Green Electric Energy Lecture 20

ECE 333

Green Electric Energy Lecture 20 Wind Energy

Professor Tom Overbye Department of Electrical and Computer Engineering

Announcements • Start reading Chapter 6. • Homework 8 is due now. • Homework 9 is 6.12, 6.14, 6.15. It doesn’t need to be turned in but should be completed •

before the test. Kate will post solutions by next Tuesday. Exam 2 is Thursday November 19 in class. You can bring in your old note sheet and one new notes sheet. Kate is posting exam 2 from last semester.

Ex. 6.11 – Annual Energy from a Wind Turbine • • • •

NEG Micon 750/48 (750 kW and 48 m rotor) Tower is 50 m In the same area, vavg is 5m/s at 10 m

•

Find the annual energy (kWh/yr) delivered

Assume standard air density, Rayleigh statistics, Class 1 surface, (total) efficiency is 30%

Ex. 6.11 Annual Energy from a Wind Turbine • We need to use (6.16) to find v at 50 m, where z for roughness Class 1 is 0.03 m (from Table 6.4) ln( H / z ) v = v0 (6.16) ln( H 0 / z ) ln(50 / 0.03) v = 5 m/s = 6.39 m/s ln(10 / 0.03)

• Then, the average power density in the wind at 50 m from (6.48) is 6 1 3 2 Pavg /m = ⋅ (1.225) ( 6.39 ) = 304.5 W/m 2 π 2

Ex. 6.11 Annual Energy from a Wind Turbine • The rotor diameter is 48 m and the total efficiency is 30%, so the average power from the wind turbine is

π 2 Pavgthe=energy 0.3 ⋅ (delivered 304.5 inW/m ) ⋅ 4 ⋅ ( 48) = 165303 W a year is • Then, 2

Energy = 165.303 kW ⋅ 8760 hrs/yr = 1.44 × 106 kWh/yr

Wind Farms • Normally, it makes sense to install a large number of •

wind turbines in a wind farm or a wind park Benefits – – – –

Able to get the most use out of a good wind site Reduced development costs Simplified connections to the transmission system Centralized access for operations and maintenance

• How many turbines should be installed at a site?

Wind Farms • We know that wind slows down as it passes through the blades. Recall the power extracted by the blades:

1 2 2 & P = m v − v (6.18) ) bthe blades( reducesdthe Extracting power with available power to • 2 •

downwind machines What is a sufficient distance between wind turbines so that windspeed has recovered enough before it reaches the next turbine?

Wind Farms

For closely spaced towers, efficiency of the entire array becomes worse as more wind turbines are added

Figure 6.28

Wind Farms • The study in Figure 6.28 considered square arrays, but • • • •

square arrays don’t make much sense Rectangular arrays with only a few long rows are better Recommended spacing is 3-5 rotor diameters between towers in a row and 5-9 diameters between rows Offsetting or staggering the rows is common Direction of prevailing wind is common

Wind Farms – Optimum Spacing Ballpark figure for GE 1.5 MW in Midwest is one per 80 acres Figure 6.29

Optimum spacing is estimated to be 3-5 rotor diameters between towers and 5-9 between rows

5 D to 9D

3 D to 5D

Ex. 6.12 – Energy Potential for a Wind Farm

4D

7D

Note that the 4D and the 7D are switched on the figure in the book.

Ex. 6.12 – Energy Potential for a Windfarm 4D

7D

a. Find annual energy production per unit of land area if the power density at hub height is 400-W/m2 (assume 50 m, Class 4 winds) b. What does the lease cost in $/kWh if the land is leased from a rancher at $100 per acre per year?

