Deployment and Initial Experience with Oscillation Detection Application at

Bonneville Power Administration

Dmitry Kosterev, Ashley Donahoo, Nick Leitschuh – BPA

Jeff Dagle, Frank Tuffner – PNNL

Dan Trudnowski – Montana Tech

2016 IEEE Meeting

BPA Overview• Bonneville Power

Administration (BPA) is a federal Power Marketing Agency in Pacific Northwest

• BPA markets power from 31 Federal dams and the Columbia Generating Station Nuclear Plant

• BPA operates more than 15,000 miles of transmission, including 4,735 miles of 500-kV lines

BPA operates several large paths in the Western Interconnection – California Oregon AC Intertie (4,800 MW), Pacific HVDC Intertie (3,100 MW), Northern Intertie (3,100 MW), and Montana Intertie (2,200 MW)

2

History of Syncrophasors at BPA

• BPA has been one of the earliest adopters of synchrophasortechnology since early 1990s

0 10 20 30 40 50 60 70 80 90 1003600

3800

4000

4200

4400

4600

4800

5000

Time (sec) from 15:47:30

Pow

er

(MW

)

COI Power, August 10 1996

BPA has greatly expanded PMU coverage and networking following 1996 outages

BPA researched, prototyped and deployed several PMU applications for engineering analysis

However, that PMU network was research-grade and was not reliable or secure for real-time control room applications

3

2010 Synchrophasor Investment Project

BPA initiated a capital investment project in 2010 to build a secure, reliable, control-grade synchrophasornetwork:• 5-year, $35M project • Part of DOE Smart Grid Program

• “Control” PMUs• Fully redundant architecture• 32 substations• 110 PMUs (55 redundant pairs)

• “Data” PMUs• 15 wind sites

• Total of 3,322 signals

4

Platt’s Global Energy Award

BPA synchrophasor investment project received 2013 Platt’s Global Energy Award for Industry Leadership in Grid Optimization

5

BPA Oscillation Detection Application

6

Control Room: Oscillation Detection

BPA deployed Oscillation Detection in its control room in October 2013

Scans 100+ signals for signs of growing or sustained power oscillations

Alarms dispatchers when an oscillation is detected

Dispatcher training sessions are performed

7

Operating procedures are developed in 2016

How are Oscillations detected?The magnitude of the oscillation is calculated in 4 frequency bands

8

100+

signals

scanned

Band 4 Energy

Band 3 Energy

Band 2 Energy

Band 1 Energy

How alarm is generated

9

If the oscillation is strong enough, and lasts long enough then an alarm is issued

Band 1 – (0.01- 0.15 Hz) >> 400 seconds

Band 2 – (0.15 - 1.0 Hz) >> 120 seconds

Band 3 – (1.0 - 5.0 Hz) >> 120 seconds

Band 4 – (5.0 - 14.0 Hz) >> 120 seconds

Must persist for this long:

120 sec

Oscillation Detection Events

• Multiple events of oscillation are detected monthly

• Examples:

– Generator control interactions

– Wind generation oscillations

– Bad operating point on a power plant

– Pacific HVDC Intertie controls

– Generator rotor angle oscillations

– Etc

10

(a) Central Oregon Oscillation on February 20, 2014 Overview display

Detailed display

(a) Central Oregon Oscillation on February 20, 2014

0 60 120 180 240 300 360 420-200

-150

-100

-50

0Active Power

Pow

er

(MW

)

0 60 120 180 240 300 360 42080

100

120

140

160

180Reactive Power

Time (sec)

Rea

ctive

(M

VA

R)

40 45 50 55 60 65 70-150

-100

-50

0Active Power

Pow

er

(MW

)

40 45 50 55 60 65 70100

110

120

130

140Reactive Power

Time (sec)

Rea

ctive

(M

VA

R)

CT failure resulted in

plant developing a large

power oscillations at 1.2

Hz frequency

7 minute plot

30-second plot

(b) Hydro Power Plant Oscillation

SYNCHROPHASOR: 10/30/2014 8:15:00 AMOSCILLATION DETECTION SUMMARY CLOSE

CUSTER

MONROE

CAPT JACK

ECHO LAKE

SUMMER LAKE

SCHULTZ

GRIZZLY

PAUL

MARION

ALVEY

NORTH

KEELER

BONNEVILLE

GARRISON

COULEE

GRAND

BELL

JOSEPH

CHIEF

ENERGY BAND KEY

.01 - .15 Hz

5.0 - 14 Hz

1.0 - 5.0 Hz

.15 - 1.0 Hz

CLICK ON A PMU

TO VIEW DETAILS

Generator, HVDC or SVC

Local Plant Controls

Inter-Area Oscil lations

Local Plant Controls or AGC

MALIN

EDDY

BIG

ROCK CREEK

SLATT

MCNARY

DAY

JOHN

SUMMARY TRENDS

500KV

500KV

230KV

500KV

500KV

230KV

500KV

230KV230KV

500KV

500KV

230KV

500KV

230KV

500KV500KV

500KV

500KV

500KV

500KV

230KV

500KV

230KV

230KV

500KV

500KV

500KV

500KV

CENTRAL

FERRY

500KV

ASHE

500KV

LOWER

MONUMENTAL

500KV

10/30/2014 8:15:00 AM10/30/2014 7:15:00 AM 60.00 minutes

ENERGY BAND 2

0.00

3.50

10/30/2014 8:15:00 AM10/30/2014 7:15:00 AM 60.00 minutes

ENERGY BAND 1

0.00

6.00

OSCILLATION ENERGY DETAILS:

