Lecture_15.ppt
- 1. EE 369 POWER SYSTEM ANALYSIS Lecture 15 Economic Dispatch Tom Overbye and Ross Baldick 1
- 2. Announcements Read Chapters 6 (section 6.12) and 7 (sections 7.1 to 7.3). Homework 12 is 6.62, 6.63, 6.67 (calculate economic dispatch for values of load from 55 MW to 350 MW); due Tuesday, 11/29. Class review and course evaluation on Tuesday, 11/29. Midterm III on Thursday, 12/1, including material through Homework 12. 2
- 3. Retail Electricity Prices • There are many fixed and variable costs associated with power systems, which ultimately contribute to determining retail electricity prices. • The major variable operating cost is associated with generation, primarily due to fuel costs: – Roughly 30% to 50% of retail costs. • Retail prices also reflect the capital costs of building the generation, transmission, and distribution system as well as other costs. 3
- 4. Power System Economic Operation • Different generation technologies vary in the: – capital costs necessary to build the generator – fuel costs to actually produce electric power • For example: – nuclear and hydro have high capital costs and low operating costs. – Natural gas generators have low capital costs, and (with gas available from fracking) moderate operating costs. 4
- 5. Power System Economic Operation • Fuel cost to generate a MWh can vary widely from technology to technology. • For some types of units, such as hydro, “fuel” costs are zero but the limit on total available water gives it an implicit value. • For thermal units it is much easier to characterize costs. • We will focus on minimizing the variable operating costs (primarily fuel costs) to meet demand. 5
- 6. Power System Economic Operation • Power system loads are cyclical. • Therefore the installed generation capacity is usually much greater than the current load. • This means that there are typically many ways we could meet the current load. • Since different states have different mixes of generation, we will consider how generally to minimize the variable operating costs given an arbitrary, specified portfolio of generators. 6
- 7. Thermal versus Other Generation The main types of generating units are thermal and hydro, with wind and solar rapidly growing. For hydro the fuel (water) is free but there may be many constraints on operation: – fixed amounts of water available, – reservoir levels must be managed and coordinated, – downstream flow rates for fish and navigation. Hydro optimization is typically longer term (many months or years). We will concentrate on dispatchable thermal units, looking at short-term optimization: Non-dispatchable wind and solar can be incorporated by subtracting from load. 7
- 8. Generator types Traditionally utilities have had three broad groups of generators: – “Baseload” units: large coal/nuclear; almost always on at max. – “Midload,” ‘intermediate,” or “cycling” units: smaller coal or gas that cycle on/off daily or weekly. – “Peaker” units: combustion turbines used only for several hours. during periods of high demand 8
- 9. Block Diagram of Thermal Unit •To optimize generation costs we need to develop cost relationships between net power out and operating costs. •Between 2-10% of power is used within the generating plant; this is known as the auxiliary power. 9
- 10. Thermal generator Cost Curves Thermal generator costs are typically represented by one or other of the following four curves – input/output (I/O) curve – fuel-cost curve – heat-rate curve – incremental cost curve For reference - 1 Btu (British thermal unit) = 1054 J - 1 MBtu = 1x106 Btu - 1 MBtu = 0.29 MWh 10
- 11. I/O Curve The IO curve plots fuel input (in MBtu/hr) versus net MW output. 11
- 12. Fuel-cost Curve The fuel-cost curve is the I/O curve multiplied by fuel cost. A typical cost for coal is $ 1.70/MBtu. 12
- 13. Heat-rate Curve • Plots the average number of MBtu/hr of fuel input needed per MW of output. • Heat-rate curve is the I/O curve divided by MW. Best heat-rate for most efficient coal units is around 9.0 13
- 14. Incremental (Marginal) cost Curve Plots the incremental $/MWh as a function of MW. Found by differentiating the cost curve. 14
- 15. Mathematical Formulation of Costs Generator cost curves are usually not smooth. However the curves can usually be adequately approximated using piece-wise smooth, functions. Two approximations predominate: – quadratic or cubic functions – piecewise linear functions We'll assume a quadratic approximation: 2 ( ) $/hr (fuel-cost) ( ) ( ) 2 $/MWh i Gi i i Gi i Gi i Gi i Gi i i Gi Gi C P P P dC P IC P P dP 15
- 16. Coal Usage Example •A 500 MW (net) generator is 35% efficient. It is being supplied with coal costing $1.70 per MBtu and with heat content 9000 Btu per pound. What is the coal usage in lbs/hr? What is the cost? At 35% efficiency required fuel input per hour is 500 MWh 1428 MWh 1 MBtu 4924 MBtu hr 0.35 hr 0.29 MWh hr 4924 MBtu 1 lb 547,111 lbs hr 0.009MBtu hr 4924 MBtu $1.70 Cost = 8370.8 $/hr or $16.74/MWh hr MBtu 16
- 17. Wasting Coal Example •Assume a 100W lamp is left on by mistake for 8 hours, and that the electricity is supplied by the previous coal plant and that transmission/distribution losses are 20%. How much coal has he/she wasted? With 20% losses, a 100W load on for 8 hrs requires 1 kWh of energy. With 35% gen. efficiency this requires 1 kWh 1 MWh 1 MBtu 1 lb 1.09 lb 0.35 1000 kWh 0.29 MWh 0.009MBtu 17
- 18. Incremental Cost Example 2 1 1 1 1 2 2 2 2 2 1 1 1 1 1 1 2 2 2 2 2 2 For a two generator system assume ( ) 1000 20 0.01 $/hr ( ) 400 15 0.03 $/hr Then ( ) ( ) 20 0.02 $/MWh ( ) ( ) 15 0.06 $/MWh G G G G G G G G G G G G G G C P P P C P P P dC P IC P P dP dC P IC P P dP 18
- 19. Incremental Cost Example, cont'd 1 2 2 1 2 2 1 2 If 250 MW and 150 MW Then (250) 1000 20 250 0.01 250 $ 6625/hr (150) 400 15 150 0.03 150 $6025/hr Then (250) 20 0.02 250 $ 25/MWh (150) 15 0.06 150 $ 24/MWh G G P P C C IC IC 19