Ex. 6.12 – Energy Potential for a Windfarm a. For 1 wind turbine: Land Area Occupied = 4D ⋅ 7 D = 28D 2 1 Annual Energy Production = ρ Av 3 ⋅ ∆t ⋅η 2 1 3 π 2 2 where ρ v = 400 W/m and A = D 2 4 Annual Energy Production/Land Area 400 W π 1 kWh 2 8760hr = ⋅ ( D m) ⋅ ⋅ 0.3 ⋅ 0.8 ⋅ = 23.588 2 2 m 4 yr 28D (m2 ⋅ yr)

Ex. 6.12 – Energy Potential for a Windfarm b. 1 acre = 4047m

2

In part (a), we found

$100 Land Cost = acre ⋅ yr

Annual Energy kWh = 23.588 Land Area (m 2 ⋅ yr) or equivalently

kWh 4047 m 2 kWh 23.588 ⋅ = 95, 461 2 (m ⋅ yr) acre (acre ⋅ yr)

Then, the lease cost per kWh is

$100 / acre ⋅ yr lease cost = = $0.00105/kWh 95, 461 kWh / acre ⋅ yr

Time Variation of Wind • • •

We need to not just consider how often the wind blows but also when it blows with respect to the electric load. Wind patterns vary quite a bit with geography, with coastal and mountain regions having more steady winds. In the Midwest the wind tends to blow the strongest when the electric load is the lowest.

Upper Midwest Daily Wind Variation

August

April

Source: www.uwig.org/XcelMNDOCwindcharacterization.pdf

How Rotor Blades Extract Energy from the Wind Airfoil – could be the wing of an airplane or the blade of a wind turbine

Figure 6.30 (a)

How Rotor Blades Extract Energy from the Wind •

•

Air is moving towards the wind turbine blade from the wind but also from the relative blade motion The blade is much faster at the tip than at the hub, so the blade is twisted to keep the angles correct

Figure 6.30 (b)

Angle of Attack, Lift, and Drag •

Increasing angle of attack increases lift, but it also increases drag Figure 6.31 (a)

Figure 6.31 (b) - Stall

• If the angle of attack is too great, “stall” occurs where turbulence destroys the lift

Idealized Power Curve Cut –in windspeed, rated windspeed, cut-out windspeed

Figure 6.32

Idealized Power Curve • Before the cut-in windspeed, no net power is generated • Then, power rises like the cube of windspeed • After the rated windspeed is reached, the wind turbine operates at •

rated power (sheds excess wind) Three common approaches to shed excess wind – – –

Pitch control – physically adjust blade pitch to reduce angle of attack Stall control (passive) – blades are designed to automatically reduce efficiency in high winds Active stall control – physically adjust blade pitch to create stall

Idealized Power Curve • • • •

Above cut-out or furling windspeed, the wind is too strong to operate the turbine safely, machine is shut down, output power is zero “Furling” –refers to folding up the sails when winds are too strong in sailing Rotor can be stopped by rotating the blades to purposely create a stall Once the rotor is stopped, a mechanical brake locks the rotor shaft in place

Example: Small Wind Turbine • Consider a 0.9 kW wind turbine with a 2.13m blade installed at a hub height • • • • •

where the average wind speed is 6.7 m/s. Assume the turbine costs $1,600 and the installation/other capital costs add an additional $900 The $2,500 total capital is financed with a 15-year, 7% load. Annual O&M costs are $100 The capital recovery factor (i=0.07, n =15) is 0.1087 Total annual payments are thus $(2500*0.1087+100) = $374.49/yr

Example: Small Wind Turbine, cont. • To estimate the energy delivered by the turbine we’ll use the CF approach from (6.65)

PR 0.9 CF = 0.087V − 2 = (0.087)(6.7) − = 0.385 2 D 2.13

• Total energy supplied by turbine would be about • • •

(0.9)kW⋅ (8760)hr/yr ⋅ 0.385 = 3035 kWh/yr Average cost per kWh is then 374.5/3035 = 0.123 $/kWh This value is close to current rates, and also assumes the wind turbine only lasts for 15 years. Note, a 6.7 m/sec average wind is class 3 (much of Illinois at 50m)

Current Prices for Small Wind •

The Home Depot is selling a 900W wind turbine kit, which includes the turbine and a 1000W inverter, for $2497.97; tower and batteries are extra (65’ tower goes for about $1000 plus installation).

