Equipment Hydroelectric Turbine EA 1 $99,645.00 $99,645.00 Mechanical Process Piping and Va)ves( Interior) LS $30,000.00 $30,000.00 HVAC LS $10,000.00 $10,000.00 Acoustical Panels DIVISION 16 Electrical $2,000.00 $2,000.00 Electric^ and Instrumentation LS $165,000.00 $165,000 SCADA Connection LS $35,000.00 $35,000 Subtotal $495.511 Contractor Overhead and Profit (15%) $74,327 Subtotal $569,837 Contingency (20%) $113,967 Estimated Capital Cost $680,000 Engineering Less Study $374,426 Owner Reserve for Change Orders (5%) $34.000 TOTAL 1.090.000 Carollo Engineers PrelimCostEstimate-Carisbad.xls 12/7/2009 8362A10 Technical Memorandum APPENDIX F - ECONOMIC ANALYSIS April 2010 pw://Carollo/Docu[nente/Clieni;CA/Carlsbad/836M10/DeliveraMes/Carisbact_TM [RevisedFinal) Client: Carisbad Municip^ Water District Project: Hydroelectric Turtiine at Maerl<le Reservoir By: CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job*: 8362A10 Alternative No. i Turbine NPV Analysis =input Commenis: Turbine Flow 5.4 cfs = 3.5 mod Number of Turbities 1 each Turbine Eff 0.7B5 Generalof btf 0.S3 Head Differential 300 fl = 130 psi Generalof Power 100 kW 134 hp REC Revenue U.04 SftWhr (H ustna Feed in Taiff. EDGE dalms REC's) Total Hours/vr 8760 hrs Adequate Flow Available 86.1% % (based on filslorical flow) Avail^litv 55% % In Service Hours/yr - TURBINE 1 7165 hrs In Service Hours/vr - TURBINE 2 0 his O&M Rale SO.OI S/kWfir Base Rale S0.0S84 S/kWhr Based on SDGE MPR Schedute tor 10 year contract (2011) Percent of Annual Hours On Peak Rale Summer (year 1) $0.1451 WMv Based cn SDGE TOD Periods 7% On Peak Rale Winter (vear 1) $0.1054 S/kWhr Based on SDGE TOO Periods 16% Semi-peak Summef (year 1) $0.0920 $/kWhr Based on SDGE TOD Perkxh 7% Semi-peak Winter [year 1) $0.0954 S/kWhr Based on SDGE TOO Periods 16% Off Peak Rate Sunvner (vear U $0.0781 S/kWhr Based on SDGE TOO Periods 16% Ofl Peak Rate VVinler (year 1) $0.0701 S/kWfir Based on SDGE TOD Penods 37% Average Rate $0.0881 (weighted avq) Inflatnn (elect and REC) 5.0% (used to catc MPR rate tor 2nd 10 vr contract) lnflatKxr(0&M) 3% Revenue from Elect Bill Net Meier $29,000 (based on MaeiUe Reservoir 2009 partial elect biUs: eibE^iolated tor 12 mos) hJel Meter Ei>erc)y 165.000 kWhrs (based on Maerkle Reservoir 2009 partial elect bils; extrapolaled for 12 mos) Discount Rale 4.5% (Based on letter from CMWD, Respofise to Request for Informafion. dated 10/1/2009) Proiecl Capital C^| $ 1,090.000 (input protect cost for payback period calc) 20 yr Net Present Value $ 290.318 NPV Pavlwck Period 15.8 vears Annual kWhrs Power Anr)U3l tutinus Net Elect Sell Derrtand REC Net Meter Year Produced Operatinq Hours Annual kWhrs Meter kWhrs Rate Flevenue Savings Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs S/kWhr S $ S $ $ s 0 £ (1,090,000) 0 1 100 7165 715,911 550,911 0.0881 $ 48.540 $ 6,600 S 29,000 s (7.159) $ 76.981 $ (1,016,334) 1 2 100 7165 715,911 550,911 0.0881 s 48,540 $ 6,930 S 30,450 £ (7.374) $ 78.546 S (944,407) 2 3 100 7165 715,911 550.911 0.0881 s 48,540 s 7,277 s 31.973 $ (7,595) S 60,194 $ (874,133) 3 4 100 7165 715,911 550,911 0.0881 $ 48,540 $ 7.640 I 33,571 $ (7,823) s 81,929 £ (805.430) 4 5 100 7165 715,911 550,911 0.0881 s 48.540 s 8,022 $ 35,250 S (8,058) I 83.755 £ (738.221) 5 6 100 7165 715,911 550,911 0.0881 s 48.540 s 8,423 t 37.012 s (8,299) s 85.676 £ (672431) 6 7 100 7165 715,911 550,911 0.0881 s 48,S40 5 8.845 s 38,863 s (8,548) $ 87.699 £ (607,987) 7 3 100 7165 715,911 550,911 0.0881 s 48,540 S 9.287 I 40.806 $ (8.805) £ 89,828 £ (544,821) 8 9 100 7165 715,911 550,911 0.0881 s 48,540 $ 9.751 42,846 £ (9.069) $ 92,069 S (482,868) 9 10 100 7165 715,911 550,911 0,0881 s 48.540 $ 10,239 44,989 £ (9.341) $ 94.427 £ (422.064) 10 11 100 7165 715,911 550,911 0.1435 s 79,067 $ 10,751 47,238 £ (9,621) $ 127,434 $ (343,539) 11 12 100 7165 715,911 550.911 01435 s 79,067 $ 11,288 £ 49,600 £ (9,910) $ 130.045 £ (266,856) 12 13 100 7165 715,911 550.911 0.1435 s 79,067 $ 11,853 £ 52,080 $ (10.207) $ 132,792 (191,925) 13 14 100 7165 715,911 550,911 0.1435 s 79,067 s 12,445 £ 54,684 £ (10,513) S 135,683 £ (118.660) 14 15 100 7165 715,911 550,911 0.1435 s 79.067 $ 13,068 S 57.418 S (10,829) S 138,724 £ (46,979) 15 16 100 7165 715,911 550,911 0-1435 s 79,067 s 13,721 S 60,289 S (11.154) £ 141,923 £ 23,198 16 17 1£?0 7165 715,911 550,011 0.1435 $ 79,067 s 14.407 s 63,303 3 <11.4B8) $ 14S.289 S 91,945 17 18 100 7165 715.911 550,911 01435 $ 79,067 s 15.127 £ 66,469 £ (11,833) $ 148,830 $ 159,335 18 19 100 7165 715.911 550,911 0,1435 s 79.067 $ 15,884 £ 69,792 £ (12.188) s 152,555 £ 225,438 19 20 100 7165 715,911 550,911 0.1435 $ 79,067 $ 16,678 £ 73,282 £ (12.554) s 156.473 S 290,318 20 TOTAL 14,318,220 572729 143182 5 2.260,852 Carollo Engineers 2/16/2010 Car1sbadHydro_NPV_rev1 .xls 5.4 NPV Client: Car1st}ad Municipal Water DislrKl Project: Hydroelectric Turbine al Maerkle Reservoir By: CTC [}ate Createc<: 10/30/2009 PtmledDale: 2/16/2010 Job #; 8362A10 Wtemative Wo. la Turbine NPV Analysis with AB 2466 (wheeling) =input Convnents: Turbine Ftow 5.4 cfs = 3.5 mgd Number of T Jibmes 1 each Turbine Eft 0.785 Generator Eft 0.S3 Head Differential 300 fl = IX psi Generator Power 100 kW 134 hp REC Revenue $0.04 £/kWir (if using Feed In Tanff. SDGE claims REC's) Total Hows/yf 8760 hrs Adequate Fto* Available 86% % (based on historical ftow) AvailabiHIv 95% % In Service Hours/yr - TURBINE 1 7157 hrs In Sen/ice Hours/yr - TURBINE 2 0 hra O&M Rate £0.01 £rtmr Summer Peak Demand Charge $13.77 Winter Peak Uemand Charge $4.77 Coincident Demand Charge $11.53 Base Rate $/kWhr Based on SDGE MPR Schedule for 10 year contract (2011) Percent Of Annual Hours On Peak Rate Summer (year 1) £AWhr Based on SDGE TOD Perwds 7% On Peak Rale Winter (vear 1) $/kVWtr Based on SDGE TOD Periods 16% Semi-peak St'mmer (year 1) £/kWhr Based on SDGE TOD Penods 7% Semi-oeak Winter (year 1) £/kWt¥ Based on SDGE TOD Penods 16% Off Peak Rate Summer (year 1) £/kWhr Based on SDGE TOD Peikids 16% Off Peak Rate Winter (year 1) $/kWhr Based on SDGE TOD Periods 37% Average Rale $0.0966 See 'AL-TOU Rates' for elect rates Inflation (elect and REC) 5.0% %/¥T (used to cak: MPR rale for 2nd 10 yr contract) Inflatkxi (O&M) 3% Revenue fnam Elect Bill Net Meier $0 (based on Maertde Reservoir 2009 partial elect twHs; extrapolaled lor 12 mos) Net Meier Energy 0 kWhrs (based on Maerkle Resenrcir 2009 partial elect bdls: extrapolated for 12 mos) Discount Rate 4.5% (Based on letter from CMWD, Re^xxise lo Request for InlonnatiOT, dated I0/1/3009I Projecl Capital Cost $ 1,090,000 (input project capital cost for payback period calc) 20 yr Net Present Value £ 1.145,441 NPV Payback Period 9.8 years 1 Annual kWhrs Demand Power Annual Minus Net Elect Sell Savings REC Net Meter Year Produced Operating Hours Annual kWhrs Kteter kWhrs Rate (2) Revenue (1 Revenue orrsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWfirs WMn £ $ E £ S $ 0 1 100 7157 715,060 715.080 £0 0966 $ 69.070 £ 19,883 $ 28.603 £ £ (7,151) £ 110.406 £ £ (1,090,000) (964.349) 0 1 2 100 7157 715,080 715.080 £0.1014 £ 72,524 $ 20.877 £ 30,033 £ £ (7,365) £ 116.069 £ (878,061) 2 3 100 7157 715.080 715,080 £0.1065 £ 76,150 $ 21.921 £ 31,535 $ £ (7,586) S 122.020 £ (771.135) 3 4 100 7157 715.080 715,080 $01118 £ 79,958 S 23.017 £ 33,112 $ £ (7,814) S 128,272 £ (663,571) 4 5 100 7157 715,080 715,080 10.1174 £ 83,955 s 24,168 $ 34,767 £ (8,048) $ 134.842 S (555,366) 5 6 100 7157 715.080 715,080 5 0.1233 £ 88,153 £ 25,376 £ 36,506 £ (8,290) £ 141.745 £ (446,521) 6 7 100 7157 715.080 715,080 $0.1294 £ 92,561 £ 26.645 £ 38,331 £ S (8,538) £ 148,999 S (337,032) 7 8 100 7157 715,080 715.080 £0,1359 $ 97,189 £ 27,977 $ 40,248 $ £ (3,795) £ 156,619 $ (226,900) 8 9 100 7157 715.080 715,080 £0,1427 $ 102,048 £ 29,376 £ 42,260 $ £ (0,058) £ 164,626 £ (116,122) 9 10 100 7157 715,080 715,080 £0.1498 $107,151 £ 30.845 £ 44,373 $ $ (9,330) $ 173,039 $ (4,698) 10 11 100 7157 715.080 715,080 £0.1573 $112,508 £ 32,387 £ 46,592 £ £ (9,610) S 181.877 $ 107,374 11 12 100 7157 715.080 715,080 £01652 £116.134 £ 34,007 £ 48,921 s £ (9,898) S 191,163 $ 220,096 12 13 100 7157 715.080 715,080 $0.1735 £ 124,040 S 35,707 S 51,367 $ £ (10,195) S 200,919 $ 333,469 13 14 100 7157 715,080 715,080 £0.1821 $ 130.242 s 37,492 s 53,936 £ S (10,501) S 211,169 S 447,495 14 15 100 7157 715,080 715,080 £0.1912 $ 136,755 s 39,367 s 56.632 £ $ (10.816) £ 221,938 $ 562.175 15 16 100 7157 715,080 715,080 £02008 £143,592 s 41.335 £ 58,464 £ £ (11,141) $ 233,251 £ 677,510 16 17 100 7157 715,080 715,080 £ 0.2108 $150,772 s 43.402 £ 62,437 £ £ (11,475) $ 245,136 £ 793,503 17 18 100 7157 715,080 715,080 S 0.2214 £158,311 £ 45,572 $ 65,559 £ £ (11,819) $ 257,622 £ 910,154 18 19 100 7157 715,080 715,080 S 0.2325 £166,226 £ 47.851 $ 66,837 £ £ (12,174) $ 270,740 £ 1.027,466 19 20 100 7157 715.080 715.080 5 0 2441 $174,537 £ 50,243 $ 72,279 £ £ (12,539) $ 284,520 $ 1,145,441 20 TOTAL 14,301.590 572064 143016 $ 3,694,974 Carollo Engineers CarisbadHydro_NPV_rev1 .xls 5 4NPV Ae2466 Client: Carlsbad Municipal Water District Project: Hydroelectric Turbine at Maerkle Reservoir By: CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job*: e362A10 Alternative No. 2 Turbine NPV Analysis =input Comments: Turbine Fkw 2.2 cfe = 1.4 mqd Number of Turtwnes 1 eacti Turbine Eff 0.75 Generator Eff 0.S5 Head Oifrerontial 300 ft = 130 psi Generator Power 36 kW 48 hp REC Revenue $0.04 SfltWhr (if usirw Feed in Tariff, SDGE daims REC's) Total Hours/yr 8760 hrs Adequate FlowAvail^e 96LD% % (based on histork:al flow) Availability 95% % In Service Hours/yr - TURBINE 1 7989 hrs In Service Hours/yr - TURBINE 2 0 hrs O&M Rate $0.01 $/kWhr Base Rate $0MS4 $/kWhr Based on SDGE NPR Schedule for 10 year conltact (2011) Percent of Annual Hours On peak Rate Summer (year 1) S0.1451 $/kWhr eased on SDGC TOO Perwds 7% On Peak Rate Winter (year 1) $0.1054 S/kWhr Based on SDGE TOD Perkxls 16% Semi-peak Summer (year 1) $0.0920 WtWhr Based on SDGB TOD Peiiods 7% Semt-peak Winter (year 1) £0.0954 $/kWhr Based on SDGt TOD Perk>ds 16% Off peak Rale Summer (year 1) $0.0781 JAWhr Based on SDGE TOD Periods 16% Off peak Kate Winter (year 1) $0i>701 $/kWhr Based on SDGE TOD Perkjds 37% Aveisge Rale $0.0681 (weighted a^K)) Inflafion (elect and REC) 5.0% %/vr (used to cak: MPR rate for 2nd 10 yr contract) Inflation (O&M) 3% Revenue from Elect Bill Net Meter $29,000 (based i>n Maerkle Reservoir 2IX)9 partial elect biHs extrapolated for 12rnos) Net Meier Enerqy 165.000 kWtirs (based on Maerkle Reservoir 2009 partiai elect bills: extrapolated for 12 mos) Discount Rale 4.5% (Based on letter from CMWD. Response to Request fO( Informatkm, dated 10/1/2009) Project Capital CosI $ 1,060.000 (mpol prciecl c^al cost lof pa^tiack period calc'> 20 yr Net Present Value $ (224.369) NPV Payback Period 25.4 years Annual kWhrs PovKr Annual Minus Net Elect Sell Demand REC Net Meter O&M Year Produced Operating Hours Annual kWhrs Meter kWhrs Rate Revenue Savinqs Revenue Offsets Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs $/kWhr $ £ £ £ S £ 0 $<1.060,000) 0 1 36 7989 283,977 118,977 0.0881 $ 10,483 £ 6,600 £ 29,000 S (2,840) $ 43,243 $(1,018,619) 1 2 35 7989 283,977 118,977 0.0881 $ 10.483 $ 6,930 $ 30,450 $ (2,925) $ 44,938 £ (977,468) 2 3 36 7989 283,977 118,977 0.0881 $ 10,483 £ 7,277 £ 31,973 S (3,013) $ 46,719 $ (936,528) 3 4 36 7989 283,977 118,977 0.0881 $ 10,483 £ 7,640 S 33,571 £ (3.103) £ 48,591 $ (895,781) 4 5 36 7989 283 977 118,977 0.0881 £ 10,483 $ 8,022 S 35,250 £ (3,196) $ 50.559 S (855.210) 5 6 36 7989 283,977 118,977 0.0881 £ 10,483 £ 8,423 $ 37,012 $ (3,292) S 52,627 $ (814.798) 6 7 35 7989 283,977 118.977 0,0881 $ 10,483 $ 8,845 $ 38,863 S (3,391) $ 54,800 £ (774,530) 7 8 36 7989 283,977 118,977 00881 £ 10,483 $ 9,287 £ 40,806 $ (3,493) S 57,083 £ (734,390) 8 9 36 7989 283,977 118.977 0,0881 S 10.483 $ 9,751 £ 42,846 S (3.597) S 59,483 £ (694,364) 9 10 36 7989 283,977 118,977 0.0881 $ 10,483 £ 10,239 £ 44.989 $ (3,705) $ 62,005 £ (654,437) 10 11 36 7989 283,977 118,977 01435 S 17,076 £ 10,751 $ 47,238 S (3,816) $ 71,248 $ (610,534) 11 12 36 7989 283,977 118,977 0.1435 £ 17,076 £ 11.288 $ 49,600 $ (3,931) $ 74,033 £ (566,880) 12 13 36 7989 283,977 118.977 0.1435 £ 17.076 $ 11,853 $ 52,080 $ (4,049) $ 76,959 £ (523,454) 13 14 36 7989 283.977 118.977 0,1435 $ 17,076 £ 12.445 3 54,684 £ (4,170) £ 80,034 $ (480,237) 14 15 36 7989 283,977 118,977 0.1435 £ 17,076 $ 13.068 £ 57,418 $ (4,295) $ 83,266 £ (437,212) 15 16 36 7989 283,977 118,977 0.1435 $ 17,076 $ 13.721 $ 60,289 S (4.424) S 86,661 $ (394,361) 16 17 36 7989 283,977 118.977 0.1435 S 17.076 $ 14,407 £ 63,303 S (4.557) S 90,229 £ (351.667) 17 18 36 7989 283,977 118,977 0.1435 $ 17,076 £ 15,127 £ 66,469 $ (-1.694) S 93.978 $ (309,113) 18 19 36 7989 283,977 118,977 0.1435 $ 17,076 £ 15.884 S 69.792 S (4,835) $ 97,917 £ (266,686) 19 20 36 7989 283,977 118.977 0.1435 $ 17,076 £ 16,678 S 73,282 $ (4,960) $ 102.056 $ (224,369) 20 TOTAL 5.679,546 227182 56795 $ 1,376.429 CaroDo Engiiwers 2/16^)10 l^rlsbadHyclro„NPV_rev1 xls 2 2 NPV Client: Carlsbad Municipal Water District Project: Hydroelectric Turbine at Maerkle Reservoir By: CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job#: 8362A10 Alternative No, 3 Turbine NPV Analysis =input Comments: Tufbirie Flow 3.5 cfs = 2,3 mqd Number of Turbines 1 each Turbine Eff 0.8 Generator Eff 0.93 Head Differential 300 fl = 130 psi Generator Power 68 kW 91 ho REC f^evenue $0.04 £/kWhr (H using Feed in Tariff, SDGE claims RECs) Tolal Hours/yr 8760 hrs Ade^yate Flow Available 93.0% % (based on historical ftow) Availabilitv 95% % In Service Hours/yr - TURBINE 1 7739 hrs In Service Hours/vr - TURBINE 2 0 hrs 04M Rate $0.01 £/kWhr Base Rale $0.0884 $/kWhr Based on SDGE MPR Schedule for 10 year contract (2011) Percent of Annual Hours On Peak Rate Summer (year 1) $0.1451 $fl(Whr Based on SDGE TOD Penods 7% On Peak Rate Winter (vear 1) S0.1054 S/kWhr Based on SDGE TOD P«iods 16* Semi-peak Summer (year 1) $0.0920 SfltWhr Based on SDGE TOD Periods 7% Semi-peak Winter (year 1) $0.0954 £/kWhr Based on SDGE TOD Periods 16% Ofl P^ak Rate SutYimer (year 1) $0.0781 £n(Whr Based on SDGE TOD Perkxls 16% Ott Peak Rate Winter (year 1) $0.0701 I/kWhr Based on SDGE TOD Periods 37% Average Rate $0.0881 (weighted avg) Inflation (elect and REC) 5.0% %/yr (used to calc MPR rale for 2nd 10 vt contract) Inflation (O&M) 3% Revenue from Elect Bit) Net Meier $29,000 (based on MaerideResenioir 2009 partial elect bils: extfa|}olated for 12 mos) Net Meter Enerqy 165.000 kWhrs (based on Maeride Reservoir 2009 partial eled bills:extraDolatedfor 12mos) Discount Rale 4.5% (Based on letter from CMWD. Ftesponse to ReouesI tor Information, dated 10/1/2009) Project Capital CosI $ 1,060,000 (input project capital cost for payback period calc] 20 yr Net Present Value £ 80.041 NPV Payback Period 18.6 years Annual kWhrs Power f^nual Minus Net Elect Sell Demand REC Net Meter Year Produced Operatinq Hours Annual kWhrs Meter kWhrs Rate Revenue Savinqs Revenue Offsets O&M Coste Net Total NPV Year Unit kW hrs/year kWhrs kWhrs ykWhr £ £ £ £ $ $ 0 £ (1,060,000) 0 1 68 7739 525.373 360,373 0.0881 £ 31.752 £ 6.600 £ 29.000 £ (5,254) $ 62,098 S (1,000,576) 1 2 68 7739 525,373 360.373 0.0881 $ 31,752 $ 6,930 £ 30.450 £ (5,411) $ 63,721 $ (942.225) 2 3 68 7739 525,373 360,373 0.0681 £ 31,752 $ 7.277 $ 31,973 £ (5.574) S 65,427 £ (884,891) 3 4 68 7739 525,373 360,373 0.0681 £ 31,752 £ 7,640 $ 33,571 £ (5,741) £ 67,223 £ (828,520) 4 5 68 7739 525,373 360.373 0.0881 £ 31.752 £ 8,022 £ 35.250 £ (5,913) $ 69,111 $ (773,062) 5 6 68 7739 525,373 360,373 0.0881 $ 31,752 £ 8,423 £ 37.012 £ (6,091) $ 71,097 $ (718,467) 6 7 68 7739 525,373 360,373 0.0881 $ 31,752 £ 8.845 £ 38,863 £ (6,273) $ 73,186 S (664,688) 7 8 68 7739 525,373 360,373 0.0881 $ 31,752 £ 9,287 £ 40,806 £ (6,461) S 75,383 $ (611,679) 8 9 68 7739 525,373 360,373 0.0881 $ 31,752 £ 9,751 $ 42,846 £ (6,655) $ 77,694 $ (559,398) 9 10 68 7739 525,373 360,373 0,0881 £ 31,752 £ 10.239 $ 44.989 £ (6.655) $ 80,124 £ (507,804) 10 11 68 7739 525,373 360,373 01435 £ 51.721 £ 10,751 S 47,238 £ (7.061) $ 102,649 £ (444,552) 11 12 68 7739 525.373 360,373 0.1435 £ 51,721 £ 11,288 £ 49,600 $ (7,272) $ 105,337 £ (382,438) 12 13 68 7739 525.373 360,373 0.1435 £ 51.721 $ 11.853 £ 52,080 $ (7,491) $ 108,163 £ (321,405) 13 14 68 7739 525,373 360,373 0 1435 $ 51,721 S 12,445 £ 54.684 £ (7,715) $ 111,135 £ (261,396) 14 15 68 7739 525,373 360,373 0.1435 S 51,721 $ I3.06S S 57,416 $ (7.947) S 114,260 S (202,355) 15 16 66 7739 525,373 360,373 0.1435 £ 51,721 $ 13,721 $ 60.289 $ (8,185) $ 117,546 £ (144,233) 16 17 68 7739 525.373 360.373 0-1435 £ 51,721 $ 14,407 £ 63.303 $ (8,431) $ 121,001 $ (86,978) 17 13 68 7739 525.373 360,373 0.1435 £ 51.721 £ 15.127 $ 66.469 $ (8,684) $ 124,633 £ (30,544) 18 19 68 7739 525,373 360,373 0.1435 £ 51,721 £ 15,884 £ 69.792 £ (8,944) % 128,452 S 25.115 19 20 68 7739 525,373 360,373 0.1435 £ 51,721 S 16.678 £ 73,282 £ (9.212) s 132,468 £ 80,041 20 TOTAL 10.507,464 420299 105075 5 1,870,708 Carollo Engineers 2/16/2010 CarlsbadHydro_NPV_rev1 .xls 3.6 NPV ("* Client: Carlsbadl^nicipalWaterDislrict Project: Hydroelectric Turbine at Maerkle Reservoir By: CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job*; e362A10 Alternative No. Turbine NPV Analysis =input Comments: Turbine Flow 6.75 cfe = 4.4 mqd Number of Turbines 1 each Turbine Eff 0.85 Generator Eff 0.93 Head Differential 300 ft = 130 psi Generator Power 135 kW 181 hp REC Revenue S0.04 $/hWhr (if usinq Feed in Tariff. SDGE claims RECs) Total Hours/yr B7«0 his Adequate Flow Available 74.0% % (based on historical fkn^) Availability 95% % In Service Hours/vr - TURBINE 1 6158 hrs In Service HoursA-r - TURBINE 2 0 hrs O&M Rale $0.01 $/kWhr Base Rale $0.0884 £/kWhr BasedonStXiEfffi^Scfiedulefor 10 year contract (2011) Percent of Annual Hours On Peak Rale Suminer (year 1) $0.1451 S/kWhr Based on SOGE TOD Periods 7% On Peak Rale Winter (year 1) $0.1054 S/kWhr Based on SDGE TOO Pertods 16% Semi-oeak Summer (year 1) $0.0920 S/kWhr Based on SDGE TOO Periods 7% Semt-peak Winter (year 1) $0.0954 VkWhr Based on SDGE TOO Periods 16% Olf Peak Rate SumiT«( (year 1) M.0T81 £(kWhi Based on SDGE TOO Periods 16% Off Peak Rate Winter {year 1) $0.0701 $/kWhr Based on SDGE TOO Penods 37% Average Rate $0.0881 (wekihted avq) Inflalion (eled and PEC) 5.0% %/yi (used to cak: MPR rate tor 2nd 10 yr contract) Inflation (O&Ml 3% Revenue from Elect Bill Net Meter $29,000 (based on Maeride Reservoir 2009 partial elect bills; extrapolated lor 12 mos) Net Meter Energy 165.000 kWhrs (based on Maerkle Reservoir 2009 partial elect bills; extrapolated lor 12 mos) Discount Rate 4.5% (Based on letter from CMWD, Response to Request ftx Infomtatkm, dated 10/1/2009) Proiecl Caoilal Cos! $ 1.120.000 (input prorect cosI for payback period calc) 20 vr Net Present Value $ 407,735 NPV Payback Period 14,7 years Annual kWlirs Power Annual Minus Net Elect Sell Demand REC Net Meter Year Produced Operating Hours Annual kWhrs Meter kWhrs Rate Revenue Savings Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWtirs kWhrs $/kWhr £ £ £ £ $ S 0 1 135 6158 832.812 667,812 0.0881 S 58.840 £ 6,600 $ 29,000 £ (8,328) £ 86.112 $ (1.120.000) £ (1.037,596) 0 1 2 135 6158 832,812 667,812 0.0881 $ 58.840 £ 6,930 £ 30,450 $ (8,578) $ 87,642 £ (957,339) 2 3 135 6158 832,812 667,812 0.0881 $ 58,840 £ 7,277 £ 31.973 $ (8,835) $ 89,254 £ (879.126) 3 4 135 6158 832,812 667.812 0,0881 £ 58,840 £ 7,640 £ 33,571 $ (9,100) $ 90,951 £ (802.858) 4 135 6158 832,812 667.812 0.0881 $ 58.840 £ 8,022 £ 35.250 $ (9,373) $ 92,739 S (728.440) 5 B 135 6158 832.812 667.812 0.0881 $ 58.840 £ 8,423 $ 37.012 $ (9,655) $ 94,621 £ (655,780) 6 1 135 6158 832,812 667,812 0.0881 £ 58.840 £ 8,845 £ 38.863 $ (9,944) $ 96,603 £ (584,793) 7 B 135 6158 832,812 667,812 0.0881 £ 58,640 £ 9,287 £ 40,806 £ (10,243) £ 98.691 $ (515,396) 6 9 135 6158 832.812 667.812 0.0881 £ 58,840 $ 9,751 £ 42,846 £ (10.550) £ 100,888 $ (447,508) 9 10 135 6158 832,812 667,812 0.0881 £ 58,840 £ 10,239 S 44,989 £ (10,866) $ 103,201 $ (381.054) 10 11 135 6158 832,812 667,812 0.1435 £ 95,845 £ 10,751 S 47.238 £ (11,192) $ 142,641 £ (293,159) 11 12 135 6158 832,812 667,812 0.1435 £ 95.845 E 11,288 £ 49.600 £ (11,528) $ 145,205 £ (207.537) 12 13 135 6156 832,812 667,612 0 1435 S 95.845 £ 11,853 S 52.080 £ (11,874) S 147,903 £ (124.079) 13 14 135 6158 832,812 667,812 0.1435 £ 95,845 £ 12,445 £ 54.684 £ (12,230) s 150,744 £ (42.662) 14 15 135 6158 832,812 667,812 0.1435 £ 95.845 £ 13,068 S 57,418 £ (12.597) s 153,733 £ 36,755 15 16 135 6158 832,812 667,812 01435 £ 95.845 S 13,721 $ 60.289 £ (12,975) $ 156,879 £ 114,328 16 17 135 6158 832,812 667,812 0.1435 $ 95.845 £ 14,407 £ 63,303 £ (13,364) s 160,191 £ 190.126 17 16 135 6158 832,812 657.812 0-1435 S 95.845 S 15,127 £ 66,469 £ (13,765) $ 163,675 £ 264.238 18 19 135 6158 832,812 667,812 0.1435 $ 95,845 £ 15,884 $ 69,792 £ (14,178) s 167,342 £ 336.748 19 20 135 6158 832,812 667.812 0.1435 $ 95,845 $ 16,678 £ 73,282 £ (14,603) s 171,201 £ 407,735 20 TOTAL 16.656,237 666249 166562 $2,500,217 Carollo Engineers 2/16/2010 CarlsbadHydro_NPV_rev1 xls 6.75 NPV Client: Carlsbad Municip^ Water District Project: Hydroeleclric Turbine at Maerkle Reservoir By: CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job#: 8362A10 Alternative No. 4a Turbine NPV Analysis - with AB 2466 (wheeling) =input Commenis; Turt)ine Flow 6.75 cfs = 4.4 mqd Number of Turbines 1 each Turbine Eff 0J9 Generator Eff 0.93 Head Differential 300 ft-130 psi Generalof Potver 135 kW = let hp REC Revenue S0.04 $/kWhr (if using Feed In Tariff, SDGE daims REC's) Total Hours/yr 8760 hrs Adeguale Fk)w Avail^le 74% % (ttased on historical tkiw) AvailatMlilv 95% % In Service HoursAr - TURBINE 1 6158 hrs In Service Hours/vr - TURBINE 2 0 hrs O&M Rale $0.01 SlkWv Summer Peak Demand Charge $13.77 Winter Peak Denn^rid Charge $4.77 Comckient Demand Charge $11.53 Base Rate $/kWhr Based on SDGE MPR Scnedule for 10 yea contrad {2011) Percent Of Annual Hours On Peak Rate Summer (year 1) E/kWhr Based on SDGE TOO Periods 7% On Peak Rale Witiier (year 1) £/kWhr Based on SDGE TOO Periods 16% Semi-peak Summer (year 1) $A(Whr Based on SDGE TOO Perkxls 7% Semi-peak Winter (year 1) £fl(Whr Based on StDGE TOO PenoOs 16% Off Peak Rate Summer (year 1) $/kWhr Based on SDGE TOO Perkids 16% Off Peak Rate Winter (year 1) £/kWhr Based on SDGE TOD Periods 37% Average Rate $0.0966 See •AL-TOU Rales' tot ded lales Inflation (elect and REC) 5.0% %/vr (used Rl cak: MPR rate lor 2nd 10 yr contract) lnflatk)n (OSM) 3% Revenue from Elect Bill Net Meter $0 (based on Maerkie Reservoir 2009 partial etect biHs; extrapolated for 12 mos) Ne! Meier Energy 0, kWhfs (based on Maerkle Reservoir 2009 partial eted biKs: extrapolaled tor 12 mos} Discount Rale 4.5% (BasedonletterfromCMWD, Response to Request lor Intormation, dated 10/1/2009) Proiect Capital Cosl S 1,090,000 (input project capital cost for paytiack perkxl calc) 20 yr Net Present Value £ 1,586,720 NPV Pavtwck Period 8.1 years 1 Annual kWhrs Demand Net Power Annual Minus Net Elect SeH Swtr«gs REC Meter Year Produced Operating Hours Annual kWhrs Meter kWhrs Rate (2) Revenue (1) Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs $/kWhr £ S $ £ £ £ 0 1 135 6158 832.812 832.812 $0.0966 £ 80,442 £ 26.912 £ 33,312 £ £ (8.328) $ 132,338 £ £ (1.090.000) (963.361) 0 1 2 135 6158 832,812 832,812 £0,1014 £ 84.464 £ 28.257 I 34,978 £ -£ (8,578) $ 139.122 £ (835,963) 2 3 135 6158 832.812 832,812 $0.1065 £ 88.688 £ 29,670 $ 36,727 £ £ (8.835) $ 146,249 £ (707.805) 3 4 135 6158 832.812 832,812 $0,1118 $ 93.122 $ 31.154 S 38,563 £ £ (9.100) £ 153,739 £ (578,885) 4 5 135 6158 832.812 832,812 $0.1174 $ 97,778 £ 32,711 S 40.492 $ -£ (9.373) S 161.608 £ (449.203) 5 6 135 6156 332,812 832,812 SO 1233 S 102.667 £ 34,347 $ 42,516 $ -£ (9,655) 5 169,875 S (318,757) 6 7 135 6158 832,812 832,812 £0.1294 £107.800 £ 36.064 £ 44.642 S -£ (9,944) $ 178,562 $ (187.544) 7 8 135 6158 832,812 832.812 £0.1359 £113,190 $ 37,867 £ 46.874 S -$ (10,243) $ 187,689 s (55.564) 8 9 135 6158 832,812 832.812 $ 0.1427 £118,850 £ 39.761 £ 49,218 s £ (10,550) $ 197,279 £ 77.186 9 10 135 6158 832.812 832.812 £0,1498 £124.792 £ 41,749 £ 51,679 £ -£ (10,866) $ 207,353 £ 210,706 10 11 135 6158 832,812 832,812 £0,1573 £131.032 $ 43,836 £ 54.263 £ -£ (11,192) S 217,938 E 345.000 11 12 135 6158 832.812 832.812 $0.1652 $137,584 £ 46,028 £ 56,976 $ £ (11,528) « 229,059 £ 480,068 12 13 135 6158 832,812 832,612 £0.1735 £ 144,463 £ 48,329 $ 59,824 £ £ (11,874) $ 240,743 £ 615.912 13 14 135 6158 832,812 832,812 £0 1821 £ 151.686 $ 50.746 £ 62,816 £ -$ (12,230) s 253,017 $ 752,534 14 15 135 6158 832.812 832,812 £0.1912 £159.270 S 53283 S 65,956 £ -$ (12,597) s 265,913 $ 889,937 15 16 135 6158 832.812 832,812 £0 2008 £167.234 £ 55,947 $ 69,254 £ $ (12,975) s 279,460 $ 1,028.122 16 17 135 6158 832,812 832,812 £ 0.2108 £175.595 £ 58,745 £ 72,717 £ $ (13,364) $ 293,693 $ 1,167,090 17 18 135 6158 832,812 832,812 £ 0.2214 $184,375 $ 61,682 £ 76.353 £ -$ (13,765) $ 308,645 S 1,306,845 18 19 135 6158 832,812 832,812 $ 0 2325 $193,594 £ 64,766 £ 80.170 £ $ (14,178) $ 324,352 $ 1,447,387 19 20 136 8158 832.812 832,812 SO 2441 J 203.274 S 68.004 £ 84,179 5 -5 (14,603) $ 340,854 $ 1,588,720 20 TOTAL 16.656.237 666249 166562 £ 4.427,489 Carollo Engineers 2/16/2010 Car1sljadHydTCi_NPV_revl ,xls 6.75NPV AB2466 jt).iii Client: Carlsbad Municipal Water District Project: Hydroeleclric Turbine al Maerkle Reservoir By: CTC Oate Created: 10/30/2009 Printed Date: 2/16/2010 Job#: 8362A10 Alternative No. Turbine NPV Analysis =inpiil Comments: Turbine Flow 7.75 cfs = 5 0 mod Number ol Turbines 1 each Turbine Efl 0J6 Generator Eff 0.93 Head Differential 300 fl = 130 psi Generator Power 157 kW 211 hp REC Revenue $0.04 $fltWht (if usinq Feed in Tariff, SDGE claims RECs) Total Hours/yr 8760 hrs Adequate Flow Available GO.0% % (t>ssed on historical Oow) Availability 99% % In Service Hours/yr - TURBINE 1 4993 hrs In Service Hours/yr - TURBINE 2 0 hrs O&M Rate $0.01 S/kWhr Base Rate $0.0884 $/kWhr Based on SDGE MPR Schedule tor 10 year conbad (2011) Percent of Annual Hours On Peak Rate Summer (year 1) $0.1451 £/kWhr Based on SDGE TOO Penods 7% On Peak Rate Winter (year 1) $0.1054 $/kWhr Based on SDGE TOO Periods 16% Semi-peak Summer (year 1) $0.0920 $/kWhr Based on SDGE TOD Periods 7% Semi-peak Winter (year 1) $0.0954 $/kWhr Based on SDGE TOD Periods 16% Off Peak Rate Sumnwr (year 1) $0.0781 £/kWhr Based on SDGE TOD Periods 16% Off Peak Rate Winter (year 1) $0.0701 $/kWhr Based on SDGE TOD Periods 37% Average Rate $0.0881 (wwqhted BWfl) Inflation (elect and REC) 5.0% %/yr (used to cak: hff>R rale lor 2nd 10 yr contrad) Inflalion (O&M) 3% Revenue ffom Elect Bill Net Meier $29,000 (based on Maertde Reservoir 2009 partial eled t>ills; extrapolated lor 12 mos) Net Meter Enerqy 165,000 kWbrs (based on Maerkle Resenoir 2009 partial eled biHs: extrapolated fra 12 mos) Discount Rate 4.5% (Based on letter from CMWD, Response lo Request tor Inlorniatkm, dated 10(112009) Proiecl Capital Cost $ 1,120,000 (input proiect cosl for pavt>ack period calc) 20 yr Net Present Value $ 346,700 NPV Payback Period 15 3 years Annual kWhrs Power Annual Minus Net Elect Sell Demand REC Net MdcT Year Produced Operating Hours Annual kWtirs Meter kWhrs Rate Revenue Savings Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs £/kWhr £ £ $ $ $ $ 0 1 157 4993 784,411 619.411 0.0881 $ 54,576 £ 6.600 s 29.000 £ (7,844) £ 82,332 £ (1.120.000) £ (1,041,214) 0 1 2 157 4993 784.411 619.411 0.0881 £ 54.576 $ 6.930 s 30.450 £ (8,079) $ 83,876 £ (964,406) 2 3 157 4993 784.411 619.411 0.0861 £ 54,576 £ 7,277 $ 31.073 £ (8,322) $ 85,503 £ (869.480) 3 4 157 4993 784,411 619,411 0.0881 £ 54.576 £ 7,640 £ 33.571 £ (8,571) $ 87,216 $ (816,344) 4 5 157 4993 784.411 619,411 0.0881 £ 54,576 £ 8,022 $ 35.250 £ (8,829) $ 89,019 £ (744,911) 5 6 157 4993 784.411 619,411 0.0881 £ 