Distributed Renewable Energy Operating Impacts and Valuation Study

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Reduction in 2007 Peak Load 2007 Peak kWh Business as Usual Greenfield Base Case 10,276 10,276 With PV 9,889 7,320 With Lighting 10,258 10,256 With SWH 10,230 9,820 © 2008 Electric Power Research Institute, Inc. All rights reserved. 24 24
Loss Analysis Conclusions • Business as Usual Case – Total energy offset of 4,936 MWh – Peak reduction in dem<strong>and</strong> of 441 kW – Reduction in losses of 93 MWh – 0.37% reduction in total losses • Greenfield Case – Total energy offset of 14,689 MWh – Peak reduction in dem<strong>and</strong> of 1,400 kW – Reduction in losses of 176 MWh – 0.7% reduction in total losses • Circuit load factor is low (~29%) • Slight increase in no-load losses due to higher voltages in circuit • High-efficiency transformers • PV peak does not coincide with load peak, therefore during light load customers are back-feeding into grid • Losses are considered regardless of current direction, if backfeeding were not allowed the loss reduction would be greater © 2008 Electric Power Research Institute, Inc. All rights reserved. 25 25
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PREPARED FOR: ARIZONA PUBLIC SERVIC
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CONTENTS List of Tables............
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Contents 5. Technical Value - Power
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Contents TABLES 1-1 RES Eligible Te
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Contents FIGURES 1-1 RES Compliance
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5-6 Typical Output, Single-Axis Tra
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EXECUTIVE SUMMARY Abundant sunshine
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Executive Summary many uncertaintie
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Executive Summary In contrast to al
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Executive Summary Capital Reduction
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Executive Summary Annual Energy and
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Executive Summary commercial custom
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Executive Summary Creation of a suc
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SECTION 1 — STUDY BACKGROUND AND
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Study Background and Description 1.
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Study Background and Description in
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Study Background and Description Fi
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Study Background and Description SH
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Study Background and Description Ta
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Study Background and Description 1.
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Study Background and Description AP
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Study Background and Description cu
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Study Background and Description to
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Study Background and Description in
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Section 2 and commercial customers.
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Section 2 Figure 2-2: Photovoltaic
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Section 2 When weighted by capacity
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Section 2 PV Model Inputs Two basel
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Section 2 Figure 2-5: Phoenix Area
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Section 2 Figure 2-7: Typical Sprin
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Section 2 account shading at the ho
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Section 2 • Residential: • A so
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Section 2 • Thermosyphon systems
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Section 2 existing systems installe
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Section 2 Figure 2-12: Hourly SHW S
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Section 2 Figure 2-14: Active Dayli
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Section 2 Daylighting Costs Capital
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Section 2 • An interior diffusion
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Section 2 Key Findings of Commercia
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Section 2 2.5 Deployment Analysis 2
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Section 2 Table 2-11 Residential PV
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Section 2 Commercial PV PV systems
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Section 2 was conceived by Frank Ba
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Section 2 Kastovich. 36 The formula
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Section 2 Figure 2-20: PV Payback -
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Section 2 Figure 2-22: PV Payback -
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Section 2 Figure 2-24: Daylighting
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Section 2 • The forecast of the a
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Section 2 Results of Market Simulat
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SECTION 3 — TECHNICAL VALUE - DIS
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Technical Value - Distribution Syst
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Section 4 Both of these benefits ar
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Section 4 decrease both real and re
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Section 4 • A simplifying assumpt
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Section 4 Results The effects of as
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Section 4 may have excess schedulin
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Section 4 4.3.2 Local Reliability/R
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Section 4 Figure 4-3: $110 Million
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Section 4 Figure 4-4: Historical PV
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Section 4 Figure 4-6: Historical PV
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SECTION 5 — TECHNICAL VALUE - POW
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Technical Value - Power Supply Capa
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Section 6 Value is also viewed and