Most Illinois sites are < 12 mph at 65’ Source: www.homedepot.com; www.kansaswindpower.net

Government Credits • Federal government provides tax credits of 30% of cost for small • •

(household level) solar, wind, geothermal and fuel cells (starting in 2009 the total cap of $4000 was removed) I don’t think Illinois has a wind credit, but they do have a solar credit (30% of cost) For large systems the Federal Renewable Electricity Production Tax Credit pays 1.5¢/kWh (1993 dollars, inflation adjusted, currently 2.1¢) for the first ten years of production

Source for federal/state incentives: www.dsireusa.org

Economies of Scale • •

Presently large wind farms produce electricity more economically than small operations Factors that contribute to lower costs are –

– – –

Wind power is proportional to the area covered by the blade (square of diameter) while tower costs vary with a value less than the square of the diameter Larger blades are higher, permitting access to faster winds Fixed costs associated with construction (permitting, management) are spread over more MWs of capacity Efficiencies in managing larger wind farms typically result in lower O&M costs (on-site staff reduces travel costs)

Environmental Aspects of Wind Energy • • • •

US National Academies issued report on issue in 2007 Wind system emit no air pollution and no carbon dioxide; they also have essentially no water requirements Wind energy serves to displace the production of energy from other sources (usually fossil fuels) resulting in a net decrease in pollution Other impacts of wind energy are on animals, primarily birds and bats, and on humans

Environmental Aspects of Wind Energy, Birds and Bats •

Wind turbines certainly kill birds and bats, but so do lots of other things; windows kill between 100 and 900 million birds per year Estimated Causes of Bird Fatalities, per 10,000

Source: Erickson, et.al, 2002. Summary of Anthropogenic Causes of Bird Mortality

Environmental Aspects of Wind Energy, Birds and Bats •

Of course most people do not equate killing a little song bird, like a sparrow, the same as killing a bigger bird, like an eagle (less prone to hit the front window). –

•

Large bird (raptor) mortalities are about 0.04 bird/MW/year, but these values vary substantially by location with Altamont Pass (CA) killing about 1 raptor/MW/year.

Turbine design and location has a large impact on mortality

Environmental Aspects of Wind Energy, Human Aesthetics •

Aesthetics is often the primary human concern about wind energy projects (beauty is in the eye of the beholder); night lighting can also be an issue

Figure 4-1 of NAS Report, Mountaineer Project 0.5 miles

Environmental Aspects of Wind Energy, Human Aesthetics, Offshore • •

Offshore wind turbines currently need to be in relatively shallow water, so maximum distance from shore depends on the seabed Capacity factors tend to increase as turbines move further off-shore

Image Source: National Renewable Energy Laboratory

Cape Wind Simulated View, Nantucket Sound, 6.5 miles Distant

Source: www.capewind.org

Environmental Aspects of Wind Energy, Human Well-Being • Wind turbines often enhance the well-being of many people, but some living • •

nearby may be affected by noise and shadow flicker Noise comes from 1) the gearbox/generator and 2) the aerodynamic interaction of the blades with the wind Noise impact is usually moderate (50-60 dB) close (40m), and lower further away (35-45 dB) at 300m –

However wind turbine frequencies also need to be considered, with both a “hum” frequency above 100 Hz, and some inaudible or barely audible low frequencies (20 Hz or less)

• Shadow flicker is more of an issue in high latitude countries since a lower sun casts longer shadows

Questions Landowners Should Consider Before Signing Up •

How much do I get and how much land will be tied up and for how long (usually about $3000/yr per turbine) –

• • • • •

Is it fixed or based on revenue?

What land rights are given up; what can I still do? Who has what liability insurance? What rights is the developer able to transfer without my consent? What are my and the developer’s termination rights? If the agreement is terminated, what happens to the wind energy structures and related facilities (they take a lot of concrete!)