JOHN DAY:POWERHOUSE #2 500KV LINE POWER10/30/2014 8:15:00 AM

10/30/2014 8:15:00 AM10/30/2014 7:15:00 AM 60.00 minutes

ENERGY BAND 3

0.00

3.00

10/30/2014 8:15:00 AM10/30/2014 7:15:00 AM 60.00 minutes

ENERGY BAND 4

0.00

0.70

JOHN DAY: POWERHOUSE #2 500KV MW-1 SEC

10/30/2014 8:15:00 AM10/30/2014 7:15:00 AM 60.00 minutes

MW

410.00

440.00

10/30/2014 8:15:00 AM10/30/2014 7:15:00 AM 60.00 minutes

-7

-2

3

-5

5

-3

7

-1

9BAND1 (.01-.15 Hz)

BAND2 (.15-1.0 Hz)

BAND3 (1.0-5.0 Hz)

BAND4 ( 5 -14 Hz)

MW

433.88

CLOSE

BAND1 ENERGY

0.7 MW

HI LIMIT

5.4 MW

BAND2 ENERGY

2.7 MW

HI LIMIT

1.6 MW

BAND4 ENERGY

0.1 MW

HI LIMIT

0.7 MW

BAND3 ENERGY

0.3 MW

HI LIMIT

2.8 MW

Oscillation Details

Overview Display

410

412

414

416

418

420

422

424

0 6 12 18 24 30 36 42 48 54 60

Po

we

r (M

W)

Time (sec)

Power

-255

-250

-245

-240

-235

-230

0 6 12 18 24 30 36 42 48 54 60

Re

acti

ve P

ow

er

(MV

AR

)

Time (sec)

Reactive Power

Period of oscillation is

3 seconds, oscillation

frequency is 0.33 Hz,

seen in both active

and reactive power

The oscillation is

caused by a surging

water vortex in one of

the turbines operating

at a partial load

Plant was re-

dispatched to a stable

operating point

(b) Hydro Power Plant Oscillation

(c) Wind Power Oscillation

(c) Wind Power Oscillations

9:00 8:30 8:00 6:30 6:00 5:30

1/30/2014 9:21:56 AMJOHN DAY - BIGLOW MVAR

10

20

30

40

50

60

70

80

9:00 8:30 8:00 6:30 6:00 5:30

1/30/2014 9:21:56 AMJOHN DAY - BIGLOW MW

-400

-360

-340

-320

-300

-280

-240

9:00 8:30 8:00 6:30 6:00 5:30

1/30/2014 9:21:56 AMJOHN DAY VOLTAGE

237,000

237,500

238,000

238,500

239,000

239,500

9:00 8:30 8:00 6:30 6:00 5:30

1/30/2014 9:21:56 AMFREQUENCY

59.95

59.97

59.98

59.99

60

60.01

60.02

60.03

60.05FREQUENCY VOLTAGE

ACTIVE POWER REACTIVE POWER

FREQUENCY VOLTAGE

ACTIVE POWER REACTIVE POWER

Oscillation is at 14

Hz, most visible in

reactive power,

indication of

voltage control

issues

Oscillations

reached 80 MVAR

peak to peak

(c) Wind Power Oscillations

Manufacturer upgraded the controls in April 2014 to fix

the oscillation problem

16:00 17:00

4/15/2014 4:14:59 PMJOHN DAY - BIGLOW MVAR

-20

0

10

20

30

40

60

16:00 17:00

4/15/2014 4:14:59 PMJOHN DAY - BIGLOW MW

-450

-350

-300

-250

-200

-150

-50

16:00 17:00

4/15/2014 4:14:59 PMJOHN DAY VOLTAGE

236,000

237,000

238,000

239,000

240,000

241,000

242,000

16:00 17:00

4/15/2014 4:14:59 PMFREQUENCY

59.95

59.97

59.98

59.99

60

60.01

60.02

60.03

60.05FREQUENCY VOLTAGE

ACTIVE POWER REACTIVE POWER

(d) Hydro Plant Control Interaction

Oscillation Details

Overview Display

Oscillation is caused by interactions between generator UEL and PSS

UEL was retuned in January 2016

-69.050

MW

10/21/2015 3:30:10 AM10/21/2015 3:30:00 AM 10.00 seconds

THE DALLES PH4 ACTIVE POWER

-90

-80

-70

-55

52.724

MV

10/21/2015 3:30:10 AM10/21/2015 3:30:00 AM 10.00 seconds

The DALLES PH4 REACTIVE POWER

35

45

50

55

65

(d) Hydro Plant Control Interaction

Success Story• BPA successfully deployed Oscillation Detection Module (ODM) in its control

room

• ODM is developed by Dan Trudnowski at MTU

• ODM scans for 100+ signals for sustained high energy oscillations

• ODM was implemented in 2013, and displays have been in the control rooms since October 2013 – log alarm only

• Several dispatcher training sessions have been performed

• Dispatchers took actions based on ODM results

• Operating procedures are developed, in effect June 1, 2016

• Several control improvements are implemented, including UEL tuning at a hydro-power plant and control firmware upgrades at a wind power plant

20