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Section 6 6.2.2 Approach to Identif
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Section 6 Table 6-1 Levelized Carry
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Section 6 6.4.2 Summary of Quantita
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Section 6 Table 6-4 Capital Cost Re
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Section 6 Table 6-6 Total Solar DE
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Section 6 savings for the High Pene
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Section 6 6.4.7 Fixed and Variable
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Section 6 current demand, but assum
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Section 6 legislation and regulatio
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Section 6 The expansion of “green
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Section 6 solar DE development over
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Section 6 • Provide financing - M
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Section 6 6.8 Conclusions The winni
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Appendix A solar incidence: solar t
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APPENDIX B — CALIFORNIA PV PROGRA
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CALIFORNIA PV PROGRAM Figure B-2. C
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CALIFORNIA PV PROGRAM largest avera
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CALIFORNIA PV PROGRAM The data show
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CALIFORNIA PV PROGRAM The following
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CALIFORNIA PV PROGRAM Figure B-6. H
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Appendix C The price of an SREC is
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Appendix C Figure C-3. Average Cost
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Appendix C Figure C-6. Average Cost
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Appendix C C.2.5 Government Facilit
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Appendix C Figure C-14. Average Cap
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Appendix C Figure C-16. Total Numbe
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APPENDIX D — CUSTOMER USE CHARACT
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Customer Use Characteristics by Sel
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APPENDIX E — MONTHLY LOAD PROFILE
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Monthly Load Profiles by Selected A
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Page 285 and 286: Monthly Load Profiles by Selected A
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Page 289 and 290: APPENDIX F — PHOTOVOLTAIC SYSTEM
Page 291 and 292: Photovoltaic system modeling Figure
Page 293: Photovoltaic system modeling - One-
Page 296 and 297: Appendix G The SRCC provides estima
Page 298 and 299: Appendix H Equipment Qualifications
Page 300 and 301: Appendix I Table I-3 Residential Ch
Page 303: Appendix J APS Incentive Schedules
Page 306 and 307: DISTRIBUTED ENERGY ADMINISTRATION P
Page 308 and 309: DISTRIBUTED ENERGY ADMINISTRATION P
Page 311: Appendix K DSS Study - Distribution
Page 314 and 315: Overview • EPRI was contracted by
Page 316 and 317: Circuit Model © 2008 Electric Powe
Page 318 and 319: Modeling Assumptions • Distributi
Page 320 and 321: Procedures After Model Conversion
Page 322 and 323: Load Models • Individual customer
Page 324 and 325: Loss Impact Analysis © 2008 Electr
Page 326 and 327: Sample Residential Solar Curves 3.0
Page 328 and 329: Hourly Average Load and Solar Curve
Page 330 and 331: Base Case Results: No Solar 12000 T
Page 332 and 333: Case 1 Results: Business as Usual 1
Page 334 and 335: Loss Analysis Results Summary Base
Page 338 and 339: Voltage Regulation © 2008 Electric
Page 340 and 341: ADEQ: Fixed Horizontal commercial P
Page 342 and 343: SOL_Desert: Fixed Latitude (residen
Page 344 and 345: Voltage Regulation Model • Same b
Page 346 and 347: Total PV Power Input Total PV Power
Page 348 and 349: Effect of PV Power on Phase Current
Page 350 and 351: Deviation between Voltage Profile 0
Page 352 and 353: Greenfield Results with Manually Ed
Page 354 and 355: Effect of Edited PV Profile on Tota
Page 356 and 357: Effect of Edited PV Profile on Volt
Page 359 and 360: APPENDIX L — MODEL RESULTS Figure
Page 361 and 362: Model Results Figure L-5. Residenti
Page 363 and 364: Model Results Figure L-9. Residenti
Page 365 and 366: Model Results Figure L-13. Resident
Page 367 and 368: Model Results Figure L-17. Resident
Page 369 and 370: Model Results Figure L-21. Commerci
Page 371 and 372: Model Results Figure L-25. Commerci
Page 373 and 374: Model Results Figure L-29. Large Co
Page 375 and 376: Model Results Figure L-33. Solar Ho
Page 383 and 384: Model Results Figure L-49. Cactus A
Page 385 and 386: Model Results Figure L-53. East Val
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Model Results Figure L-57. East Val
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Model Results Figure L-61. Galvin P
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Model Results Figure L-65. Javalina
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Model Results Figure L-69. Pioneer
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Model Results Figure L-73. Thompson
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Model Results Figure L-77. DE Impac
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Appendix M Figure M-2. Power Factor
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Appendix M Table M-1 Data Points fo
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Appendix M Figure M-6. Zoomed Plot
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Appendix M Figure M-10. Plot of Tra
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Appendix M • I harmonic number: 3
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Appendix M • File ending: Bad •
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Appendix M Table M-7 Limit Setups V
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Appendix N Evaluation of Economic V
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Appendix N N.3 Economic Value of Ca
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Distributed Renewable Energy Operat
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Calculation of APS Carrying Charges
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Calculation of APS Carrying Charges
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Distributed Renewable Energy Operating Impacts and Valuation Study

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