Wind Turbines and Property Taxes in Illinois • Illinois taxes property (land/buildings) at a rate equal to 1/3 its “fair cash value.” –

Personal property is not taxed (e.g., they tax your house but not what you have in your house).

• Beginning in 2008 Illinois assigns a fair cash value to wind •

turbines based at a rate of $360,000 per MW*an inflation value (set to 1.0 in 2008) – a depreciation value. Property tax rates in Champaign county are around $7 to $8 / $100. At 8% the owner of 1.5 MW wind turbine would need to pay $9600 per year, which is about $2.4 per MWh (assuming a 30% capacity factor)

Power Grid Integration of Wind Power • Currently wind power represents a minority of the generation in • •

power system interconnects, so its impact of grid operations is small But as wind power grows, in the not too distant future it will have a much larger, and perhaps dominant impact of grid operations Wind power has impacts on power system operations ranging from that of transient stability (seconds) out to steady-state (power flow) –

Voltage and frequency impacts are key concerns

Wind Power, Reserves and Regulation •

A key constraint associated with power system operations is pretty much instantaneously the total power system generation must match the total load plus losses –

•

Excessive generation increases the system frequency, while excessive load decreases the system frequency

Generation shortfalls can suddenly occur because of the loss of a generator; utilities plan for this occurrence by maintaining sufficient reserves (generation that is on-line but not fully used) to account for the loss of the largest single generator in a region (e.g., a state)

Wind Power, Reserves and Regulation, cont. Eastern Interconnect Frequency Response for Loss of 2600 MW;

Wind Power, Reserves and Regulation, cont. •

A fundamental issue associated with “free fuel” systems like wind is that operating with a reserve margin requires leaving free energy “on the table.” –

•

A similar issue has existed with nuclear energy, with the fossil fueled units usually providing the reserve margin

Because wind turbine output can vary with the cube of the wind speed, under certain conditions a modest drop in the wind speed over a region could result in a major loss of generation –

Lack of other fossil-fuel reserves could exacerbate the situation

Wind Power and the Power Flow • The most common power system analysis tool is the power flow (also known sometimes as the load flow) – – – – –

power flow determines how the power flows in a network also used to determine all bus voltages and all currents because of constant power models, power flow is a nonlinear analysis technique power flow is a steady-state analysis tool it can be used as a tool for planning the location of new generation, including wind