54,576 $ 8,423 $ 37.012 £ (9.093) $ 90,918 £ (675.095) 6 7 157 4993 784.411 619.411 0.0881 £ 54,576 £ 8,845 $ 38.863 £ (9.366) £ 92,917 £ (606.817) 7 8 157 4993 784,411 619,411 0.0881 £ 54,576 £ 9,287 £ 40.806 $ (9,647) £ 95,021 £ (540.000) 8 9 157 4993 784,411 619,411 0.0861 £ 54.576 £ 9,751 £ 42.646 $ (9.937) $ 97,236 $ (474,569) 9 10 157 4993 784,411 619.411 0.0881 £ 54,576 £ 10,239 £ 44.969 £ (10.235) $ 99,568 $ (410.454) 10 11 157 4993 784,411 619.411 0.1435 £ 88,898 £ 10,751 £ 47,238 $ (10,542) S 136,345 $ (326,438) 11 12 157 4993 784,411 619.411 01435 £ 86.698 £ 11,288 £ 49,600 $ (10.858) S 138,928 £ (244,518) 12 13 157 4993 784,411 619,411 0.1435 £ 88.898 £ 11,853 $ 52,080 £ (11,184) S 141,647 $ (164,590) 13 14 157 4993 784,411 619,411 0-1435 $ 88,898 £ 12.445 S 54,684 £ (11,519) * 144,508 £ (86.560) 14 15 157 4993 784,411 619.411 0.1435 £ 88.898 £ 13,068 $ 57,418 £ (11.865) t 147,519 £ (10.334) 15 16 157 4993 784.411 619,411 0.1435 £ 88.898 £ 13,721 S 60.289 £ (12,221) % 150,687 $ 64,176 16 17 157 4993 784.411 619,411 0.1435 £ 88,898 £ 14,407 $ 63.303 £ (12.587) S 154,021 £ 137.055 17 18 157 4993 784,411 619,411 0.1435 £ 88.898 £ 15,127 £ 66,469 £ (12,965) s 157,529 £ 206,384 18 19 157 4993 784411 619,411 0,1435 £ 88,898 £ 15,884 $ 69,792 £ (13.354) £ 161,220 £ 276.241 1.9 20 157 4993 784.411 619,411 0.1435 £ 88.898 £ 16.678 £ 73,282 £ (13,755) $ 165,103 £ 346,700 20 TOTAL 15,688.227 627529 156882 £2,401,112 Carollo Engineers 2/16/2010 CarlsbadHydro_NPV_rev1,xls 7.75 NPV Client: Cadsbad Municipal Water Dislrid Project: Hydroelectnc Turbine al Maerkle Reservoir By: CTC Date Created: 10/3012009 Printed Date: 2/16/2010 Job #: 8362A10 AHernatlve Ho. 6 Turbine NPV Analysis =input Turtjtne Ftow 3.6 CfS = 2.3 mgd Number ot Turbirtes 2 each Turbine Eff 80% Generator Eff 03% Head Differenbal 300 ft = 130 psi Generator Power per Turt>ine 68 kW kW at hp Generator Power Total 136 kW kW 182 hp REC Revenue $0.04 $*Whr {H using Feed in Tarin, SDGE claims REC's) Tolal Hours/yr 8760 hrs Adequate Fknv Available for Both Turt>ir>es 63.0% % (tused on histcrical Ikiw) Adequate Flow for OnN One TurtMte 30.0% % (based on historical fkm) Availability 95% % In Service Hours/yr - TURBWE 1 7738 hrs In Service Hours/yr - TURBINE 2 5243 tirs O&M Rate SO.Ot £/kWhr Base Rate $0.0884 $/kWhr Based on SDGE MPR Schedi«e for 10 year conlracl (2011) Percent Of Annual Hours On Peak Rate Summer (vear 1) t0.1451 £/kWhr Based on SDGE TOO Periods 7% On Peak Rate Winter (year 1) 10.1054 S/kWhr Based on SDGE TOD Periods 16% Semi-peak Summer (year 1) $0.0920 VkWhr Based on SDGE TOD Periods 7% Semi-peak Winter (year 1) fO.0954 S/kWhr Based on SDGE TOD Periods 16% Off Peak Rate Summer (year 1) $0.0781 £/kWhr Based on SDGE TOD Periods 16% Off Peak Rate Winter (year 1) $0.0701 £/kWhr Based on SDGE TOD Periods 37% Average Rate $0.0881 (Uiciqhted avq) Inflatkm (elect and REC) 5.0% %^r (used to ealc MPR rale lor 2nd 10 yr conlract) Inflatnn (OSU) 3% Revenue from Bed BiH Net Meter $29,000 (based on MaeiWe Reservoir 2009 partial elect liills; eiUapolaled lot 12 mos) Net Meter Enerqy 165,000 kWhrs (based on Maertile Reservoir 2009 partial elect trills; exbapolaled lor 12 mos) Discount Rate 4^ (Based on letter from CMWD, Response lo RequesI lor InfonnalkKi, dated 10/1/2009) Project Capital Cost 1 1.290.000 (Input project cost for paytjacK period cak:) 20 yr Net Present Value £ 298,844 NPV Payback Period 16.2 years Annual kWhrs Annual Minus Net Eled Sell DemarKl REC Net Meier Year Power Produced Operatinq Hours Annual KWhrs Meier kWhrs Rate Revenue Savings Revenue Offsets OftM Costs Net Total NPV Year Unit kW iKS/year kWhrs kVrtirs £/kWhr £ $ $ $ $ $ 0 £ (1,290,000) 0 1 68 12982 881,271 716.271 0.0881 $ 63.110 S 6.600 $ 39,000 £ (8.B13) S 89,897 $ (1.303.974) 1 2 68 12982 881.271 716.371 00881 $ 63,110 $ 6.930 $ 30,450 $ (9,077) t 91,413 $ (1.130.364) 3 3 68 12982 881.271 716.271 00881 £ 63.110 $ 7.277 $ 31.973 £ (9.349) t 93,010 £ (1.038.760) 3 4 66 12982 881.271 716,271 0.0881 £ 63,110 $ 7,640 $ 33,571 $ (9,630) s 94,692 $ (959.356) 4 5 68 12982 881.271 716.271 00881 £ 63.110 £ 8.022 £ 35,250 £ (9.919) % 96,463 £ (881,949) 5 6 68 13982 881,271 716,271 0.0881 $ 63,110 $ 8.423 $ 37,012 $ (10,216) s 98,329 $ (806,442) 6 7 68 12982 881,271 716.271 0.0881 $ 63,110 $ 8,845 $ 38,863 $ (10,523) s 100,295 $ (732,743) 7 8 68 12982 881,271 716,271 0.0881 S 63,110 £ 9.287 £ 40,806 £ (10.839) s 102,364 $ (660,762) e 9 68 12982 881,271 716,271 0.0881 I 63,110 £ 9.751 $ 42.846 $ (11,164) s 104,544 $ (590,414) 9 10 68 12982 881,271 716.271 0.OB81 S 63.110 $ 10.239 $ 44.989 $ (11.499) s 106.839 £ (521.618) 10 11 68 12983 881,271 716.271 0,1435 $102,799 $ 10,751 $ 47.238 $ (11.844) s 148.945 $ (429.838) 11 12 66 12982 881,271 716.271 0.1435 $102,799 $ 11,288 £ 49,600 £ (12,199) % 1S1,48S $ (340,511) 13 13 68 12982 881,271 716,271 0.1435 $102,799 £ 11,853 £ 52,080 £ (12,565) % 154,167 £ (253,519) 13 14 6B 13983 881,271 716.371 0.1435 $103,799 £ 13,445 £ 54,684 $ (12,943) 1 156,987 $ (168,750) 14 15 68 13982 881.271 716.371 01435 $103,799 $ 13,068 $ 57,418 $ (13.330) s 159,955 $ (86.098) 15 16 68 13983 881.271 716,271 0.1435 $102,799 £ 13,721 £ 60.289 £ (13.730) $ 163,070 $ (5,460) 16 17 6S 12982 881.271 716,271 0.1435 £102.799 £ 14,407 £ 63.303 £ (14,143) % 166,368 £ 73.261 17 18 68 12982 881,271 716,271 0.1435 £103.799 15,127 $ 66,469 $ (14,566) s 169,829 $ 150.160 18 19 68 12982 881.271 716,371 0.1435 $102,799 £ 15,884 $ 69,792 $ (15,003) $ 173.472 £ 225,326 19 20 68 12982 881.271 716,271 0.1435 £102,799 £ 1^678 £ 73.282 £ (15.453) $ 177,306 £ 298,844 20 TOT/y. 17,625.423 705017 176254 $3,599,442 Carollo Engineers CarlsbadHydro_NPV_revl .xls (2) 36 NPV Client: CarlsbadMu nicipal Wate r District Project: Hydroeleclnc Turbine at Maerkle Reservoir By: CTC Date Created: 10/30^2009 Printed Date; 2/16/2010 Job #: a362A1D Mtematlve Nd- 7 Turbine NPV Analysis ^nput Tutt)inel Flow 3.6 cts = 2.3 mqd Turbine2 Ftow 5.4 cts = 3.5 mgd Total Turbine Fkiw 9.0 cfs = 5.8 mfld Number of Turbines 2 TurtJioel Eff 80% Turt)ine2 Eff 78.5% Generator Eff 93% Head Differenlial 300 n = 130 psi Turt>ine1 Generator Power Turbine2 Generator Power 68 100 kW = kW 91 hp Turt>ine1 Generator Power Turbine2 Generator Power 68 100 kW = kW 134 tip REC Revenue $0.04 £/kWhr (il using Feed in Tariff, StXjE daims REC's) Tolal Hours/p 8760 hrs Adequate F)oW AvailatAe loi Both Turtles 42.0% % (based on In^orical How) Adequate Ftow (or Turbinel -Only 8.9% % Adequate FicW lor Turt>lne2 - On^ 44.1% % Percent Avail - Turbinel 48.9% Percent Avail - Turbine2 86.1% Availability 05% % In Service Hours/yr - TURBINE 1 4069 hrs In Servk:e HoursAr - TURBINE 2 7165 hrs O&M Rate $0.01 $/kWhr Base Rale $0.0884 $/kWhr Based on SDGE MPR StheduleforlO year contract (2011) Percent of Annual HOurs On Peak Rale Sunvner (year 1) $0.1451 $*Whr Based on SDGE TOD Periods 7% Csi Peak Rate Winter (year 1) $0.1054 SKmt Based on SDGE TOD Periods 16% Semi-oeak Surwner (year 1) $0.0020 £/kWhr Based on SDGE TOD Periods 7% Semi-oeak Winter (year 1) $0.0954 £fl(Whr Based on SDGE TOD Periods 16% Off Peak Rate Summer (year 1) $0.0781 £/kWhr Based on SDGE TOD Periods 16% Ofl Peak Rate Winter (year 1) S0.0701 £/kWhr Based on SDGE TOD Periods 37% Average Rate $0.0881 Ivieiqhied aval Inflatwn (elect 3nd REC) 5.0% %/yr fused to cale MPR rate lot 2nd 10 yr conlractl inflatkm (O&M) 3% Revenue from Elect BiH Net Meter $29,000 (based on Maeikle ReienOii 2009 partial elect bills; extrapoiated for 12rnos) Net Meter FnerOV 165.000 kWhrs (based on Maerkle Reservoir 2009 oarlid elect bills: extrapolaled toi 12 mos) Discount Rate 4.5% (eased on leder Irom CMWD. ResfKmse to Request lor IntormalKin. dated 10/1/20091 Project Capital Cost $ 1,340.000 (input project cost tor payback period cak:) 20 vr Net Present Value S 388.675 NPV Pavtjack Period 15.5 vears Annual kWhrs Annual Minus Net Elect Sell Demand REC Net Meter Year Total Power Produced OpetaUnQ Hours Annual kWhrs Meter kWhrs Rale Revenue Savings Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs $/kWhr $ £ £ $ $ £ 0 $ (1,340,000) 0 1 168 11235 992,156 827,156 0.0881 $ 72,880 $ 6,600 £ 39.000 $ (9,922) t 98,558 $ (1,345,686) 1 3 168 11235 992,156 827.156 O.0881 S 73.880 £ 6.930 $ 30,450 £ (10,319) S 100,041 $ (1,154,076) 2 3 168 11235 992,156 827,156 0.0881 $ 72,880 I 7,277 £ 31,973 £ (10,526) t 101,603 £ (1,065,041) 3 4 168 11235 992,156 837,156 0.0881 S 73.880 £ 7.640 $ 33,571 $ (10,842) $ 103,250 $ (978,460) 4 5 168 11235 992.156 827,156 0.0881 £ 72.880 £ 8.032 $ 35,250 $ (11.167) $ 104.985 $ (894,214) 5 6 168 11235 992,156 827.156 0.0881 £ 72.880 S 8,423 S 37,012 $ (11,502) $ 106,814 £ (812,193) 6 7 168 11335 992.156 827,156 0.0881 £ 72.880 £ 8,845 S 38,863 $ (11,847) $ 108,740 $ (732,387) 7 8 168 11235 992.156 837.156 0,0881 £ 72.880 £ 9,287 S 40,806 $ (12,202) $ 110,770 $ (654,395) S 9 168 11335 993.156 827,156 0.0881 $ 72.880 $ 9,751 S 42,846 S (12,568) $ 112,909 S (578,418) 9 IQ 168 11235 992,156 837,156 0.0881 £ 72,880 £ 10,239 S 44,989 S (12,945) $ 115,162 $ (504,262) 10 11 168 11235 992.156 827,156 0.1435 £118,714 £ 10,751 $ 47,238 $ (13,334) $ 163,369 $ (403.595) 11 12 168 11235 992,156 827,156 0.1435 $118,714 $ 11,288 £ 49,600 $ (13,734) $ 165,868 £ (305,788) 12 13 168 11235 993.156 827,156 0,1435 £118,714 $11,853 £ 53,080 $ (14,146) $ 168,500 $ (210,708) 13 14 168 11235 992,156 827.156 0 1435 $118,714 £ 12.445 $ 54,684 $ (14,570) $ 171,273 $ (118,236) 14 15 168 11235 993.156 827,156 0,1435 $118,714 $13,068 £ 57.418 $ (15,007) $ 174,192 $ (28,217) 15 16 168 11235 992,156 837,156 0.1435 S118.714 $ 13.731 $ 60,289 $ (15,457) $ 177,266 $ 59,436 16 17 168 11235 992,155 827,156 0.1435 $118,714 5 14.407 $ 63.303 $ (15,921) $ 180,503 $ 144.845 17 18 168 11235 992.156 827,156 0.1435 $118,714 $ 15,127 $ 66,469 s (16,399) t 183,911 $ 228,130 18 19 168 11235 992.156 837,156 0,1435 £118,714 £15,884 £ 69,792 (16,891) $ 187,499 $ 309,363 19 20 168 11235 992.156 837.156 0.1435 £118,714 £ 16.678 $ 73,282 £ (17,398) $ 191,278 $ 388,675 20 TOTAL 19.843.113 793724 198431 $2,826,486 Carollo Engineers CarlsbadHydro_NPV_rev1 .xls 3.8-5.4 NPV Client: Carlsbad Municipal Water District Projecl: Hydroeleclric Turbine at Maerkie Reservoir By: CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job#: 8362A10 Alternative No. 8 Turbine NPV Analysis =input Turbinel Flow 3.6 cts = 2,3 mqd Turbine2 Flow 6.75 cfs = 4.4 mqd Tolai Turbine Fkiw 10.4 c(s = 6.7 mqd Numt>er ol Turiiine^ 2 Turbinel Eff 80% Turbine2 Eff 85.0% Generator Eff 93% Head Differential 300 fl = 130 psi Turbinel Generator Power Turbine2 Generator Povjer 68 135 kW kW 91 hp Turbinel Generator Power Turbine2 Generator Povjer 68 135 kW kW 191 hp REC Revenue $0.04 $/KWhr Of using Feed in Tariff. SOGE daims REC's) Total Hours/yr 8760 hrs Adequate Flow Available tor Both Turbines 8.0% % (based on histOTKal ftow) Adequate Flow for Turbinel -Only IB.0% % Adequate Flowfar Tuftiir«2 - Only 66.0% % Percent Avail - Turt»nel 27.0% Percent Avail - Turt>ine2 74.0% Availability 05% % In Service Hours/yr - TURBINE 1 2247 hrs In Service Hours/yr - TURBINE 2 6158 hrs O&M Rate $0.01 £/kWnr Base Rate $0.0884 $/kWhr Based on SDGE MPR Schedide for 10 year contract (2011) Percent of Annual Hours On Peak Rate Summer (year 1) $0,1451 $/kWhr Based on SDGE TOD Periods 7% On Peak Rale Winter (year 1) $0.1054 S/kWhr Based on SDGE TOO Penods 16% Semi-peak Summer (year 1) $0.0920 £/kWhr Based on SDGE TOD Periods 7% Semi-peak Winter (year 1) $0.0954 $/kWhr Based on SOGE TOD Perkids 16% Off Peak Rate Summer (year 1) $0.0781 $/l(Whr Based on SDGE TOD Perkxls 16% Off Peak Rate Winter (year 1) $0.0701 £*Whr Based on SDGE TOO Periods 37% Average Rate $0.0881 (weltjtited avq) Inflation (elect and RFC) 5.0% %^r (used to calc MPR rate for 2nd 10 yr contracll Inflatran (OSM) 3% Revenue ftom Eleei Bill Net Meter $29,000 (based on Maerkle Resenroir 2009 partial eied bills: eitraoolated for 12 mos) Net Meter Enerqy 165,000 kWhrs (based on Maerkle Reservoir 2009 partal elect titlls; extrapolated for 12 mos) Discount Rate 4.5% (Based on letter ftom CMMD. Response to Reauest lor InlormalKn. dated 10/1120091 Project Capital Cost S 1.340,000 (inpul project cost for payback period calc) 20 yr Net Present Vakje $ 380,079 NPV Payback Peritxi 15,6 vears Annual kWhrs Annual Minus Net Elect Sell Demand REC Net Meter Year Total Power Produced Operating Hours Annual KWhrs Meter KWhrs Rate Revenue Savings ReverMie Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs $/kWht £ £ $ £ £ £ 0 £(1,340,000) 0 1 303 8405 985.340 820,340 0.0881 $ 72,279 $ 6,600 £ 29,000 $ (9,853) $ 98,026 $(1,246,195) 1 2 203 8405 985,340 820,340 0.0881 $ 72.279 £ 6,930 £ 30,450 $ (10,149) $ 99.510 £(1.155,071) 2 3 203 8405 985,340 830,340 0.0881 S 72,279 $ 7,277 £ 31,973 $ (10,453) S 101,076 5(1.066,499) 3 4 203 8405 985,340 820,340 0 0881 $ 72,279 $ 7,640 £ 33,571 £ (10,767) $ 102,724 $ (980,359) 4 5 203 8405 965,340 820,340 0.0881 £ 72,279 $ 8,033 £ 35,250 £ (11,090) $ 104,461 $ (896,534) 5 6 203 8405 985.340 820,340 0,0881 $ 73.279 $ 8,423 $ 37,012 £ (11,423) s 106,292 £ (814,913) 6 7 203 8405 985,340 820,340 0.0881 $ 72,379 £ 8,845 $ 38,863 £ (11,765) $ 108,221 £ (735,389) 7 8 203 8405 985,340 820,340 0.0881 £ 72,279 £ 9,287 £ 40,806 S (12,118) $ 110,254 £ (657,860) 8 9 203 8405 985,340 820,340 0.0881 $ 72,279 $ 9.751 £ 42,846 $ (12,482) $ 112,395 $ (582.229) 9 10 303 8405 985.340 820.340 0.0881 $ 72,379 $ 10,239 £ 44.989 $ (12,856) s 114,650 $ (508,402) 10 ll 203 8405 985,340 820,340 0,1435 5117,735 $ 10,751 $ 47,238 s (13.242) $ 182,482 $ (408,281) 11 12 203 8405 985,340 820.340 01436 $117,735 £ 11,288 $ 49,600 £ (13,639) $ 164,984 £ (310,996) 13 13 203 8405 985,340 830.340 0.1435 $117,735 £ 11,853 £ 52,080 £ (14,049) $ 167,619 £ (216,413) 13 14 203 8405 985,340 830,340 0.1435 $117,735 £ 12,445 $ 54,684 £ (14,470) $ 170,394 S (124,405} 14 15 303 8405 985,340 820,340 0.1435 $117,735 $ 13,068 $ 57,418 £ (14,904) s 173,317 £ (34,849} 15 16 203 8405 985,340 820,340 0.1435 $117,735 $ 13,721 $ 60,289 £ (15,351) $ 176,394 £ 52,373 16 17 203 8405 985,340 820,340 0.1435 £117,735 $ 14.407 £ 63,303 $ (15,812) $ 179,634 $ 137,371 17 18 203 8405 985,340 830,340 0.1435 $117,735 £ 15,127 £ 66,469 £ (16,286) $ 183,045 $ 220254 18 19 203 8405 985,340 820,340 0.1435 £117,735 $ 15,884 £ 69,792 $ (16,775) t 106,636 $ 301,124 19 So 203 8405 985,340 820,340 0.1435 $117,735 £ 16,678 $ 73,282 £ (17,278) $ 190,417 £ 380,079 20 TOTAL 19,706.791 788272 197068 $2,812,531 Carollo Engineers CarisbadHydro_NPV_rev1 .xls 3.6-6.75 NPV Client: Carlsbad Municipal Water District Project: Hydroelectric Turbine at Maerkle Reservoir By: CTC Date Created: 10/30/2009 Printed Date-. 