The Economics of Grid-Connected Hybrid Distributed Generation

848 views
774 views

Published on

This is a case study on the economics of hybrid distributed generation embedded in the Orion Networks distribution system in New Zealand

Published in: Technology
0 Comments
0 Likes
Statistics
Notes
  • Be the first to comment

  • Be the first to like this

No Downloads
Views
Total views
848
On SlideShare
0
From Embeds
0
Number of Embeds
17
Actions
Shares
0
Downloads
27
Comments
0
Likes
0
Embeds 0
No embeds

No notes for slide

The Economics of Grid-Connected Hybrid Distributed Generation

  1. 7. SCENARIO PAYMENT OPTIONS                 Customer Status   Scenario   Payment Options (Typical)                       (GCLM) Load   Line Rental Fee         Management   Single / Multiple Energy Tariff(s) (may / may not be time-related)       General Customer (GC)                     Connection Fee         (IPP) Generation   Peak Period Demand Pricing             TOU Energy Pricing or             Net-metering                           Connection Fee         (MCLM) Load Management   Assessed Capacity (AC) Pricing             Control Period Demand (CPD) Pricing       Major Customer (MC)       TOU Energy Pricing                         (IPP)   Connection Fee         Generation   Peak Period Demand (PPD) Pricing             TOU Energy Pricing  
  2. 8. ENERGY PAYMENT OPTIONS
  3. 9. CAPACITY SAVING SCHEDULE MCLM: Chargeable Major Customer Winter Periods MCLM: Chargeable Major Customer Summer Periods Season Control Period Total Duration Summer 2000-01 1 Nov 00 – 28 Feb 01 81.1 Hours Summer 2001-02 1 Nov 01 – 28 Feb 02 1.6 Hours Summer 2002-03 1 Nov 02 – 28 Feb 03 31.4 Hours Season Control Period Total Duration Winter 1994 1 May 94 – 31 Aug 94 61.1 Hours Winter 1995 1 May 95 – 31 Aug 95 80.9 Hours Winter 1996 1 May 96 – 31 Aug 96 52.1 Hours Winter 1997 1 May 97 – 31 Aug 97 53.8 Hours Winter 1998 1 May 98 – 31 Aug 98 9.6 Hours Winter 1999 1 May 99 – 31 Aug 99 34.6 Hours Winter 2000 1 May 00 – 31 Aug 00 20.0 Hours Winter 2001 1 May 01 – 31 Aug 01 181.6 Hours Winter 2002 1 May 02 – 31 Aug 02 111 Hours
  4. 10. CAPACITY GENERATION SCHEDULE IPP: Summer Chargeable Peaks for Capacity Generation Season Peak Period Total Duration Summer 2000-01 1 Oct 00 – 31 Mar 01 307.5 Hours Summer 2001-02 1 Oct 01 – 31 Mar 02 53 Hours Summer 2002-03 1 Oct 02 – 31 Mar 03 108.5 Hours IPP: Winter Chargeable Peaks for Capacity Generation Season Peak Period Total Duration Winter 2001 1 Apr 01 – 30 Sep 01 318.5 Hours Winter 2002 1 Apr 02 – 30 Sep 02 233 Hours
  5. 11. CAPACITY PRICING SCHEDULE CAPACITY SAVING SCENARIO CAPACITY GENERATION SCENARIO Pricing Definition Line Transmission Delivery Fixed (Connection) - $500.05 ----- - $500.05/year Control Period Demand - $60.00 - $21.92 - $81.92/kVA/year Assessed Capacity - $24.40 - $22.00 - $46.40/kVA/year Pricing Definition Line Transmission Delivery Fixed (Connection): GC - $0.00 ----- - $0.00/year Fixed (Connection): MC - $500.05 ----- - $500.05/year Peak Period Demand $66.70 $33.30 $100.00/kVA/year
  6. 14. PROJECT FINANCIAL ANALYSIS
  7. 15. MCLM ENERGY & CAPACITY SAVINGS
  8. 16. IPP ENERGY & CAPACITY REVENUES
  9. 17. COMPARING MCLM & IPP SCENARIOS
  10. 18. WIND ENERGY CONTRIBUTIONS
  11. 19. WIND VS. WIND-DIESEL HYBRID
  12. 20. INFLUENCE OF GOVT. INCENTIVES
  13. 21. AVERAGE PPD WHOLESALE PRICES NOV 02 JAN 03 MAR 03 OCT 02 F E B 0 3 DEC 02

×