Five Bus Power Flow Example

1

T1

5

T2 800 MVA 4 345/15 kV

Line 3 345 50kV mi

345 kV 100 mi

Line 1

400 MVA 15/345 kV

Line 2

400 MVA 15 kV 345 kV 200 mi

2 280 Mvar

800 MW

Single-line diagram

3

520 MVA

800 MVA 15 kV 40 Mvar 80 MW

37 Bus Power Flow Example Metropolis Light and Power Electric Design Case 2 SLA CK345

A MVA A MVA

1.03 pu

1.02 pu

T I M3 45

A

A

MVA

MVA

A

SLA CK138

1.02 pu A

A

MVA

MVA

MVA

RA Y1 38 1.03 pu

A

T I M138

1.00 pu

33 MW 13 Mvar

A

A

23 MW 7 Mvar

MVA

MORO1 38

39 MW 13 Mvar HA NNA H69 60 MW 19 Mvar

12 MW 5 Mvar 1.00 pu

0.99 pu

A

1 .00 pu DEMA R69

KYLE69

A

20 MW 12 Mvar UI UC6 9 1.00 pu 12.8 Mvar

A

MVA

MVA

A MA NDA 69

0.99 pu

25 MW 10 Mvar

1.02 pu

20 MW 3 Mvar 1.00 pu

1.00 pu

A

A

MVA

MVA

MVA

5 5 MW 2 5 Mvar

A

7.3 Mvar

SHI MKO69 7.4 Mvar

MVA

A

1.01 pu

MVA

23 MW 6 Mvar

A MVA

MVA MVA

4 5 MW 0 Mvar

14 MW

1.02 pu BUCKY13 8

ROGER69

2 Mvar

14 MW 3 Mvar

A MVA

SA VOY69

1.02 pu

A

38 MW 3 Mvar

J O1 38

MVA

A

MVA

1.01 pu A

10 MW 5 Mvar

LA UF138 1 .01 pu

A

PA TT EN69

WEBER69

22 MW 15 Mvar

A

MVA

A

1.00 pu

LA UF69

1.02 pu

1 .02 pu

1 5 MW 5 Mvar

MVA

A

1.0 0 pu

A

MVA

A

1 .00 pu

0.0 Mvar

20 MW 28 Mvar

MVA

MVA

MVA

36 MW 10 Mvar

LYNN138 14 MW 4 Mvar

BLT 69

1.01 pu

HA LE69

MVA

60 MW 12 Mvar

MVA

BLT 13 8

MVA

A A

13 Mvar

16 MW -14 Mvar A

A A

BOB69 56 MW

A MVA

1.01 pu

A

MVA

MVA

12 4 MW 45 Mvar

A

MVA

2 5 MW 3 6 Mvar

MVA

MVA

MVA A

A

MVA

A

BOB138

A

MVA

A

MVA

A

1.01 pu

28.9 Mvar 1.00 pu

WOLEN69

4.9 Mvar

58 MW 40 Mvar

MVA

14.2 Mvar

H OMER69

1.01 pu

12 MW 3 Mvar

PET E69 A

MVA

1 3 Mvar

FERNA 69

MVA

HI SKY 69

A

MVA

A

A

A

3 7 MW

1 7 MW 3 Mvar

GROSS69

MVA

MVA

A

RA Y6 9

MVA

1 .01 pu

A

A

1.02 pu

PA I 69

1.01 pu

T I M69

MVA

1.03 pu

MVA

18 MW 5 Mvar A

MVA

MVA

1.02 pu

MVA

A

1 5.9 Mvar

22 0 MW 52 Mvar

RA Y3 45 slack

System Losses: 10.70 MW

1.0 1 pu

A

MVA

SA VOY13 8

J O345

A

150 MW 0 Mvar

MVA

A

MVA

150 MW 0 Mvar

A MVA

1.02 pu

A

MVA

1 .03 pu

Good Power System Operation •

Good power system operation requires that there be no reliability violations for either the current condition or in the event of statistically likely contingencies •

•

•

Reliability requires as a minimum that there be no transmission line/transformer limit violations and that bus voltages be within acceptable limits (perhaps 0.95 to 1.08) Example contingencies are the loss of any single device. This is known as n-1 reliability.

North American Electric Reliability Corporation now has legal authority to enforce reliability standards (and there are now lots of them). See http://www.nerc.com for details (click on Standards)

Looking at the Impact of Line Outages Metropolis Light and Power Electric Design Case 2 SLACK345