2/16(2010 Jobs: 8362A10 Alternative No. 8a Turbine NPV Analysis - with AB 2466 (wheeling) =inpul Comments: Turbine Flow cfs = 0.0 mqd Number of Turbines each Turbine Eff Generator Efi Head Differential ft^ 0 psi Generator Power kW 0 hp REC Revenue $0.04 £/kWhr (H using Feed in Tariff, SDGE claims RECs) Total Hours/yr hrs Adequate Flow Available % (based on historical flow) Availability % In Service Hours/yr - TURBINE 1 hrs In Service Hours/yr - TURBINE 2 hrs O&M Rate $0.01 t(kWlK Summer Peak Demand Charqe $13.77 V\/inter Peak Demand Charoe $4.77 CoincidenI Demand Charge $11.53 Base Rale £/kWhr Based on S[>GE MPR Schedule tor 10 year contract (2011) Percent of Annual Hours On Pea* Rate Summer (year 1) £/kWhr Based on SDGE TOD Periods 7% On Peak Rale Winter (year 1) £/kWhr Based on SDGE TOD Periods 16% Semi-peak Summer (year 1) ykWhr Based on SDGE TOO Penods 7% Semi-peak Winter (year 1) £AWhr Based on SDGE TOD Periods 16% Off Peak Rate Summer (year 1) £fl<Whr Based on SDGE TOD Periods 16% Off Peak Rate Winter (year 1) SfltWhr Based on SDGE TOD Periods 37% Average Rate $0.0966 See •/U.-TOU Rates" for etect rates Inflalion (elect and REC) 5.0% %/yr (used to calc MPR rate for 2nd 10 vr conlracl) Inflation (O&MI 3% Revenue from Elect Bill Net Meter $0 (based on Maerkie Reservoir 2(X)9 partial elect Dills: extrapolated lor 12 mos) Net Meter Energy 0 kWhrs (based on Maeride Reservoir 2009 partial elect HHIs: extrapolated tor 13 mos) Discount Rate 4.5% (Based on lellet from CMWD. Response lo Request for IntormaBon, daled 10/1/2009) Project Capital Cosl $ 1.090,000 (input project capital cost for payback period calc) 20 yr Net Present Value £ 2.251.210 NPV Payback Period 6,5 vears 1 Annual KWhrs Demand Power Annual Minus Net Elect Sell Savings REC Net Meter Year Produced Operating Hours Annual KWhrs Meter kWhrs Rate (2) Revenue (1) Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/vear kWhrs kWhrs £/kWhr £ £ £ $ £ $ 0 £ (1,090,000) 0 1 203 6405 985,340 965.340 S 0.0966 S 95,175 $ 40.420 S 39414 £ £ (9,853) $ 165,156 £ (931,956) 1 2 203 8405 985,340 985.340 £0.1014 $ 99,934 $ 42.441 $ 41.384 $ £ (10.149) S 173,610 $ (772,976) 2 3 203 8405 985,340 985,340 £0.1065 $104,931 £ 44.563 £ 43,453 £ £ (10,453) $ 182.494 S (613,057) 3 4 203 8405 985,340 985,340 £0.1118 $110,177 £ 46.792 £ 45.626 £ £ (10,767) $ 191,838 $ (452.198) 4 5 203 8405 985.340 985,340 $0.1174 £115,686 £ 49,131 £ 47.907 £ $ (11,090) $ 201,634 £ (290.396) 5 6 203 8405 985.340 985,340 £0.1233 £121,470 £ 51.588 $ 50.303 $ $ (11,423) $ 211,938 £ (127,650) 6 7 203 8405 985,340 985,340 $0.1294 £127,544 $ &4.167 £ 52,818 £ £ (11,765) $ 222.763 $ 36.042 7 8 203 8405 985,340 985,340 $0,1359 £133,921 £ 56.875 £ 55,459 £ $ (12,118) $ 234,137 $ 200.684 8 9 203 8405 985.340 985,340 £0.1427 £140,617 £ 59.719 $ 58,232 $ £ (12482) $ 246.086 $ 366.276 9 10 203 8405 985.340 985,340 $0.1498 $147,646 $ 62.705 £ 61.143 $ $ (12,856) s 258,640 £ 532,822 10 11 203 8405 985,340 985,340 £0.1573 £ 155,030 $ 65.840 £ 64,201 £ £ (13,242) $ 271.829 $ 700,322 11 12 203 8405 985,340 985,340 $0.1652 £162.782 £ 69,132 £ 67,411 £ $ (13,639) $ 285,685 £ 868.780 12 13 203 8405 985.340 965,340 £0.1735 £170.921 £ 73.589 £ 70,781 $ $ (14,049) $ 300.242 £ 1,038,199 13 14 203 8405 985,340 985,340 £0.1821 $179,467 £ 76,218 $ 74,320 £ $ (14,470) $ 315,535 $ 1.208,579 14 15 203 8405 985.340 985,340 $0.1912 $188,440 £ 80,029 £ 78,036 S £ (14.904) s 331.602 £ 1,379,925 15 16 203 8405 985,340 965,340 £0.2008 £197,862 £ 84.031 £ 81.938 £ £ (15.351) $ 348,480 $ 1,552.237 16 17 203 8405 985.340 985,340 $0.2108 £207,755 £ 88,232 £ 86,035 £ £ (15,813) $ 366,211 £ 1,725.519 17 18 203 8405 985,340 985,340 £0.2214 £218,143 $ 92.644 $ 90,337 £ £ (16.286) $ 384,838 £ 1,899,774 18 19 203 8405 985,340 985.340 S 0.2325 £229,050 $ 97,276 £ 94,853 £ £ (16,775) $ 404,405 £ 2,075,003 19 20 203 8405 985,340 985,340 $0,2441 £240,503 $102,140 £ 99,596 £ £ (17,278) s 424,961 £ 2,251,210 20 TOTAL 19.706,791 788272 197068 £ 5.522,073 Carollo Engineers 2/16/2010 CarlsbadHydro_NPV_revl .xls 3.6-6.75NPV AB2466 Client: Carisbad Municipal Water Disfrict Project: Hydroelectric Turbme at MaerWe Reservoir By: CTC Date Created: 10/30/2009 Printed bate: 2/16/2010 Job#: 8363A10 Alternative No. 9 Turbine NPV Analysis =input Turbinel Flow 2.2 cfs = 1.4 mod Turt)ine2 Fkiw 7.75 Cf5 = 50 mgd Total Tufbine Ftow 10.0 cfs = 6.4 mgd Number of Turbines 2 Turbinel Eff 75% TurtJineS Eff 86.0% Generator Efl 93% Head Differential 300 fl = 130 psi Turbinel Generator Pcrwer Turbine? Generator Power 39 157 kW = kW = 52 hp Turbinel Generator Pcrwer Turbine? Generator Power 39 157 kW = kW = 211 hp REC Revenue $0.04 SfltWhr (if usino Feed in Tann, SDGE claims REC's) Total Hours/yr 8760 hrs Adequate Ftow Available tor Both Turbines 29.0% % (l>ased on tiistaxical (low) Adequate Flow for Turbinel -Only 35.0% % Adeqii^e Ftow for Jtfft3ine2 - Only 32.0% % Percent Avail - Turbinel 64.0% Percent Avail - Turbine2 61.0% Availability 95% % In Servk:e Hours/yr - TURBINE 1 5326 hrs In Sen/k:e Hours/yr - TURBINE 2 5076 hrs O&M R^te $0.01 £/kVyhr Base R^te S0.0884 $/kWhr Based on SOGE MPR Schedule for 10 year contract (2011) Percent of Annual Hours On Peak Rate Sunvner (^ear 1) $0.1461 vmt» Based on SDGE TOD Periods 7% On Peak Rate Winter (vear 1 \ $0.1054 £ikWhr Based on SDGE TOD Pertods 16% Semi-P6ak Surwner (year 1) $0.0920 £/kWhr Based on SDGE TOO Periods 7% Semi-P63k Winter f vear 1) $0.0954 MrtWir Based on SDGE TODPeiiixIs 16% Ofl Peak Rate Summer (year 1) $0.0781 £/kWhr Based on SDGE TOD Periods 16% Off Peak Rate Winter (year 1) $0.0701 $/kWhr Based on SDGE TOD Periods 37% Average; Rate S0.0S81 (MCiatited avq) Inflatton (elect and REC) 5.0% %/vr (used to calc MPR rate loF 2nd 10 yr conlractj Inflalton (O&M) 3% Revenue ftom Elect Bill Net Meier $29,000 (l>ased on Maerkle Reservoir 2009 parSal elect bills: extrapolated for 17 mos) l*( Meter Energy 165.000 kWhrs (based on Maerkle Resenroir 2009 partial elect bills: extrapolated for 12 mosj Discount Rate 4.5% (Based on letter trom CMWD, Response to Request for Infonnation, dated 10<I/200SI Project Caoilal Cost $ 1.290,000 (input protect cost tor payback period cato) 20 yr Nst Present Vakie £ 454,394 NPV Payback Period 14,8 vears Annual KWhrs Annual Minus Net Elect Sell Demand REC Net Meter Year Total Power Produced Operatinq Hours Annual KWhrs Meter KWhrs Rate Revenue Savinqs Revenue onsets O&M Costs Net Total NPV Year Unit hW hrs/year kWhrs kWhrs $/kWhr $ $ £ $ £ £ D $ (1,290,000) 0 1 196 10403 1,004,631 839,621 0.0881 $ 73,978 $ 8,600 $ 29,000 $ (10,046) S 99,532 $ (1,194,754) 1 2 196 10403 1,004,621 839,621 0,0881 £ 73,978 £ 6,930 £ 30,450 $ (10,348) S 101,011 £ (1,102,256) 2 3 196 1CM03 1,004,621 839,621 0.0881 $ 73.978 $ 7,277 £ 31,973 $ (10,658) $ 102,569 $ (1.012,375) 3 4 196 10403 1,004,621 839,621 0.0881 $ 73,978 $ 7,640 S 33,571 $ (10,978) i 104.212 $ (924.986) 4 5 196 10403 1,004.621 839,621 0.0881 $ 73,978 $ 8,022 £ 35,250 £ (11,307) $ 105,043 $ (839,972) 5 6 196 10403 1,004,631 839,621 0.0881 $ 73,978 $ 8,423 £ 37,012 £ (11.646) $ 107,768 $ (757,318) 6 7 t96 10403 1,004,621 839,621 o.osat $ 73,978 S 6,845 $ 38.863 $ (1(,996) s 109,690 S (676.615) 7 8 196 10403 1,004,621 839,621 0.0881 $ 73,978 £ 9.287 $ 40,806 £ (12,356) $ 111.715 £ (598,058) 8 9 196 10403 1,004.621 839,631 0.0881 $ 73,978 $ 9,751 £ 42,846 £ (12,726) $ 113.849 $ (521,448) 9 10 196 10403 1,004.521 839,621 0.0881 $ 73,978 $ 10,239 £ 44,989 £ (13.108) $ 116,097 S (446,690) 10 11 196 10403 1,004,631 839,621 0,1435 £120,503 £ 10,751 £ 47,238 $ (13501) £ 164,990 £ (345,023) 11 12 196 10403 1,004,621 839,621 0.1435 $120,503 $ 11,288 $ 49.6(X) $ (13.906) S 167,485 $ (246.264) 13 13 196 10403 1,004,631 839,621 0.1435 $120,503 $ 11,853 $ 52,080 $ (14,323) $ 170,112 $ (150,275) 13 14 196 10403 1,004,621 839,521 0.1435 $120,503 £ 12,445 £ 54,684 £ (14,753) $ 172,870 $ (56,925) 14 15 196 10403 1,004,621 839,621 0-1435 $120,503 $ 13,068 £ 57,418 $ (15,196) s 175,793 $ 33,911 15 16 196 10403 1,004,621 839.621 0.1435 £120,503 $ 13,721 $ 60.289 $ (15,652) $ 178,861 £ 122,352 16 17 196 10403 1.004.621 839,621 0.1435 £120,503 $ 14,407 $ 63.303 £ (16,121) $ 182,092 $ 208,514 17 18 196 10403 1,004,621 839,621 0.1435 £120,503 $ 15,127 £ 66.469 $ (16.605) $ 185,494 £ 292,505 18 19 196 10403 1,004,621 839,621 0.1435 $120,503 £ 15.884 $ 69,792 £ (17,103) $ 189,075 $ 374.432 19 30 196 10403 1,004,621 839,621 0-1436 £120,503 £ 16,678 $ 73,382 £ (17,616) s 192,848 £ 454,394 20 TOTAL 20,092,425 803697 200924 $2,852,012 I Carollo Engineers 2/16/2010 CarisbadHydro_NPV_rev1 .xls 2.2-7.75 NPV Client: Carisbad Municipal Water Distrkl Project: HydnDelecUic Turbine al Maerkte Reservoir By: CTC Date Created: 10/3(V2009 Printed Date: 2/16/2010 Job#: 8362A10 Alternative No. 10 Turbine NPV Analysis - Assuming Running Turbine During Peak Periods =ffiput Comments: Turbine Flow 7.75 cfs = 5,0 mod Numtjer of Turbines 1 each Turbine Eff 0.86 Generator Eff 0.93 Head Differential 300 fl = 130 psi Generator Power 157 KW = 211 hp REC Revenue $0.04 £/kWhr fif usina Feed in Tanff, SDGE daims REC's) Total Hours/yr 8760 hrs Adequate Ftow Available % Availatiililv % In Service Hours/yr - TURBINE 1 7705 tws (refer lo TurbtneAvaitalJility.xIs') In Service Hours/yr - TURBINE 2 0 hrs Percentaqe Hours ON PEAK 37% Percentage Hours OFF PEAK 63% O&M Rate $0.01 £/kWhr Base Rate $0.0884 ilMVtv Based on SDGE MF^ Schedule lor 10 year contract (2011) Percent of Annual Hours On Peak Rate Summer (year 1) $0.1451 t/kWhr Based on SDGE TOD Periods 31% 11% 884 On Peak Rate Winter (year 1) S0.1054 £/kWhr Based on SDGE TOD Periods 69% 26% 1967 Sen*-peak Summer (year 1) S0.0920 $/kWhr Based on SDGE TOD Periods 7% 6% 452 Senn-peak WHiler (year 1) $0,0954 £/kWhr Based on SDGE TOD P^iods 16% 13% 1019 Off Peak Rate Summer (year 1) $0.0781 Based on SDGE TOD Periods 16% 14% 1043 Off Peak Rate Winter (year 1) $0.0701 Based on SDGE TOD Periods 37% 30% 2340 Average Rate $0.0934 (welghtedavB) 100% 7,705 Inflatton (elect and REC) 5.0% %/vr (used to calc MPR rate for 2nd 10 yr contract) Inflation (O&lvl) 3% Revenue from Elect Bill Net Meter $29,000 (tiased on Maerkle Reservoir 2009 partial elect biHs: extrapolated lor 12 mos) Nel Meter Enerqy 165,000 KWhrs (based on Moeikle Reservoir 2009 partial elect bills: extrapotated (or 12 mos) Discount Rate 4.5% (Based on letter ftom CMWD, Resjmnse to Request for IntonnBlton, dated 10/1/2009) Pnaject Capital Cost $ 1.120.000 (input protect cosl for payback period cak:) 20 yr Net Present Value $ 974.078 NPV Payback Pehod 10.7 years Annual KWhrs Power Annual Minus Net Elect Sell Demand REC Net Meter Year Produced Operating Hours Annual kWhrs Meter KWhrs Rate Revenue Savings Revenue Offsets OAM Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs $/kWhr £ £ £ $ £ £ 0 S (1.120,000) 0 1 157 7705 1,210.424 1,045,424 0.0934 $ 97,672 £ 6,600 £ 29,000 £ (12,104) $ 121,168 £ (1,004,050) 1 2 157 7705 1,210.424 1.045424 0.0934 £ 97,672 £ 6,930 £ 30.450 $ (12,467) $ 122,585 £ (891,795) 2 3 157 7705 1,210.424 1.045,424 0,0934 £ 97,672 £ 7.277 £ 31,973 S (12,841) $ 124,080 £ (783,064) 3 4 157 7705 1,210,424 1,045,424 0 0934 £ 97,672 £ 7.640 £ 33,571 $ (13,227) $ 125,657 $ (677,693) 4 5 157 7705 1,210,424 1,045,424 0.0934 $ 97.672 £ 8,022 £ 35.250 £ (13.623) $ 127,321 £ (575,534) 5 6 157 7705 1,210.424 1,045,424 0.0934 $ 97,672 £ 8,423 £ 37,012 $ (14,032) $ 129,076 $ (476,407) 6 7 157 7705 1,210,424 1.045.424 0-0934 £ 97,672 $ 8,845 £ 38,863 S (14,453) $ 130,927 £ (380,198) 7 6 157 7705 1,210,424 1,045,424 0.0934 £ 97,672 $ 9.287 $ 40,806 $ (14.887) $ 132,878 £ (286,760) 6 9 157 7705 1.210,424 1,045.434 0 0934 £ 97,672 $ 9.751 £ 42,846 £ (15,333) $ 134,936 £ (195,961) 9 10 157 7705 1,210,424 1,045.424 0-0934 £ 97,673 $ 10,239 $ 44,989 £ (15,793) $ 137,106 £ (107,674) 10 11 157 7705 1,210,424 1,045.424 0.1522 £159,098 $ 10,751 £ 47,238 £ (16,267) $ 200.820 $ 16,070 11 12 157 7705 1,210,424 1,045,424 0.1522 $159,008 £ 11,288 £ 49,600 £ (16,755) S 203,231 £ 135.908 13 13 157 7705 1,210,424 1,045.424 0-1522 £159,098 $ 11,853 £ 52.080 £ (17,258) $ 205,773 £ 353,030 13 14 157 7705 1,210,424 1,045.424 0.1522 £159,098 £ 13,445 £ 54,684 $ (17,775) $ 208,492 £ 364,578 14 15 157 7705 1,210,424 1,045.424 0.1522 $159,098 $ 13,068 £ 57.418 £ (18,309) $ 211,275 $ 473,748 15 16 157 7705 1,210,424 1.045.424 0.1522 £159,098 $ 13,721 £ 60.289 £ (18,858) $ 214,250 £ 579,688 16 17 157 7705 1,210,424 1.045,424 0-1522 £159,098 $ 14,407 £ 63.303 £ (19,424) $ 217,385 £ 682,550 17 18 157 7705 1,210,424 1.045,424 0,1522 $159,098 £ 15,127 £ 66,469 £ (20,006) $ 220,687 $ 782.477 18 19 157 7705 1,210,424 1.045.424 0.1522 $159,098 $ 15,884 £ 69,792 £ (20,607) $ 224.167 $ 879,609 19 20 157 7705 1,210,424 1,045,424 0.1522 £159,098 S 16,678 £ 73.282 £ (21,225) $ 227.833 £ 974,078 20 TOTAL 24,208,482 968339 242085 £ 3,419,606 Carollo Engineers CarlsbadHydro_NPV_rev1 .xls 7 75 NPVpeak Client: Carlsbad Municipal Water Distnct Project: Hydroeleclric Turbine al Maerkle Reservoir By: CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job *: 8362A10 Aitemative No. 11 Turbine NPV Analysis - Assuming Running Turbine During Peak Periods =in put Commenis; Turbine Flow 7.2 cfs = 4.6 mgd (3,6 + 3.6 cfs) Number of Turbines 1 