Transmission Planning for Wind Energy Resources in the Eastern United States Dale Osborn
Layered Design Typical utility planning Distribution delivery to loads Lower voltage transmission delivery from transmission and local Higher voltage transmission bulk energy delivery from base load generation and some interconnections. Regional transmission ( RTO) market delivery How does an energy market work What is an RTO Interconnection transmission market to market delivery
Possible layers to consider Individual utility Standard power flow and stability studies for planning More off peak studies Regional northern Africa collector system Economic studies to determine transmission Need databases to model Interconnection European market access Economic studies to determine transmission Capacity delivery Energy delivery Need databases to model
Rule of three for a new high voltage overlay One higher voltage line will not be economical generally due to the ability due to low levels of precontingent loadings due to the ability of the underlying system to withstand the outage of the line. Two higher voltage lines that can back up the contingent loss of the other generally break even with lower voltage alternatives. Three higher voltage lines that can back up the contingent loss of one other are generally economically superior to lower voltage alternatives. Economical loading levels must be possible on the higher voltage expansion
UMTDI Scenario B Plus Illinois Zones UMTDI Upper Midwest Transmission Development Initiative 6
Long Range Coordination with Other RTO s And Utilities Joint Coordinated System Planning Study www.jcspstudy.org Operations conditions for generation mix and characteristics
Eastern Wind Integration Transmission Study Overlays Scenario 1 1.22:11 Scenario 2 2 1.09:1 Scenario 3 0.75:1 Scenario 4 0.79:1 EIWTS Technical Review Committee Webinar October 2, 2009
Potential Benefits Adjusted Production Costs $35B/Yr E_CAN 12% IMO 3% PJM 14% NYISO 13% ISO-NE 10% SERCNI 25% MISO 10% MHEB 3% TVASUB 6% SPP 4% MAPP 0% 10
Loop Flow Patterns Interface AC Flows without an Overlay Interface Flows with an Overlay including HVDC
Price and Quantity of Sources and Sinks Determine Transmission Requirements
West to East Interface Flows OH-PA 25000 20000 15000 MW 10000 5000 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec 0 0 720 1440 2160 2880 3600 4320 5040 5760 6480 7200 7920 8640 Hour of the Year
3500 3000 2500 2000 1500 1000 500 0-500 -1000-1500 -2000 Transmission Overlay Design Workshop Example Interface Flow Duration Curve 1 245 489 733 977 1221 1465 1709 1953 2197 2441 2685 2929 3173 3417 3661 3905 4149 4393 4637 4881 5125 5369 5613 5857 6101 6345 6589 6833 7077 7321 7565 7809 8053 8297 8541 Transmission Capacity designed to deliver 80% of desired energy flow Hours WAPA-MINN MW Flow
$/Mw-Mile 4,000 3,600 3,200 2,800 2,400 2,000 1,600 1,200 800 400 0 Transmission and Substation Costs per Mw-mile by Transmission Voltage And Type of Construction 345 kv Steel Wooded Areas 2-345kkV on Steel Lowest cost options 500 kv 765 kv 765 HSIL 800 kv GIL 1200 mile- 800kV HVDC 600 1200 1300 2600 5400 5300 6400 Target typical planned loading Mw, use economics to choose voltage
$/Mw Delivery Capacity $/MW $5,000,000 $4,500,000 $4,000,000 $3,500,000 $3,000,000 $2,500,000 $2,000,000 $1,500,000 $1,000,000 $500,000 $0 200 400 600 800 1000 1200 1400 1600 Miles 345 kv AC 765 kv AC 800 kv HVDC 17
Power Transfer Breakover by Voltage Cost/Mile $16,000,000 $14,000,000 $12,000,000 $10,000,000 $8,000,000 $6,000,000 $4,000,000 $2,000,000 $0 345 kv AC+600 Mw 1-765kV AC 1-800 kv HVDC 345 kv AC+1000 Mw 200 1,200 2,200 3,200 4,200 5,200 6,200 7,200 8,200 9,200 10,200 11,200 12,200 13,200 Power Transfer MW 18
765 kv AC 345 kv +800 kv 400 kv 1200/1600 MVA 1200/1600 MVA +800 kv Bi Polar Transmission line 400 kv 1200/1600 MVA 1200/1600 MVA 800 kv 800 kv 3 HVDC Lines could have 12 terminals at the source and 12 terminals at the sinks 14,400 MW self contingent
EWITS Total Future Cost 15%
Maximum and Minimum Wind http://www.jcspstudy.org/ Data provided though the DOE Eastern Wind Integration and Transmission Study Simulated Maximum Power Output on April 29, 0600 GMT for calendar year 2004 Simulated Minimum Power Output on August 13, 1500 GMT for calendar year 2004 2005 2006 2007 2008 MW % of NP MW % of NP MW % of NP MW % of NP Nameplate Capacity (NP) 871 1,032 1,462 3,008 Actual Metered at Peak 103 1 11.8% 1 686 2 66.5% 2 24 3 1.6% 3 351 4 11.7% 4 1 Midwest ISO Peak Hour - August 3, 2005 16:00 2 Midwest ISO Peak Hour - July 31, 2006 16:00 3 Midwest ISO Peak Hour - August 8, 2007 16:00 4 Midwest ISO Peak Hour - July 29, 2008 16:00 21
Conclusions Transmission design methods depend on the planning area and ownerships markets Renewable Energy Zones are a practical method of managing the transmission planning problem Large amounts of renewable energy can be accommodated in large diverse areas using the rule of three Benefits can pay for transmission under certain conditions Geographical diversity linked by transmission produces a better wind product for the markets
Wind Diversity
Year to Year ELCC Variability Year to Year variation in the ELCC results is due to The different Hourly Load & Wind Profiles (2004, 2005 & 2006) And where the wind is located in each of the different Scenarios Study System ELCC Scenarios (1-4) Existing & Overlay Transmission Tie Limits - ELCC (%) {Shaded Area shows Increased ELCC of Overlay} 40% 35% 32.8% 30% 25% 20% 27.7% 28.0% 28.3% 28.1% 30.5% 27.3% 27.0% 25.4% 24.1% 26.4% 24.2% 23.8% 22.7% 20.2% 19.9% 18.8% 29.8% 26.6% 24.8% 24.6% 20.4% 20.6% Overlay Existing 15% 16.0% 10% 5% 0% As can be seen in the results a shift As more wind was located in the East (Scenario 3 & 4) The 2006 profile contained the higher ELCC As more wind was located in the West (Scenario 1) The 2004 profile contained the higher ELCC Scenario-1 System Scenario-2 System Scenario-3 System Scenario-4 System 2004 Profile 2005 Profile 2006 Profile