A

MVA A

MVA

1.03 pu

1.02 pu

A

A

MVA

T I M345

A

SLA CK138

MVA

1.02 pu A

A

MVA

MVA

MVA

RAY138 1.03 pu

A

TI M138

1.01 pu

33 MW 13 Mvar

A

A

23 MW 7 Mvar

12 MW 5 Mvar 1.00 pu

0.90 pu

A

MVA

1.01 pu

28.9 Mvar

DEMA R69

KYLE69

A

A

A

A

25 MW 36 Mvar

MVA

AMA NDA69

0.90 pu

124 MW 45 Mvar

A

56 MW

A

135%

A

MVA

55 MW 32 Mvar

MVA

60 MW 12 Mvar

MVA

MVA

1.00 pu

0.99 pu

MVA

23 MW 6 Mvar

A

80%

A

10 MW 5 Mvar

MVA

LA UF138 BUCKY138

ROGER69

2 Mvar A

MVA

SAVOY69

1.02 pu

A

38 MW 9 Mvar

J O138

MVA

A

MVA

MVA MVA

14 MW

14 MW 3 Mvar 1.01 pu

1.00 pu

1.01 pu

PA T TEN69 45 MW 0 Mvar

WEBER69

22 MW 15 Mvar

A

A

1.00 pu

LA UF69 A

A

MVA

MVA

A

1.01 pu

1.02 pu

15 MW 5 Mvar MVA

A

7.2 Mvar

1.00 pu

0.0 Mvar

20 MW 40 Mvar

SHI MKO69 7.3 Mvar

MVA

A

36 MW 10 Mvar

A A

A

BLT69

1.01 pu

MVA

HA LE69

LYNN138

14 MW 4 Mvar

MVA

MVA

MVA

A

MVA

BLT138

1.00 pu

A

20 MW 3 Mvar 0.94 pu

13 Mvar

16 MW -14 Mvar

A

MVA

1.01 pu

MVA

BOB69

MVA

A

25 MW 10 Mvar

MVA

MVA A

MVA

1.02 pu

A

MVA

MVA

A

BOB138

MVA

20 MW 12 Mvar UI UC69 1.00 pu 12.8 Mvar

MVA

MVA

A

1.00 pu

1.00 pu

WOLEN69

4.9 Mvar

58 MW 40 Mvar

11.6 Mvar

110%

1.01 pu

12 MW 3 Mvar

PET E69

A

HOMER69

13 Mvar

FERNA 69

A

A

39 MW 13 Mvar HA NNAH69 60 MW 19 Mvar

37 MW A

MVA

A

MVA

HI SKY69

MORO138

GROSS69

MVA

MVA

A

MVA

RA Y69 17 MW 3 Mvar

MVA

1.01 pu

A

A

1.02 pu

PA I 69

1.01 pu

TI M69

MVA

1.03 pu

MVA

18 MW 5 Mvar A

MVA

MVA

1.02 pu

MVA

A

16.0 Mvar

227 MW 43 Mvar

RA Y345 slack

System Losses: 17.61 MW

1.01 pu

A

MVA

SAVOY138

J O345

A

150 MW 4 Mvar

MVA

A

MVA

150 MW 4 Mvar

A

MVA

1.02 pu

A

1.03 pu

MVA

Opening one line (Tim69-Hannah69) causes an overload. This would not be allowed (i.e., we can’t operate this way when line is in.

Contingency Analysis Contingency analysis provides an automatic way of looking at all the statistically likely contingencies. In this example the contingency set Is all the single line/transformer outages

Generation Changes and The Slack Bus •

The power flow is a steady-state analysis tool, so the assumption is total load plus losses is always equal to total generation •

•

Generation mismatch is made up at the slack bus

When doing generation change power flow studies one always needs to be cognizant of where the generation is being made up •

Common options include system slack, distributed across multiple generators by participation factors or by economics