each Turbine Eff 80% Generator Eff 0.93 Head Differential 300 n = 130 psi Generator Power 136 kW 182 hp REC Revenue $0.04 (if using Feed in Tariff. SDGE claims REC's) Total Hours/yr 8760 hrs Adequate Flow Available % Availability % In Service Hours/yr - TURBINE 1 7SB1 hrs (refer lo TurbineAvailabiiitv.xis') In Service Hours/yr - TURBINE 2 0 hrs Percentaqe Hours ON PEAK 36% Percentage Hours OFF PEAK 64% O&M Rate SO.OI S/kWhr Base Rate $0.0884 S/kWhr Based on SDGE MPR Schedule for 10 year conlracl (2011) Percent of Annual Hours On Peak Rate Summer (year 1) $0.1451 ykWhr Based on SDGE TOO Penods 31% 11% 880 On Peak Rsle Winter (year 1) $0.1054 VkWhr Based on SDGE TOO Pertods 69% 25% 1958 Semi-peak Summer (year 1) $0.0920 Smihi Based on SDGE TOT Penods 7% 6% 469 Semi-peak Winter (year 1) S0.0954 $/kWhr Based on SIX^ TOD Pertods 16% 13% 1059 Off Peak Rate Summer (year 1) $0.0781 ykWhr Based on SOGE TOD Periods 16% 14% 1083 Off Peak Rale Winter (year 1) $0.0701 $/kWhr Based on SDGE TOD Periods 37% 31% 2432 Average Rate $0.0930 (weighted avg) 100% 7.881 Inflation (elect and REC) 5.0% %/yr (used to cak: MPR rale tor 3nd 10 yr conlracl) Inflation (OSM) 3% Revenue ftom Elect Bill Net Meter $29,000 (based on Maedde Reservoir 2009 partial elect bills; extrapolaled for 12 mos) Nel Meter Enerqy 165.000 kWhrs (based on Maertde Reservoir 2009 partial elect bills; exirapolaled for 12 mos) Discount Rate 4.5% (Based on letter from CMWD. (Response to Request for Informafion. dated 10/1/2009) Proiect Capital Cost $ 1,290,000 (input project cost for payback period calc) 20 yr Net Present Value $ 609.185 NPV Payback Period 13 6 years Annual KWtirs Power Annuat Minus Net Elect Sell Demand REC Net Meter Year Produced Operatinq Hours Annual KWhrs Meter KWhrs Rate Revenue Savinqs Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs KWhrs SftWhr $ £ £ £ S $ 0 S (1,290,000) 0 1 136 7881 1,069.963 904.963 0.0930 £ 84,201 $ 6,600 £ 29,000 £ (10,700) S 109,101 $ (1,185.597) 1 2 136 7881 1,069,963 904.963 0.0930 £ 84,201 $ 6,930 £ 30,450 £ (11,021) £ 110,560 £ (1,084,354) 2 3 136 7681 1,069,963 904,963 0.0930 £ 84,201 £ 7,277 £ 31,973 £ (11,351) S 112,098 $ (986,122) 3 4 136 7881 1,069,963 904.963 0.0930 £ 84,201 £ 7,640 £ 33,571 £ (11,692) $ 113,720 $ (890,761) 4 5 136 7881 1,069,963 904,963 0.0930 $ 84,201 £ 8.022 £ 35,250 £ (12,043) $ 11S.430 $ (798,134) 5 6 136 7881 1,069,963 904,963 0.0930 £ 84,201 £ 8,423 $ 37,012 S (12,404) $ 117,233 $ (708,112) 6 7 136 7881 1,069,963 904,963 0.0930 S 84,201 $ 8,845 £ 38,863 £ (12,776) $ 119.132 £ (620,570) 7 8 136 7881 1,069,963 904,963 0 0930 £ 84,301 £ 9,287 £ 40,806 £ (13,159) $ 121,134 $ (535,390) 6 9 136 7881 1,069,963 904,963 0.0930 $ 84,201 $ 9.751 $ 42,646 $ (13,554) $ 123,244 £ (452,458) 9 10 136 7861 1.069.963 904,963 00930 $ 84,201 £ 10.239 £ 44,989 £ (13.961) $ 125,467 $ (371,667) 10 11 136 7881 1.069.963 904,963 0-1516 £137,154 £ 10.751 $ 47,238 S (14.379) $ 180,763 £ (260,280) 11 12 136 7881 1,069,963 904,963 0.1516 £137,154 £ 11,288 £ 49,600 £ (14,811) $ 183,231 £ (152,236) 12 13 136 7881 1,069,963 904,963 0-1516 £137.154 £ 11,653 $ 52,080 $ (15,255) $ 185,831 £ (47,376) 13 14 136 7881 1,069,963 904.963 0.1516 $137,154 £ 12,445 £ 54,684 £ (15,713) S 188,570 £ 54,447 14 15 136 7881 1,069,963 904,963 0.1516 £137,154 S 13,068 £ 57,418 £ (16,164) $ 191,455 $ 153,376 15 16 136 7881 1.069.963 904.963 0 1516 £137,154 S 13,721 $ 60,289 $ (16,670) $ 194,494 S 249,547 16 17 136 7881 1,069,963 904.963 0.1516 £137,154 £ 14,407 £ 63,303 £ (17,170) $ 197,895 S 343,092 17 18 136 7881 1,069,963 904,963 0,1516 £137.154 £ 15,127 £ 66.469 £ (17,685) % 201,065 $ 434,134 18 19 136 7881 1,069,963 904.963 0 1516 $137,154 £ 15,884 $ 69.792 $ (18,215) $ 204,614 $ 522,794 19 30 136 7881 1^69,963 904,^963 0,1518 $137,154 £ 16,678 $ 73.282 $ (18,762) $ 208,352 £ 609,185 20 TOTAL 21.399,251 855970 213993 £3,103,192 Carollo Engineers 2/16/2010 CarlsbadHydro_NPV_rev1 .xls (2)3,6NPVpeak Client: Carlsbad Municipal Water District Project: Hydroeleclric Turbine at Maerkle Reservoir By: CTC Date Created; 10/30/2009 Printed Date: 2/16/2010 Job*: 8362A10 Aitemative No. 12 Turbine NPV Analysis - Assuming Running Turbine During Peak Periods =input Comments: Turbine Flow 11 cfs = 7.1 mgd Number of Turbines 1 each Turbine Eff D.8« Generator Eff 0.93 Head Differentia) 300 n = 130 psi Generator Pow^r 223 kW 399 hp REC Revenue $0.04 $/KWhr (if usinq Feed in Tariff, SDGE claims RECs) Total Hours/vr 8760 hrs Adequate Flow Available % Availability % In Service Hours/yr - TURBINE 1 6220 hrs (refer to TurbineAvailatiility.xJs') In Service Hours/yr - TURBINE 2 0 hrs Percentaqe Hours ON PEAK 45% Percentage Hours OFF PEAK 55% O&M Rale $0.01 $/JflNhr Base Rate $0.0884 SlkVJhr Based on SDGE MPR Schedute for 10 year contract (2011) Percent of Annual Hours On Peak Rate Summer (year 1) $0.1451 £/kWhr Based on SDGE TOD Periods 31% 14% 868 On Peak Rate Winter (year 1) $0.1054 £/kWhr Based on SDGE TOD Periods 69% 31% 1931 Semi-peak Summer (year 1) $0.0920 £AWhr Based on SDGE TOD Periods 7% 5% 318 Semi-peak Winter (year 1) $0.0954 ykWhr Based on SDGE TOD Periods 16% 12% 718 Off Peak Rate Summer (year 1) $0.0781 £/kWhr Based on SDGE TOD Penods 16% 12% 735 Off Peak Rate Winter (year 1) $0.0701 £fltWhr Based on SDGE TOD Penods 37% 27% 1649 Average Rate $0.0965 (weighted avg) 100% 6.220 Inftation (elect and REC) 5.0% %/vr (used lo calc MPR rate tor 2nd 10 yr contract) Inflation (O&M) 3% Revenue from Elect Bill Net Meter $29,000 (based on Maeride Resenrair 2009 partial elect bills; exftapolaled for 13 mos) Net Meter EnerdV 165.000 kWhrs (based on Maeride Reservoir 2009 partial elect bills: extrapolated for 12 mos) Discount Rate 4.5% (Based on letter from CMWD, (Response lo Request tor Infonnaeon dated 10/1(2009) Proiect Capital Cost $ 1.150,000 (input project cost for payback period calc) 20 yr Net Present Value $ 1,242,891 NPV Payback Period 9.6 years Annuat kWhrs Power Annual Minus Net Elect Sell Demand REC Net Meter Year Produced Operatinq Hours Annual KWhrs Meter KWhrs Rate Revenue Savinqs Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs £/kWhr £ £ $ £ £ $ 0 1 223 6220 1,386,904 1,221,904 0 0965 £117,926 £ 6.600 $ 29,000 £ (13.869) £ 139,657 S S (1,150.000) (1,016,357) 0 1 2 223 6220 1,386,904 1,221.904 0.0965 £117.926 £ 6,930 £ 30,450 $ (14,285) £ 141,021 £ (887.220) 3 3 223 6220 1,386,904 1.221.904 0.0965 $117,926 £ 7.277 £ 31,973 £ (14,714) $ 142,461 £ (762,382) 3 4 223 6220 1,386,904 1,221.904 0.0965 $117,926 $ 7,640 $ 33,571 $ (15.155) $ 143.982 £ (641.644) 4 5 223 6220 1.386.904 1,221,904 0.0965 $117,926 £ 8,022 $ 35,250 £ (15,610) $ 145,588 £ (524,816) 5 6 223 6220 1.386,904 1,221.904 0.0965 $117,926 $ 8,423 £ 37,012 £ (16,078} $ 147.284 £ (411,718) 6 7 223 6220 1,386,904 1,221,904 0.0965 £117,926 £ 8,845 $ 38,863 £ (16,560) $ 149,073 $ (302,175) 7 8 223 6220 1,386,904 1,221.904 0.0965 £117,926 $ 9,287 £ 40,806 £ (17.057) $ 150,962 $ (196,021) 8 9 223 6220 1,386,904 1,231,904 0.0965 $117,926 $ 9,751 £ 42,846 $ (17.569) $ 152,954 £ (93,097) 9 10 223 6220 1.386,904 1,221,904 0,0965 $117,926 $ 10,239 £ 44,989 £ (18,096) $ 155,057 $ 6,748 10 11 223 6220 1,386,904 1,221.904 0 1572 $192,089 $ 10,751 £ 47,239 £ (16,639) £ 231,439 $ 149,361 11 12 223 6220 1,386,904 1,221,904 0.1572 $192,089 $ 11,288 £ 49,600 $ (19.198) $ 233,779 $ 287,212 12 13 223 6220 1,386,904 1,221.904 0-1572 £192,089 £ 11,853 £ 52.080 £ (19,774) S 236,247 £ 420,519 13 14 223 6220 1.386,904 1.221,904 01572 £192,089 £ 12.445 $ 54.684 £ (20,367) $ 238,851 $ 549,492 14 15 223 6220 1,366,904 1,221,904 0.1572 £193.089 £ 13,068 £ 57.418 £ (20,978) $ 241,596 £ 674,330 15 16 223 6220 1.386,904 1,221,904 0-1572 £192,089 £ 13.731 $ 60.289 £ (21,608) $ 244,491 £ 795.223 16 17 223 6220 1,386.904 1.221.904 0.1572 £192,089 $ 14.407 £ 63.303 $ (22,256) $ 247.543 £ 912.355 17 18 223 6220 1,386,904 1,221,904 0.1572 £192,089 £ 15,127 £ 66.469 £ (22,923) $ 250,761 £ 1.025.900 18 19 223 6220 1,386,904 1.221.904 0,1572 £192,089 $ 15.884 £ 69.792 $ (23,611) $ 254,153 £ 1,136,025 19 20 223 6220 1,386,904 1,221.904 0,1572 $192,089 $ 16,678 $ 73.282 £ (24,319) $ 257,729 £ 1,242,891 20 TOTAL 27,738,072 1109523 277381 $ 3,904,630 Carollo Engineers CarlsbadHydn3_^NPV_revl .xls 11 NPVpeak Clieni: Project: By: Date Created: Printed Date: Job*: Alternative No. Carisbad Municipal Water District HydroelectFic Turbine al Maerkle Reservoir CTC 10/30/2009 2/16/2010 8362A10 13 Turbine NPV Analysis - Assuming Running Turbine During Peak Periods =inpiil Turbine Flow 10.35 cfs = 6,7 ntqd (6.75* 3.6 cfe) Nun*er of Turbines 2 each Turbine Eff 0.83 (weii^ted avq of two effs) Generator Eff 0.93 Head Differential 300 ft = 130 Dsi Generator Power 202 kW 271 hp REC Revenue $0.04 SftWhr (if using Feed in Tariff, SDGE claims RECs) Tolal Hours/yr 8760 hrs Adequate Flow Available % Availability % tn Service Hours/yr - TURBINE f £568 hrs (refer to TurbneAvailabilily.xfs') In Service Hours/yr - TURBINE 2 0 hrs Percentage Hours ON PEAK 43% Percentaqe Hours OFF PEAK 57% O&M Rate $0.01 $/kWhr Baseplate $0.0884 3/kWhr Based on S(X3E MPR Schedt/te fisf 10 year contract (2011) Percent of Annual Hours On Peak Rale Summer (year 1) $0.1451 £rt(Whr Based on SDGE TOD Periods 31% 13% 875 On Peak Rate Winter (year 1) $0.1054 $/kWhr Based on SIX3E TOD Periods 69% 30% 1949 Semi-Peak Summer (year 1) $0,0920 SAcWhr Based on SDGE TOO Penods 7% 5% 348 Senn-peak Winter [year 1) $0.0954 S/kWhr Based on SDGE TOO Periods 16% 12% 786 Off Peak Rate Summer (year 1) $0.0781 ykWhr Based on SDGE TOD Periods 16% 12% 804 Oft Peak Rate Winter (year 1) $0.0701 ykWhr Based on SDGE TOD Periods 37% 27% 1805 Average Rate $0.0957 (weighted avq) 100% 6.568 Inftation (elect and REC) 5.0% %/yr (used to cak: MPR rale lor 2nd 10 yr contract) Inflation (O&M) 3% Revenue from Elect Bill Net Meter $29,000 (based on MaeiMe Reservoir 2009 partial elect bills; exbapolated for 12 mos) Net Meter Enerav 165.000 kWhrs (based on Maerkle Reservoir 2009 partial eled biHs; extrapolaled tor 12 mos) Discount Rate 4.5% (Based on letter from CMWD, Response lo Request for IntiannaUon, daled 10/1/2009) Project Capital Cosl $ 1,340.000 (input project cost for payback period calc) 20 yr Net Present Value £ 958,606 NPV Payback Period 11.7 years Annual KWhrs Power Annual Minus Nel Etect Sell Demand REC Net Meter Year Produced Operatinq Hours Annual KWhrs hleter KWhrs Rate Revenue SavirHis Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs $/kWhr £ $ £ $ £ £ 0 1 202 6568 1,329,838 1.164.838 0.0957 £111,521 £ 6,600 £ 29.000 £ (13,298) $ 133,823 $ (1,340,000) £ (1.211,940) 0 1 2 202 6568 1,329,838 1.164.838 0.0957 £111,521 £ 6,930 £ 30,450 $ (13,697) S 135,204 $ (1,088,130) 2 3 202 6568 1,329,838 1,164,838 0.0957 £111,521 £ 7,277 £ 31,973 $ (14,108) $ 136,662 $ (968,373) 3 4 202 6568 1,329,838 1.164,838 0.0957 $111,521 $ 7,640 $ 33,571 $ (14,531) $ 138,201 $ (852,483) 4 5 202 6566 1.329,838 1,164,638 0.0957 £111,521 $ 9,022 S 35,250 £ (14,967) $ 139,826 £ (740,280) 5 6 202 6568 1.329,838 1,164,638 0 0957 £111.521 S 8,423 $ 37,012 £ (15,416) $ 141,540 s (631,592) 6 7 202 6566 1,329.838 1,164,838 0.0957 £111,521 $ 8,845 S 38,863 $ (15,879) $ 143,350 £ (526.254) 7 8 202 6568 1,329,838 1,164.838 0.0957 £111,521 $ 9,287 £ 40,806 $ (16,355) $ 145.259 £ (424.111) 8 9 202 6566 1,329,838 1.164.838 0.0957 £111.521 £ 9,751 $ 42,846 £ (16,846) $ 147,273 £ (325,010) 9 10 202 6568 1.329.838 1,164,838 0.0957 $111,521 $ 10,239 £ 44,969 $ (17,351) $ 149,397 £ (228,810) 10 11 202 6568 1,329,638 1,164,836 0.1559 £181,656 £ 10.751 $ 47,238 £ (17.872) $ 221.773 £ (92,153) 11 12 203 6568 1,329.838 1,164.838 0.1558 $181,656 $ 11,288 S 49,600 S (18,408) $ 224,136 $ 40,012 12 13 202 6568 1,329,838 1,164,838 0.1559 £181,656 £ 11,853 £ 52,080 £ (18,960) $ 226,628 $ 167,892 13 14 202 6568 1,329,838 1,164,838 0,1559 $181,656 £ 12,445 $ 54,684 £ (19,529) $ 229,256 £ 291,684 14 15 202 6568 1,329,838 1,164,838 0.1559 £181,656 £ 13,068 £ 57.418 £ (20,115) s 232,027 £ 411,577 15 16 202 6568 1,329,838 1.164,838 0.1559 £181,656 £ 13,721 £ 60,289 £ (20,718) $ 234.948 £ 527,751 16 17 202 6568 1,329,838 1.164,836 0,1559 £181,656 £ 14,407 $ 63,303 £ (21,340) $ 238,027 $ 640,380 17 18 202 6568 1,329,838 1,164.838 0.1559 £181,656 $ 15,127 S 66.469 $ (21,980) $ 241,272 £ 749,628 18 19 202 6568 1,329,838 1,164,838 0.1559 £181,656 $ 15.884 $ 69,782 £ (22.640) $ 244,692 £ 855.653 19 20 202 6568 1,329.838 1,164,838 0.1559 £181,656 £ 16,678 £ 73,282 £ (23,319) $ 248,297 £ 956,608 20 TOTAL 26.596,761 1063870 265968 $3,751,589 Carolto Engineers 2/16/2010 CarlsbadHydrD_NPV_^revl .xls 3.6-6.75NPVpeak it tl m til ell Client: Carlsbad Municipal Water District Project: Hydroelectric Turbine al Maerkle Reservoir By: CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job#: 8362A10 Aitemative No. 14 Turbine NPV Analysis - Assuming Running Turbine During Peak Periods =input Comments Turbine Flow 9.95 cfs = 6 4 mqd (7.75 • 2.2 cfs) Number of Turbines 1 each Turbine Eff 0.84 (weic^iled avq of two effs) Generator Eff 0.93 Head Differential 300 ff = 130 psi Generator Powef 197 kW 264 hp REC Revenue S0.04 $/kWhr (if usinq Feed in Tariff, SDGE claims RECs) Total Hours/yr 8760 hrs Adequate Flow Available % Avaitabilitv % In Service Hours/yr - TURBINE 1 6769 hrs (refer lo TurbineAvailatJilitv.xIs') in Service Hours')^ - TURBINE 2 0 hrs Percentaoe Houfs ON PEAK 41% Percentaqe Hour's OFF PEAK 59% O&M Rate $0.01 SAWhr Base Rale $0.0884 $/kWhr Based on StXJE MPR Schedifle for 10 year contract (2011) Percent of Annual Hours On Peak Rale Summer (year 1) $0.1451 $/kWhr Based on SDGE TOD Periods 31 % 13% 860 On Peak Rale Winter (year 1) $0.1054 ykWhr Based on SDGE TOD Periods 69% 28% 1915 Semi-peak Summer (year 1) $0.0920 £fl(Whr Based on SDGE TOD Penods 7% 5% 372 Semi-peak Winter (year 1) $0.0954 $/kWhr Based on SDGE TOD Periods 16% 12% 839 Off Peak Rale Summer (year 1) $0.0781 SfltWhr Based on SDGE TOD Perkxls 16% 13% 858 Off Peak Rate Winter (year 1) $0.0701 $fl<Whr Based on SDGE JOO Penods 37% 28% 1925 Average Rate $0.0950 (weighted avg) 100% 6,769 Inflation (elect and REC) 5.0% %/vr (used lo calc MPR rate for 3nd 10 yr contract) inflalion (O&M) 3% Revenue from Elect Bill Net Meier $29,000 (based on Maertde Reservoir 2009 partis elect bils; exftapolaled for 12 mos) Net Meter Enertjy 1S5.000 kWhrs (based on Maerkle Reservoir 2009 parlial eiect bills; extrapolsled for 12 mos) Discount Rate 4.5% (Based on letter from CMWD, Response lo Request (or Informabon dated 10/1/3009) Project Capital Cost $ 1.290,000 (input project cost for payback period calc) 20 yr Nel Present Value $ 999,079 NPV Payback Period 11,3 years Annual kWhrs PovKcr Annual Minus Net Elect Sell Demand REC Net Meter Year Produced Operatinq Hours Annual KWhrs Meter kWhrs Rate Revenue Savinqs Revenue Offsets O&M Costs Net Total NPV Year Unil kW hrs/year kWhrs kWhrs $/kWhr £ £ £ $ £ $ 0 1 197 6769 1,333,496 1,168.496 0,0950 $110,971 £ 6.600 $ 29,000 £ (13.335) $ 133,236 £ £ (1,290,000) (1,162,501) 0 1 2 197 6769 1,333,496 1,168.496 0 0950 $110,971 £ 6,930 $ 30,450 £ (13,735) $ 134,616 £ (1,039,229) 2 3 197 6769 1,333,496 1.168,496 0-0950 £110,971 £ 7,277 $ 31,973 £ (14,147) $ 136,073 £ (919.989) 3 4 197 6769 1.333,496 1,168,496 0 0950 £110,971 £ 7,640 £ 33,571 £ (14.571) $ 137,611 £ (804,593) 4 5 197 6769 1,333,496 1,168,496 0.0950 $110,971 $ 8,022 £ 35,250 $ (15,009) $ 139,235 £ (692.865) 5 6 197 6769 1,333,496 1,168,496 0.0950 $110,971 $ 8423 £ 37.012 $ (15,459) $ 140,948 £ (584,631) 6 7 197 6769 1,333,496 1,168,496 0.0950 $110,971 $ 8.845 £ 38,863 £ (15,923) S 142,756 £ (479.730) 7 8 197 6769 1,333,496 1,168.496 0,0950 $110,971 $ 9,287 £ 40.806 $ (16,400) $ 144,664 £ (378,005) 8 9 197 6769 1,333,496 1,168,496 0.0950 £110,971 £ 9.751 £ 42.846 $ (16,892) $ 146.676 £ (279,306) 9 10 197 6769 1,333.496 1,168,496 0.0950 £110,971 £ 10,239 $ 44.989 $ (17,399) s 148.799 $ (183,490) 10 11 197 6769 1.333,498 1,168,496 0 1547 £180,760 $ 10,751 $ 47.238 $ (17,921) s 220,828 £ (47,416) 11 12 197 6769 1,333,496 1,168,496 0 1547 $180,760 £ 11,288 $ 49,600 £ (18,459) $ 223,190 £ 84,191 12 13 197 6769 1,333,496 1.168,496 0.1547 £180.760 £ 11,853 £ 52,080 $ (19,012) $ 229,680 $ 211,536 13 14 197 6769 1.333496 1.168,496 01547 £180.760 $ 12,445 £ 54,684 £ (19,583) $ 228,307 £ 334,815 14 15 197 6769 1,333,496 1.168,496 01547 $180,760 $ 13,068 $ 57,418 £ (20,170) $ 231,076 £ 454,217 15 16 197 6769 1,333496 1,168,496 0.1547 £180,760 £ 13,721 £ 60.289 £ (20,775) $ 233,995 S 569,920 16 17 197 6769 1,333,496 1,168,496 0.1547 £180,760 £ 14,407 £ 63,303 $ (21,399) $ 237,072 £ 682.097 17 18 197 6769 1,333,496 1,168,496 0,1547 $180,760 $ 15,127 £ 66,469 $ (22,041) $ 240,316 £ 790,912 18 19 197 6769 1,333,496 1,168,496 0.1547 £180,760 $ 15.884 £ 69.792 $ (22,702) $ 243.734 $ 896.522 19 20 197 6769 1,333,496 1,168,496 0.1547 £ 180,760 $ 18.678 £ 73,282 $ (23.383) $ 247.337 $ 999,079 20 TOTAL 26.669,915 1066797 266699 £3.736,14/- Carollo Engineers CarlsbadHydro_NPV_revl .xls 7.75-2-2NPVpeak Client: Cartsbad Municipal Water Dislricl Project: Hydroelectric Turbine at Maeride Reservoir By; CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job #: 8362A10 15 Alternative NQ. Turbine NPV Analysis - Assuming Running Turbine During Peak Periods =input (Commenis: Turbine Flcwv 10 cfs = 6.5 mgd Number of T urbines 1 each Turbine Eff 0.86 Generator Eff 0.93 Head Differential 300 ft = 130 psi Generator Power 203 kW = 272 hp REC Revenue $0.04 JAWhr [if usinjf Feed in Tariff. SDGE daims RECS) Tolal Hours/yr 8760 hrs Adequale Ftow Available % AvailabiHty % In Service Hours/vr - TURBINE 1 6769 hrs (refer to TurbineAvaaability.xls') In Service HoursAir - TURBINE 2 0 hrs Percenlape Hours ON PEAK 41% Percentage Hours OFF PEAK 59% O&M Rate $0.01 ykWhr Base Rate $0.0884 $fl(Whr Based on SDGE MPR Schedule for 10 year contrad (3011) Percent of Annual Hours On Peak Rate Summer (year 1) $0.1451 £/kWhr Based on SDGE TOD Periods 31% 13% 860 On Peak Rate Winter (vear 1) $0.1054 $fl(Whr Based cn SDGE TOO Periods 69% 28% 1915 Semi-peak Summer (vear 1) $0.0920 £/kWhr Based on SDGE TOO Periods 7% 5% 372 Semi-peak Winter (year 1) $0.0954 Based on SOGE TOD Penods 16% 12% 839 Off Peak Rate Summer (vear 1) $0.0781 £AWhr Based on SDGE TOD Perkxts 16% 13% 858 Off Peak Rale Winter (year 1) $0.0701 $rtiWhr Based on SDGE TOD Penods 37% 28% 1925 Average Rate $0.0950 [vrek^hted avQl 100% 6,769 Inflation (elect and REC) 3.0% %/yr (used to cak: MPR rate for 2nd 10 vr contract) Inflalkxi (OSM) 3% Revenue from Elect Bill Net Meter $29,000 (based on MaerUe Reservoir 200S partol elect blNs; extrapolated tor 12 mos} Nel Meter En^rov 165.000 kWhrs (based on Maerkle Reservoir 2009 partial elect bins; extrapolated for 12 mos) Discount Rate 4.5% (Based on letttf from CMWD. Response to Request for Information, dated 10/1/2009) Proiecl Capitat Cosl S 1,130,000 (input project cosl for paytiack period cak:) 20 yr Nel Present Value S 1,212,062 NPV Payback Period 96 years Annual KWhrs Power Annual Minus Net Elect Sell Demand REC Net Meter Year Produced Operating Hours Annual KWhrs Meter KWhrs Rate Revenue Savings Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs £fl(Whr £ £ S £ $ £ 0 £ (1,130,000) 0 1 203 6769 1,372,106 1,207,106 0.0950 $114,638 £ 6.600 £ 29,000 £ (13,721) $ 136,517 $ (999,362) 1 2 203 6769 1,372,106 1,207,106 0,0950 $114,638 £ 6,930 $ 30,450 £ (14.133) $ 137,885 $ (873,096) 2 3 203 6769 1,372,106 1,207,106 0.0950 $114,638 $ 7,277 $ 31,973 £ (14,557) $ 139,330 $ (751,002) 3 4 203 6769 1,372,106 1,207,106 0.0950 £114.638 £ 7,640 $ 33,571 £ (14,993) $ 140,856 $ (632,885) 4 5 203 6769 1,372,106 1.207,106 0.0950 £ 114,638 £ 8,022 $ 35,250 S (15,443) $ 142,467 $ (518,562) 5 6 203 6769 1,372,106 1,207,106 0.0950 £ 114.638 £ 8.423 $ 37,012 £ (15,906) $ 144,167 $ (407,857) 6 7 203 6768 1,372.106 1,207,106 0.0950 $ 114,638 5 8.845 S 38,863 J (16.384) J 145,962 S (300,600? 7 8 203 6769 1,372,106 1,207,106 0.0950 £114,638 $ 9,287 £ 40,806 £ (16,875) $ 147,856 £ (196,631) 8 9 203 6769 1,372,106 1,207,106 00950 $114,638 $ 9,751 £ 42,846 $ (17,381) S 149.854 £ (95,793) 9 10 203 6769 1,372,106 1,207.106 0.0950 $114,638 £ 10,239 £ 44,980 £ (17,903) $ 151,962 £ 2,060 10 11 203 6769 1,372,106 1,207,106 0,1547 £186,733 S 10,751 £ 47,238 $ (18,440) $ 226,282 £ 141,494 11 12 203 6769 1,372.106 1,207,106 0-1547 £186.733 £ 11,288 £ 49,600 $ (18,993) $ 228,628 $ 276,308 12 13 203 6769 1,372,106 1,207,106 0.1547 £ 186,733 £ 11,853 $ 52,080 $ (19,563) $ 231,103 $ 406,713 13 14 203 6769 1.372,106 1,207,106 0.1547 £186.733 £ 12.445 $ 54,684 £ (20,150) $ 233,712 £ 532,911 14 15 203 6769 1.372,106 1,207,106 01547 $ 136,733 £ 13,068 $ 57,418 £ (20,754) $ 236,464 $ 655,097 15 16 203 6769 1,372,106 1,207,106 0.1547 £ 186,733 £ 13,721 £ 60,289 $ (21,377) $ 239.366 $ 773,456 16 17 203 6769 1,372,106 1,207,106 0.1547 £186,733 £ 14,407 £ 63,303 $ (22,018) $ 242,425 £ 888.166 17 18 203 6769 1,372,106 1,207.106 0,1547 $186,733 £ 15,127 £ 66,469 $ (22.679) $ 245,650 £ 999,396 18 19 203 6769 1,372,106 1.207,106 0-1547 £186,733 $ 15,884 $ 69,792 £ (23,359) $ 249,050 £ 1,107,310 19 20 203 6769 1,372,106 1.207,106 0-1547 £186,733 £ 16,678 £ 73,282 $ (24,060) $ 252.633 £ 1,212,062 20 TOTAL 27,442.124 1097685 274421 £ 3,822,169 Carollo Engineers 2/16/2010 Car1sbadHydro_NPV_revl .xls 10 NPVpeak Client: Carlsbad Municipal Water Dislricl Project: Hydroelectric Turbine at Maerkle Reservoir By: CTC Date Created: 10/30/2009 Printed Date: 2/16/2010 Job#: 8362A10 Alternative No. 16 Turbine NPV Analysis - Assuming Running Turbine During Peak Periods =input Commenis: Turbine Flow 12 cts = 7,7 mqd Number of Turbines 1 each Turbine Eff OM Generator Eff 0.33 Head Differential 300 B = 130 psi Generator Power 243 KW 326 hp REC Revenue $0.04 $/kWhr (rt usinq Feed in Tariff, SDGE daims RECs) Total Hours/yr 8760 hrs Adequate Flow Available % Availability % In Service Hours/yr - TURBINE 1 9704 hrs (reter to TurbffieAvailability.xls') In Service Hours/yr - TURBINE 2 0 hrs Percentaqe Hours ON PEAK 49% Percentaqe Hours OFF PEAK 51% OSIVI Rate $0.01 $/kWhr Base Rate $0.0884 $AWbr Based on SDGE MPR Schedule to 10 year conlracl (2011) Percent ot Annual Hours On Peak Rate Summer (year 1) $0.1451 $/kWhr Based on SDGE TOD Penods 31 % 15% 866 On Peak Rate Winter (year 1) $0.1094 £/kWhr Based on SDGE TOO Pertods 69% 34% 1929 Semi-peak Summer (vear 1) $0.0920 £/kWhr Based on SDGE TOD Periods 7% 5% 271 Serrw-peak Winter (vear 1) $0.0954 S/kWhi Based on SDGE TOD Periods 16% 11% 611 Off Peak Rate Summer (year 1) $0,0781 $/kWhr Based on SDGE TOD Penods 16% 11% 625 Off Peak Rate Winter (year 1) $0.0701 £/kWhr Based on SDGE TOO Perkxls 37% 25% 1402 Average Rate $0.0981 (wenjited avq) 100% 5,704 Inflation (elect and REC) 9.0% %/yr (used to c^c MPR rale lor 2nd 10 yr contract) Inflation (0£M) 3% Revenue from Elect Bill Net Meter $29,000 (based on Maeikle Reservoir 2009 partial elect bills; extrapolated for 13 mos) Net Meter Enerqy 16S.000 kWhrs (based on Maeikle Reservoir 2009 partial elect bills; extrwotated for 12 mos) Discount Rate 4.3% (Based on letter from CMWD, Response to BequesI for InfOmiatron. dated 10/1/2009) Projecl Capital Cosl $ 1,160^ (input project cost for payback period calc) 20 yr Net Present Value $ 1,264,220 NPV Payback Period 96 years Annual kWhrs Power Annual Minus Net Elect Sell Demand REC Net Meter Year Produced Operating Hours Annual KWhrs Meter KWhrs Rate Revenue Savinqs Revenue Offsets O&M Costs Net Total NPV Year Unit kW hrs/year kWhrs kWhrs $/kWhr £ $ $ £ $ $ 0 £ (1,160,000) 0 1 243 5704 1,387.471 1.222,471 0.0981 £119.864 £ 6,600 £ 29.000 $ (13.875) £ 141,590 $ (1.024,508) 1 2 243 5704 1,387.471 1.222,471 0 0981 £119.864 £ 6.930 £ 30.450 £ (14,291) $ 142,953 £ (893,601) 2 3 243 5704 1,387,471 1,222.471 0.0981 $119,864 £ 7.277 £ 31.973 £ (14,720) $ 144,394 £ (767,069) 3 4 243 5704 1,387.471 1,222.471 0.0981 £119,864 £ 7,640 £ 33.571 £ (15,161) $ 145.914 £ (644,711) 4 5 243 5704 1,387,471 1,222.471 0.0981 £119,864 £ 8.022 £ 35,250 £ (15,616) $ 147,520 £ (526,334) 5 6 243 5704 1,387,471 1,222,471 0.0981 £119.864 £ 8.423 £ 37.012 £ (16,085) S 149,215 £ (411.752) 6 7 243 5704 1,387,471 1,222471 0 0981 £119.864 $ 8,845 £ 38.863 £ (16,567) $ 151,004 £ (300.789) 7 8 243 5704 1,387,471 1,222,471 0.0981 £119,864 £ 9,287 £ 40,806 £ (17,064) $ 152,893 $ (193,277) 6 9 243 5704 1.387.471 1,222,471 0,0981 $119,864 £ 9,751 $ 42,846 $ (17,576) $ 154,886 £ (89,054) 9 10 243 5704 1.387.471 1,222,471 0.0981 £119.864 £ 10,239 $ 44,989 £ (18,103) $ 156,988 £ 12.035 10 11 243 5704 1,387,471 1,232.471 0 1597 $195,246 $ 10,751 S 47,238 $ (18.646) S 234,988 156,588 11 12 243 5704 1.387.471 1,222,471 0.1597 £195,246 £ 11,288 $ 49.600 £ (19,206) $ 236,928 $ 296.296 12 13 243 5704 1,387.47! 1,222,471 0.1597 $195,246 £ 11,853 £ 52,080 £ (19.782) $ 239,397 £ 431.381 13 14 243 5704 1,387,471 1,222,471 0.1597 $ 195,246 £ 12,445 £ 54,684 £ (20,375) $ 242.000 £ 562.054 14 15 243 5704 1,387.471 1,222,471 0.1597 $195,246 $ 13,066 $ 57,418 £ (20.987) $ 244,745 $ 688,519 15 16 243 5704 1,387,471 1,222.471 0.1597 $195,246 $ 13,721 £ 60,289 £ (21.616) $ 247.640 £ 810.969 16 17 243 5704 1.387.471 1.222,471 0-1597 £195,246 $ 14,407 $ 63.303 £ (22.265) $ 250.692 £ 929,590 17 18 243 5704 1.387,471 1,222.471 01597 $195,246 £ 15,127 £ 66,469 £ (22,933) $ 253.909 £ 1,044.561 16 19 243 5704 1,387.471 1,222,471 0.1597 $195,246 $ 15,884 $ 69,792 £ (23,621) $ 257,301 £ 1,156,050 19 20 243 5704 1,387,471 1,222,471 0.1597 £195,246 $ 16.678 $ 73,282 $ (24,329) $ 260,876 $ 1,264,220 20 TOTAL 27.749,424 1109977 277494 $3,955,433 Carollo Engineers 2/16/2010 CarlsbadHydro_^NPV_revl ,xls 12 NPVpeak Client: Cartsbad Municipal Water District Project: Hydroelectric Tuitiirte al Maerkle Reservoir By: CTC bate Created: 10/30/2009 Printed Date: 2/24/2010 Job#: 8362A10 Alternative No. 17 Zeropex Unit NPV Analysts =input Commenis: Turbine Fkiw 7.7 cfs = 5.0 mgd = 218 l/s (if unit can only hande 8 cfs then the avq should be 7 cfs; Numt)er of Tuftiines 1 each (2 units bul modeled as one) if up lo 11 cfe then 7-8cfe; jf upto 10 cfs, then 7 7cfe) Water lo w^e Eff 0.75 Head Differential 334 fl = 145 psi Generator Power 163 kW 218 hp REC Revenue SrtWhr (Ff usinq Feed in Tariff, SDGE claims REC's) Total Hours/yr 87fi0 hrs Adequate Fkw Available 100.0% % (can accept varyirm fKiw rates) Availability 95% % In SsA-ice Hours.'vr - TURBINE 1 8322 hrs In Service Hours/vr - TURBINE 2 0 hrs O&M Rate S0.01 $/kWhr Base Rate $0.08M mWhT eased on SDGE MPR Schedule (ar 10 year conlracl (2011) Percent of Annual Hours On Peak Rale Summer (year 1) $0.1451 $/kWhr Based on SDGE TOD Perwds 7% On Peak Rats Winter (year 1) $0.1054 S/kWhr Based on SDGE TOD Periods 16% Semi-peak Summer (year 1) $0.0920 $/kWhr Based on SDGE TOD Penods 7% Semi-peak Winter (year 1) S0.0954 S/mhr Based on SDGE TOD Periods 16% Off Peak Rate Summer (year 1) $0.0781 S/kWhr Based on SDGE TOD Perkids 16% Off Peak Rale Winter (year 1) $0.0701 $/kWfir Based on SDGE TOD Periods 37% Average Rate $0.0881 (wekihled ava) Inflatbn (elect and REC) 5.0% %/vr (used to cak: MPR rate for 2nd 10 yr contract) infialion (OSM) 3% Revenue hwn Elect Bill Net Meter $29,000 (based on Maerkle Resen/oir 2009 partial elect bits; extrapolated for 12 mos) Net Meier Enerqy 165.000 kWhrs (based on Maertde Resenmir 2009 parlial elect bills; e>lrapolaled \or 12 mos) Discount Rate 4.5% (Based on letter from CMWD, Response to Request for Informalkin, dafed 10/1/2009) Project Capital Cost $ 1^10,000 (hput txoject capital cost for payback period calc) 20 yr Net Present Value $ 677,605 NPV Payback Period 13.8 years AnrHial KWhrs Power Annu^ Annual Minus Net Elect Sell Demand REC Net Meter Year Produced Operating Hours kWhrs Meter kWhrs Rate Revenue Savings Revenue Offsets O&M Costs Net Total NPV Year Unil kW hrs/year kWhrs kWhrs $fl<Whr S £ $ $ S S 0 1 163 8322 1,356,084 1,191,084 0.0881 $ 104,945 £ 6,600 £ 29,000 $ (13,561) £ 126,984 £(1,510,000) $(1,388,484) 0 1 2 163 