Generation Change Example 1 A

SLA CK34 5

MVA A

MVA

0 .00 pu

1 62 MW 3 5 Mvar

RA Y34 5 slack

0 .00 pu

TI M34 5

A

A

MVA

MVA

A

SLA CK138

-0.0 1 pu

A

MVA

RA Y13 8

A

0.0 0 pu

A MVA

MVA

TI M13 8

0.0 0 pu

A

A

A

0 MW 0 Mvar

MVA

0 MW 0 Mvar

MVA

MVA

MVA

0.0 0 pu -0 .1 Mvar

-0 .01 pu

RA Y69

TI M69

PA I 69

0 .00 pu

0 MW

0 MW 0 Mvar

A

0 .00 pu

MVA

A

0 Mvar MVA

A

A

0 MW 0 Mvar

0.0 0 pu

GROSS69

A

MVA

FERNA 6 9

MVA

A

MVA

MVA

HI SKY69

MVA

-0.1 Mvar A

MVA

0 MW 0 Mvar

-0.01 pu -0.03 pu

A

PETE6 9

DEMA R6 9

MVA

0.0 0 pu

WOLEN6 9 A

A

0 MW 0 Mvar

0.0 0 pu

0 MW 0 Mvar

A

MORO1 38

HA NNA H6 9 0 MW 0 Mvar -0.2 Mvar

MVA

MVA

0 MW 0 Mvar

UI UC69

A

0.0 0 pu

-157 MW -45 Mvar

A

-0 .1 Mvar A

0 MW

MVA A

-0.0 02 pu

0 MW 0 Mvar

0.00 pu

BLT1 38

-0.0 3 pu

MVA

0 MW 0 Mvar

MVA

A A

A

HOMER69

MVA

0.0 0 pu

A

A

HA LE6 9

0.0 0 pu A

BLT 69

-0.0 1 pu

A

0 MW 0 Mvar 0 .00 pu

SHI MKO69 0.0 Mvar

MVA

0 MW 0 Mvar

MVA

LYNN13 8

A

A

A MA NDA 69

0 Mvar

0 MW 0 Mvar

MVA

A MVA

BOB69

MVA

0.0 0 pu

0 .00 pu

MVA

A

A MVA

0 MW 0 Mvar

-0.1 Mvar

BOB1 38

A

MVA

MVA

MVA MVA

MVA

0 MW 51 Mvar

A

MVA

0 MW 0 Mvar A

MVA

0 MW 0 Mvar

A A

0 MW 0 Mvar

MVA

MVA

MVA

A

0 .0 Mvar

A A

0 .00 pu

0.0 Mvar

0.0 0 pu

MVA

0 .00 pu

PA TTEN69

MVA MVA

A

MVA

0.0 0 pu

LA UF69

0 .00 pu 0 MW 4 Mvar 0.0 0 pu

A

A

MVA

MVA

0 MW 0 Mvar

WEBER69

0 MW 0 Mvar

0 MW 0 Mvar

LA UF13 8 0 .00 pu

0 MW 0 Mvar

0.0 0 pu BUCKY13 8

ROGER69

0 Mvar

0 MW 0 Mvar

A

MVA

SA VOY69

0.0 0 pu

0 MW 3 Mvar

A

A

MVA

0 MW

J O13 8

MVA

0 .00 pu

A

MVA

SA VOY138

J O34 5

A

0 MW 2 Mvar

MVA

A

MVA

0 MW 2 Mvar

A

MVA

0 .00 pu

A

0.00 pu

MVA

Display shows “Difference Flows” between original 37 bus case, and case with a BLT138 generation outage; note all the power change is picked up at the slack

Generation Change Example 2 A

SLA CK34 5

MVA A

MVA

0 .00 pu

0 MW 3 7 Mvar

RA Y34 5 slack

0 .00 pu

TI M34 5

A

A

MVA

MVA

A

SLA CK138

-0.0 1 pu

A

MVA

RA Y13 8

A

0.0 0 pu

A MVA

MVA

TI M13 8

0.0 0 pu

A

A

A

0 MW 0 Mvar

MVA

0 MW 0 Mvar

MVA

MVA

MVA

0.0 0 pu -0 .1 Mvar

0.0 0 pu

RA Y69

TI M69

PA I 69

0 .00 pu

0 MW

0 MW 0 Mvar

A

0 .00 pu

MVA

A

0 Mvar MVA

A

A

0 MW 0 Mvar

0.0 0 pu

GROSS69

A

MVA

FERNA 6 9

MVA

A

MVA

MVA

HI SKY69

MVA

0 .0 Mvar A

MVA

0 MW 0 Mvar

0.00 pu -0.03 pu

A

PETE6 9

DEMA R6 9

MVA

0.0 0 pu

WOLEN6 9 A

A

0 MW 0 Mvar

0.0 0 pu

0 MW 0 Mvar

A

MORO1 38

HA NNA H6 9 0 MW 0 Mvar -0.2 Mvar

MVA

MVA

0 MW 0 Mvar

UI UC69

A

0.0 0 pu

-157 MW -45 Mvar

A

-0 .1 Mvar A

0 MW

MVA A

-0.0 03 pu

0 MW 0 Mvar

0.00 pu

BLT1 38

-0.0 3 pu

MVA

0 MW 0 Mvar

MVA

A A

A

HOMER69

MVA

-0 .01 pu

A

A

HA LE6 9

0.0 0 pu A

BLT 69

-0.0 1 pu

A

0 MW 0 Mvar 0 .00 pu

SHI MKO69 -0 .1 Mvar

MVA

0 MW 0 Mvar

MVA

LYNN13 8

A

A

A MA NDA 69

0 Mvar

0 MW 0 Mvar

MVA

A MVA

BOB69

MVA

0.0 0 pu

0 .00 pu

MVA

A

A MVA

0 MW 0 Mvar

-0.1 Mvar

BOB1 38

A

MVA

MVA

MVA MVA

MVA

19 MW 51 Mvar

A

MVA

0 MW 0 Mvar A

MVA

0 MW 0 Mvar

A A

0 MW 0 Mvar

MVA

MVA

MVA

A

0 .0 Mvar

A A

0 .00 pu

0.0 Mvar

0.0 0 pu

MVA

0 .00 pu

PA TTEN69

MVA MVA

A

MVA

0.0 0 pu

LA UF69

0 .00 pu 99 MW -20 Mvar 0.0 0 pu

A

A

MVA

MVA

0 MW 0 Mvar

WEBER69

0 MW 0 Mvar

0 MW 0 Mvar

LA UF13 8 0 .00 pu

0 MW 0 Mvar

0.0 0 pu BUCKY13 8

ROGER69

0 Mvar

0 MW 0 Mvar

A

MVA

SA VOY69

0.0 0 pu

A

A

MVA

0 MW

42 MW -14 Mvar

J O13 8

MVA

0 .00 pu

A

MVA

SA VOY138

J O34 5

A

0 MW 0 Mvar

MVA

A

MVA

0 MW 0 Mvar

A

MVA

0 .00 pu

A

0.00 pu

MVA

Display repeats previous case except now the change in generation is picked up by other generators using a participation factor approach

Siting New Wind Generation Example A MVA

1.02 pu

System Losses:

1.02 pu

RAY345 slack

8.73 MW

TIM345

A

A

MVA

MVA

A

SLACK138

1.01 pu

A

A

MVA

MVA

MVA

RAY138 1.03 pu

A

TIM138

1.00 pu

MVA

A

1.02 pu

MVA

1.02 pu

A

A

1.02 pu

RAY69

A

MVA

MVA

PAI69

1.01 pu

TIM69

A

MVA

1.01 pu

A

MVA

GROSS69

A

MVA

FERNA69

MVA A

A

A MVA

A

MORO138

PETE69

MVA A

MVA

1.01 pu

MVA

12 MW 5 Mvar 1.00 pu

HISKY69

1.00 pu

12 MW 3 Mvar

MVA

HANNAH69

DEMAR69

Wind69

1.00 pu

1.00 pu

UIUC69

50 MW

0.99 pu

BOB138

A

A

MVA

MVA

20 MW 12 Mvar

1.01 pu

A

BOB69

MVA

1.00 pu

A

A

MVA

MVA

0 MW 0 Mvar

56 MW 13 Mvar

A A

A

MVA

A

0.99 pu

MVA

-2 Mvar AMAN DA69

1.00 pu

MVA

HOMER69

1.00 pu

MVA

SHIMKO69

MVA

MVA

A

1.01 pu

A A

BLT138 A

A

BLT69

MVA

MVA

HALE69

MVA

A A

1.01 pu

MVA A

A

MVA

MVA

MVA

1.01 pu

A MVA

1.00 pu

A

1.00 pu

A MVA

LAUF69

1.02 pu

1.01 pu

WEBER69

PATTEN69

MVA

14 MW 2 Mvar

A

A

A

MVA

MVA

MVA

A MVA

ROGER69