8322 1,356,084 1,191.034 0,0881 £104,945 $ 6,930 $ 30.450 £ (13,968) $ 128.358 $(1,270,943) 2 3 163 8322 1,356,084 1.191,084 0.0881 £104,945 $ 7,277 $ 31,973 £ (14,387) $ 129,808 £(1,157.193) 3 4 163 8322 1.356,084 1,191,084 0.0881 $ 104,S45 S 7,640 S 33,571 S (f4,818) 1 131,335 $(1,047,058) 4 5 163 8322 1,356,084 1,191,084 0.0881 $ 104,945 £ 8,022 $ 35,250 $ (15,263) $ 132,954 $ (940,368) 5 6 163 8322 1,356,084 1,191.084 0-0881 $104,945 $ 8.423 $ 37,012 S (15,721) $ 134,660 $ (836,963) 6 7 163 8322 1,356,084 1,191,084 0-0881 £ 104,945 £ 8,845 $ 38,863 £ (16,192) S 136,460 $ (736,688) 7 8 163 8322 1,356,084 1,191,084 0.0881 $104,945 £ 9,287 $ 40,806 S (16.678) $ 138.360 $ (639,395) 8 9 163 8322 1,356,084 1,191,084 0.0881 S 104.945 $ 9.751 S 42,846 S (17,178) $ 140,364 $ (544,344) 9 10 163 8322 1,356,084 1.191,084 0.0881 $ 104,945 £ 10.239 £ 44,969 $ (17,694) $ 142,479 S (453,198) 10 11 163 8322 1,356,084 1,191,084 0.1435 $ 170.945 £ 10,751 $ 47,238 £ (18,225) $ 210,709 $ (323.359) 11 12 163 S322 1,356.084 1,191,084 0.1435 £170,945 $11,288 $ 49.600 £ (18,771) S 213.062 $ (197.724) 12 13 163 8322 1,356,084 1,191,084 0.1435 $170,945 £11,853 S 52,080 S (19,335) $ 215,543 $ (76,100) 13 14 163 8322 1,356,084 1,191,084 0.1435 $ 170.945 $ 12,445 $ 54,684 $ (19,915) £ 218,159 $ 41,700 14 15 163 8322 1,356,084 1.191,084 0.1435 $170,945 £ 13.068 £ 5741a £ (20,512) £ 220.918 S 155,853 15 16 163 8322 1,356,084 1.191,084 0.1435 $170,945 £ 13,721 $ 60,289 $ (21,127) $ 223,827 £ 266,529 16 17 163 8322 1,356.084 1,181,084 0.1435 $ 170,945 £ 14.407 S 63,303 S (21,761) £ 226,894 $ 373.690 17 18 163 8322 1.356,084 1.191,084 0,1435 $170,945 $ 15.127 S 66,469 S (22,414) £ 230,127 S 478.092 18 19 163 8322 1.356,084 1.191.084 0.1435 $170,945 $ 15,884 $ 69,792 £ (23,086) $ 233.534 $ 579,282 19 20 163 8322 1,356,084 1.191,084 0.1435 $ 170,945 $ 16,678 $ 73,282 £ (23,779) £ 237,125 £ 677,605 20 TOTAL 27,121,688 1084868 271217 $3,571,665 m tm Carollo Engineers 2/24/2010 Zeropex_NPV.xls ZeropexUnil^NPV Technical Memorandum APPENDIX G - FERC FILING INFORMATION April 2010 pw:/;C:arolk)/Documems/aient/CA/Ca!lsbad/8362A10/Deliverables/Carisbad_TM (RevisedFinal) c c o .9 (U u (0 ro per CL o c u 0 O u th >• 00 c ite C CU 00 "D m %— 01 a. X. a X re SOU n me ent UJ re SOU n o fit 'em x: > DO OI Q. JZ DO C •Q. o c _ E 2 iR o c CL) £ (U 3 cr i_ 00 c J3 a £^ E =5 O (U i_ a c ra 1^ C (U •a IO ra x: c o CL a • Q; -t-» a .E 8 < T3 4-* '•V QJ Q. X UJ JOJ, a. E R3 X 5 ^ in O "1 ^ S u - CL a ; < . c o >3» 00 42 C U ^ <^ o a P > cu '5 O o E O CL 2 TJ X Federal Energy Regulatory Commijsibn- 888 First St.. N.E. Washington, D.C. 20426 C (U 4-* c QJ C o S c to •o O 0) o Q. 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Summary of ihe Provisions in AB 2466 This bill, which was signed by the Governor on September 28, 2008, allows local governments to receive a credit for excess generation from a renewable energy generation system and to apply that credit against other accounts in the jurisdiction. The key provisions of this bill are described below. 1.1. Who is eUgible? Under AB 2466, local governmenis that are eligible to lake advantage of the crediting j procedure provided for in the law, include a city, county, whether general law or chartered, ^ city and county, special district, school district, political subdivision, or other local public ' agency. The state of California, any agency or deparunent of the state of Califomia, or joint ( powers authorities are not ehgible. ^ Further, to be eligible, a local government must satisfy all of the following criteria: ^ • The local govemment designates one or more benefiting accounts to receive a bill credit. t • A benefiting account receives service under a time~of-use rate schedule (such as AL-TOU). ^ • The benefiting account is the responsibility of, and serves property that is owned, operated, or on property controlled by the same local government that owns, operates, or i controls the eligible renewable generating facility. ^ • The electrical output ofthe eligible renewable generating facility is metered for time of use to allow calculation ofthe bill credit based upon when the electricity is exported to the ' grid. I • All costs associated with the metering requirements of the bill are the responsibility of the local government. ^ • All costs associated with interconnection are the responsibility ofthe local government. ^ • The local govemment does not sell electricity exported to the electrical grid to a third party. ( 1.1. What renewable energy generation technologies are eligible? ^ To be eligible under AB 2466, a renewable generation facility must meet the following criteria: ^ • Have a generation capacity of no more than one megawatt (MW). • Be owned, operated, or on property controlled by the local govemment entity. ^ • Be located within the boundaries of the govemmental entity or on land owned or controlled by govemmental entity, including leased land. *^ • Sized to offset all or a port of electrical load of the benefiting account. f Energy Policy Initiatives Center 1 www.sandiego.edu/epic • Be an eligible renewable energy resource pursuant to the California Renewables Portfolio Standard Program (Public Utilities Code Section 399.12).' 1.2. How would credits be calculated and distributed to other accounts? Local govemments with eligible renewable energy generation faciHties that generate more elecuicity than can be used by the associated (or generating) account would elect a "benefiting account" or multiple benefiting accounts to which excess electricity would be credited. To receive credit, an account must be located within the geographical boundaries of the local government and be mutually agreed upon by the local government and the electrical utility. i.2.1. Calculation of Credits A credit would be created when a renewable energy generation facility associated with an electrical account ("generating account") produced more electricity in a given bilhng cycle than was consumed by that account. The total amount consumed by the generating account would be handled by net energy metering. The credil under AB 2466 would be equal to the amount of excess electricity produced in a billing cycle multiplied by the commodity rate of the applicable time-of-use tariff for the benefiting account. The credit would not include the transmission, distribution, and ancillary charges components that together widi the generation components comprise full retail rates. For illustrative purposes, the current time-of-use commodity prices for the AL-TOU tariff, which is used by many commercial entities (including govemmenrs), are presented in die table below.^ Commodity Prices for AL-TOU Tariff ($/kWh) On-Peak Semi-Peak Off-Peak Summer 0.108 0.088 0.066 Winter 0.106 0.098 0.073 The figure below presents a simple diagram of how the crediting procedure would work under AB 2466. Renewable Energy Generation Facility (Renewable Energy Offsets Retail Rate Excess Energy Upto 100% of Building Load Credit =TOU Commodity Rate Benefiting Account 1 Generating Account Benefiting Account 2 ' For details on eligibility, see California Energy Commission, Renewabies Portfolio Standard EligibiHty, Third Edition (January 2008). Go to http://www.energy.ca.gov/2007pubIications/CEC-300- 2007-006/CEC-300-20D7-006-ED3-CMF.PDF. ^ SDG&E Schedule EECC, Electric Energy Commodity Cost, Effective May 1, 2008. Energy Policy Initiatives Center www.sandiego.edu/epic 1.2.2. Distribution of Credits The credits would be subtracted from the benefiting account's normal billing cycle commodity (or generation) costs. It is important to note that credits are calculated based on the commadify or generation portion of the applicable rate and applied to the commodity portion of the benefiting account. This is sometimes called "Gen to Gen," short for "generation to generation". If, during the billing cycle, the generation component of the electricity usage charges exceeds the bill credit, the benefiting account would be billed for the difference Qocal govemment pays). If, during the billing cycle, the bill credit applied exceeds the generation component of ttie electricity usage charges, the difference would be carried forward as a financial credit to the next billing cycle (local govemmen( receives credit}. Credit cannot be carried forward more than 12 months; that is, at the end of a 12-month period, any remaining credit would be reset to zero and the local govemment would not receive any compensation. 1.3. How would a local govemment initiate or terminate this arrangement? A local government must inform the electrical utility at least 60 days in advance that an eligible renewable generating facility will become operational. The electrical corporation must then file an advice letter with the CPUC not later than 30 days after receipt of the notice proposing a rate tariff for the benefiting account(s). The CPUC must approve or specify changes to the proposed tariff within 30 days of the date of filing. To terminate its participanon in this arrangement, a local government must inform the electrical utility a minimum of 60 days prior to the proposed termination date. 1.4. Who owns the renewable energy credits (REC) under AB 2466? Similar to the way Califomia handles renewable energy credits (REC) under net energy metering, the renewable energy generation system owner retains ownership of RECs under the crediting arrangement provided for in AB 2466. Further, electricity that is exported to the electric utihty does not count toward the local electric utility's renewable portfolio standard (RPS) requirements of providing 20% of retail sales by renewable sources by 2010. 1.5. What are the limitations on this crediting procedure? AB 2466 contains a total statewide limit (250 MW) to the amount of renewable energy generators that can participate in the crediting arrangement. Investor-owned electrical utiUlies are obligated to offer bill credit under AB 2466 until the rated capacity of eligible generators in their territory reaches its proportionate share of the 250 MW statewide limit based on the ratio of its peak demand to the total statewide peak demand. Using an estimate from a recent CPUC resolution, diis would put SDG&E's service territory limit at about 20 MW.^ 1.6. What are the pros and cons of AB 2466? The table below summarises the positive and negative attributes of AB 2466. ^ See CPUC Resolution E-4137. February 14, 2008. €1 r Energy Policy Initiatives Center 3 www.sandiego.edu/epic Pros and Cons of AB 2466 Pros Provides a mechanism to compensate local governments for excess renewable generation. Allows renewable generation owner to retain renewable energy credits (REC), Broadly defines renewable energy generation facilities. Allows renewable generation owner to participate in financial incentive programs. Allows renewable generation owner to participate in net energy metering. Cons Credit is calculated based on the commodity rate. Limited to tfme-of-use accounts. Limits renewable generation facility to 1 MW. Limit of 20 MW (total) in SDG&E service territory. 2. Suinmarv of AB 1969 "Feed-in'' Tariffs In 2006, Assembly Bill (AB) 1969 (Yee) added Pubhc Utihties Code (PU Code) Section 399.20, which authorizes tariffs and standard contracts for the purchase of eligible renewable generation from public water and wastewater facilities.^ To implement this law, the Califomia Public Utilities Commission (CPUC) has taken the following actions: • On July 26, 2007, the Commission adopted Decision (D.) 07-07-027 ordering each regulated electric utility to submit tariff proWsions implementing PU Section 399.20. • D.07-07-027 also authorized additional tariffs beyond those required for AB 1969 to facilities other than the public water and wastewater facilities in PG&E and SCE service territories. • Resolution E-4137 approved the final tariffs and standard contracts and set the effective date ofthe tariffs as Febmary 14, 2008. • Decision 08-09-033, adopted on September 18, 2008, directs SDG&E to expand its feed- in tariff to all customers.^ • On September 29''', SDG&E submitted for approval Advice Letter 2207-E, which provides details on the Customer Renewable Energy (CRE) tariff stmcture and eligibility.^ This advice letter has not been approved by the CPUC, but approval is expected. AB 1969 feed-in tariffs allow the owner of a renewable energy generation system either to sell all electricity from an eligible facility directly to the electrical utility or to sell only the excess electricity above the needs of a specific account (building). The figure below presents these two options graphically and illustrates the difference between AB 1969 feed-in tariffs and AB 2466 credits. ^ For more information on the AB 1969 feed-in tariffs, go to http://www.cpuc.ca.gov/PUC/energy/electric/RenewableEnergy/feedintariffssum.hlm. ^ Go to http://doc5.cpuc.ca.gov/word_pd^FINAL_DECIS10N/91159.pdf " Go to http://www.sdge.com/lm2/pdf/2027-E.pdf. Energy PoUcy Initiatives Center 4 vkrww.sandiego.edu/epic Excess Energy Option All Energy Option EXCESS Energy Purchased at MPR +TOD Factor Renewable Energy Generation Facility Up to 100% of Buildirtg Load OR ALL Energy Purchased at MPR +TOD Factor Renewfable Energy Generation Fadlity The following provides more details about the provisions of the current AB 1969 feed-in tariff offered by SDG&E. 2.1. Who is eligible? With adoption of Decision 08-09-033, all customers except a Public Water Agency and Wastewater Agency are eligible to enter into standard contracts under (he CRE rate schedule.^ Public Water and Wastewater Agencies are eligible customers under SDGScE's Schedule WATER. 2.2. What renewable energy generation technologies are eligible? A renewable energy generating facility is considered eligible if it meets the following criteria: • Is a generadng facihty that receives distribution service from SDG&E. • Has an effective capacity of not more than 1.5 MW. • Is interconnected and operates in parallel with the utility's electric transmission and distribution grid. • Is strategically located and interconnected to the utihty's electric transmission system in a manner dial optimizes the deliverabiUty of electricity generated at the facility to load centers. • Is an eligible renewable energy resource, as defined in Public Utilities Code Section 399.12. Cl 2.3. What is the rate at which SDG&E will purchase eligible renewable energy? The SDG&E CRE tariff allows eligible renewable energy generation owners to sell power directly to an investor-owned utility at a standard rate equal to die market price referent (MPR). This rate is administratively determined by die CPUC and is used, among odier ^ SB 380, enacted in 2008, codifies the expanded eligibility of AB 1969 tariffs. Energy Policy Initiatives Center vvTvw.sandiego.edu/epic diings, to determine when funding from die supplemental energy fund can be applied to renewable energy contracts between generators and investor-owned utilities.^ In this case, the MPR serves as the standard rate at which renewable energy generation owners would be compensated for their electricity. Time-of-dehvery (TOD) factors are used to determine rales for different times of the year and day. A contract under the CRE feed-in tariffs would purchase electricity at a differential rate depending on the time of day and time of year that the electricity is delivered to the electric utility. The table below provides an example of the 2008 MPR rates widi TOD factors applied for diree different contract lengths for summer and winter. 2008 Market Price Referents (MPR) with Time-of-Delivery Factor Adjustments ($/kWh)* 10 YEAR Baseload On Peak Semi Peak Off Peak Summer 0.093 0.152 0.096 0.082 Winter 0.093 O.no 0.100 0.074 15 YEAR Summer 0.094 0.154 0.098 0.083 Winter 0.094 0.112 0.101 0.074 20 YEAR Summer 0.096 0.157 0.100 0.085 Winter 0.096 0.114 0.103 0.076 "2008 MPR numbers from CPUC resolution RESOLUTION E - 4118, October 4,2007; Time of delivery factors from SDG&E 2008 Request for Offers for Eligible Renewable Resources. Revised April 3,2008. Under diis tariff a separate meter is required to determine the time of day and year that renewable energy was transferred to the electrical utility. 2.4. Who owns the renewable energy credits (REC) in AB 1969 feed-in tarifi^transactions? Unhke AB 2466 credits and net metering, under AB 1969 feed-in tariffs, ownership of all green attributes, including renewable energy credits, associated with the electricity purchased by the utihty would transfer to the utility. Further, this electricity could count toward the utility's RPS obligation. 2.5. What are the other limitations of AB 1969 Feed-in Tariffs? Feed-in tariffs provided for in AB 1969 are only available to customers until the total statewide capacity of participating facilities equals 500 MW, or 40 MW in SDG&E service territory.'^ Afler this limit is reached the electrical utility is not required to offer these feed-in tariffs. " For more details on the market price referent, go to http://www.cpuc. ca.gov/PUC/energy/eiectric/RenewabIeEiiergy/faqs/04MarketPriceReferent.htm SB 380, enacted in 2008, expands the total statewide capacity lo 500 MW. Energy Policy Initiatives Center www.sandiego.edu/epic Also, unlike AB 2466 credits, customers participating in AB 1969 feed-in tariffs are not eligible to participate in any other SDG&E interruptible, Self Generation Incentive Program (SGIP), California Solar Initiative, net energy metering program, or other similar programs. 2.6. What are the pros and cons ofthe 1969 Feed-in Tariffs? The table below summarizes the positive and negative attributes of the feed-in tariffs offered by SDG&E. Pros and Cons of AB 1969 Feed-in Tariffs Pros Provides a mechanism to compensate local governments for excess renewable generation. Provides a standard contract and price for selling renewable energy to the local utility. Broadly defines renewable energy generation facilities. Cons Limits renewable generation facility to 1.5 MW. Limits total installed capacity to 40 MW in SDG&E service territory. Renewable generation owner not eligible to participate in financial incentive programs. Renewable generation owner not eligible to participate in net energy metering. Utilty retains green attributes of all energy sold to them. 3. Summary Comparison of Options The table beiow compares the key aspects of each option presented above. Note that diis includes the current net energy metering option, which is not discussed in detail above. Comparison of Options for Renewable Energy Generation in San Diego County Net Energy Metring AB 2466 ABI 969 Feed-in Tariff Rate Offered Retail Rate TOU Commodity Rate MPR+TOD m System Limit 1 MW 1 MW 1.5 MW Overall Umit 2.5% of Peak Demand 116MW in 2007 20 MW 40 MW Cl REC Ownership System Owner System Owner Utility W ^' Eligible Customers All Customers Local Governments Alt Customers except Water/Wastewater Agencies e Eligible Technology Solar, Wind, Fuel Celts, Biogas All Renewables' All Renewables^ e Eligible for Rebates* Yes Yes No e Eligible for Net Metering n/a Yes No e '10 MW for up to 3 biogas digesters. ' Pursuant to Renewable Portfolio Standard. ^Self-Generation Inventive Program, Caiifomia Solar Initiative Energy Policy Initiatives Center wvvTv.sandiego.edu/epic Technical Memorandum APPENDIX I - CANYONHYDRO INSTALLATION LIST AND PHONE SURVEY April 2010 pw.//Carollo/Documents^Client/CA/Cart5ba(t'8362A10/t)eliverables/Carisbad_TM (RevisedFinal) TELEPHONE MEMORANDUM Date: January 26,2010 Time: 3:00 PM WO #: 8362A10 From: Christopher Crotwell Contact: Dick Margetts - Manager, Adam Turner-Assist. Manager Project Name: Project 7 Water Authority Plione No.: 970-250-4676 Subject: Hydroelectric Turbine Turbine Size: 60.8KW 91.3KW Unit Type: 6TR1-F16Unit 10TR1 Unit Address: 69128 E. Hwy. 50 PO Box 1185 Montrose, CO 81402 Email: project7@montrose.net Description of System? How elect connected? System consisted of two raw water lines to the WTP from nearby reservoir. Each 24 inch diameter. One is used for hydroelectric while the other is the standby and bypass. There are two hydroelectric turbines installed on the pipe, one small and one large unit. Currently they only operate the smaller unit. They operate the small unit in the winter when desired flows to the WTP are lower and the larger unit in the summer when desired flows are higher. They do not operate both turbines at the same time. Startup for the turbines was October 2009 and the units were bought in June 2009. FERC The turbine supplies power locally and then the extra power is delivered to the grid through a net-metering program. The excess power that is delivered to the grid is put in a credit bank. Project 7 Water Authority can then use this credit bank to pay for its electricity bills at the WTP and elsewhere. They have not had to pay for a electric bill since the turbines have been operating. e: Cl Any additional valving besides inlet shutoff valve? Has two pressure relief valves for surge. These valves discharge to atmosphere and open upon a high surge pressure situation. c:>pw_wort«rq\ptqeGWiseVamt«eWms98502\to 2010.doi:x operation - start/stop, controls, etc.? The control panel was created by Bat Electric, Inc. The grid controls the rpm of the generator. The turbine starts by first determining if adequate grid power is available. Then the inlet butterfly valve begins to open. The butterfly valve is set to open in 45 seconds. When the inlet BFV is 30 percent open, the turbine starts to rotate. At 1810 rpm, the generator is connected to the grid and electricity is produced. Maintenance Issues? Contract maintenance? Cost? Turbines have pretty smooth operation. Had one current deviation problem that had to be resolved during startup. The reactive 3 phase power had currents that were not within the expected range ofthe turbine controls. Therefore the controls would trip the turbine offline. They had to get the local electric utility to work on the issue and get each phase current even. Turbine and generator require greasing once per week. This is done while turbine is in operation. They have a maintenance contract with a local consultant who has done a lot of turbines. He helped Project 7 through the FERC process. However, this is for the first year. After that. Project 7 will do all the maintenance. How long out of service? Have not been out of service since installed in October 2009. Noise? Noise is less than that of pump. Sounds like a quiet hum. The turbines are also in a insulated metal building. Has unit shut down automatically? Why? How? See startup, phase current issue. Other comments: Works really well. Delivers set flow based on input turbine head. If the turbine head is constant, the flow will be constant. Have two pressure sustaining valves to control surges. Has an a- synchronous generator. The generator produces a good bit of heat. A good ventilation system is important. TELEPHONE MEMORANDUM Date: January 25, 2010 Time: 3:00 PM WO#: 8362A10 From: Christopher Crotwell Contact: Bob Burke and Wes Haskell Project Name: Bangor Maine Water District Project Phone No.: 207-947-4516 x386(Bob) Subject: Hydroelectric Turbine Hydroelectric Turbine Size: 75KW Unit Type: 8TR3-CC Unit Address: PO Box 1129 Bangor, Maine 04402- 1129 Fax No.: 603-629-5036 Email: Bob.burke@bango rwater.org Discussed Bangor's turbine with Bob and Wes. The majority of the information came from Wes. Description of System? How elect connected? They have the turbine installed but have not operated other than for an hour to test. Should be operational in a month. It has just been approved to startup. They are not using the power locally as the building has essentially no power demand. They are feeding into the grid. Had to battle with the power company about the interconnection and power purchasing agreement. The turbine would be installed at an existing PRV station. The existing PRV station has one duty/one standby cone valve. There is a fairly large elevation difference between the water treatment plant (5 mgd)/ finished water reservoir and the distribution system. Therefore they use the PRV's and will use the turbine to lower the pressure before it enters the distribution system. Initially they thought that they would not need FERC approval. Then after the turbine was purchased they realized they needed the conduit exemption. This set the project back some because the Maine Wildlife and Fisheries wanted to use the conduit exemption to determine how much water they could treat. They finally got a FERC conduit exemption. Any additional valving besides inlet shutoff valve? Yes, Wes decided that he was not completely comfortable with relying on the inlet valve to close and also worried about water hammer when the hydraulically actuated inlet valve closes suddenly. To resolve this, a pressure relief valve was installed to relieve any pressure surges to atmosphere. Operation - start/stop, controls, etc.? CanyonHydro supplied the whole package with switchgear, controls and MCC. BAT did the controls/switchgear system. c:\pw_workirig\projectwise\ccrolwell\dms96502\bburkejan 2010.docx Maintenance Issues? Contract maintenance? Cost? None as unit is not operating. How long out of service? Not in service yet; should be in a month. Noise? During the hour test, the noise was minimal; no more than a pump, possibly less. Has unit shut down automatically? Why? How? Not in service yet; should be in a month. TELEPHONE MEMORANDUM Date: January 26, 2010 Time: 2:00PM WO #: 8362A10 From: Christopher Crotwell Contact: Mike Chadebois Project Name: SRP-Bartlett Dam Project Phone No.: 602-236-5116 Subject: Hydroelectric Turbine Hydroelectric Turbine Size: 55KW. Installed 2006 Unit Type: 10TR1 Unit Address: PO Box 52025 Mail Station PAB358 Phoenix, AZ 85072-2025 Fax No.: 602-236- 6694 Email: MCharlebois@srpnet.com Description of System? How elect connected? The turbine is located at the Bartlett Dam in Arizona which is located on the Verde River. Was installed in 2006. Originally they had a diesel generator to supply power locally at the dam facility. They installed the turbine to replace the diesel generator. The turbine is fed from the dam penstock. The penstocks consist of (2) 70 inch diameter pipes. Each penstock does not have a turbine, only a pressure reducing valve. The fiows fluctuate too much for them to install a turbine on the penstock which would accept all of the dam flow. The max flow through the penstocks is 1200 cfs while the average is about 100 cfs. However, the 55kW turbine can always run. The facility typically does nol need all of the 55 kW power. The power that is not needed is dissipated through two electric resistance heaters. Any additional valving besides inlet shutoff valve? They use the inlet shutoff valve to throttle the flow so that the turbine head is reduced and the power is therefore reduced. Operation - start/stop, controls, etc.? Push first button which starts to open the inlet valve. When the turbine registers as being available, an additional button is pushed to connect the turbine to the grid and start feeding power. dm c:\pw_wixkirig\projechiwse\ccrotodl\drns98502\mdiartebois jan 2010.docx Maintenance Issues? Contract maintenance? Cost? The turbine has been operating very well. Since the turbine was installed in 2006, it has only been out of service for a few days when a voltage regulator had to be replaced. Other than that the turbine operates 24/7. The turbine is virtually maintenance free. Turbine and generator must be greased about once a week. This is done while the turbine is operating. Generator oil must also be replaced at regular intervals. No other maintenance has been required. They will need to check the bearings in a few years. Noise? Fairly quiet unit. Has unit shut down automatically? Why? How? A high voltage will shut the unit down.