adine anm sweden

8/3/2019 Adine ANM Sweden

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ADINE is a project co-funded by the European Commission

ADINE

Active Network Management (ANM)

demonstration project

Sami Repo

Tampere University of Technology

Finland




Contents

1. Active distribution network

Drivers Description

A ctive network management

2. ADINE concept

Overview

Hierarchy of control system Automation and ICT

3. Real time laboratory simulations

Simulation environment

Examples of simulation results




Active distribution network




Drivers of active network

1. Penetration of distributed generation (DG)

Renewable energy sources

Controllable resource for distribution network management

Other existing resources are: direct load control

reactive power compensation

demand side management

2. Additional drivers Regulation of network monopolies

Profit regulation

Power quality regulation (interruptions)

Customers expectations for extreme reliability and quality

A ging network infrastruct ure




Distributed Generation

Increased DG penetration is expected

New products New connection standards

A dvantages

Many use renewable energy sources

May relieve network

Island operation may reduce interruption time Challenges

Network operation and DG interact

Exploit communication for control

New view on DG needed DG offers new possibilities




Impacts of DG on distribution network

1. Transfer of electricity

Direction and amount of power flow may change Losses will be affected

2. Distribution network rating

Voltage rise effect

Increment of fault current level

3. Protection Protection schemes designed for unidirectional power flow may

become ineffective

4. System impacts

Consequences of immediate tripping of DG units may becomeadverse when short-circuit in transmission grid is seen by severalDG units




Active network as a solution

Passive network until now

Network is dimensioned to handle the worst loading conditions Investments are in lines, cables, transformers and switchgear

Active network

Flexibility to network comes from the use of controllable

resources Investments are in controllability and information and

telecommunication technologies

Requires integration of DG units instead of "fit & forget

Synergy effects from co-operation of individual controllable

resources




Active network

Active network

Active Network Management

Active resources

Future infrastructure of

power distribution A c t i v e n e t w o r k a r c h

i t e c t u r e s

E n e r g y m a r k e t

CablingDC in distributionNew materialsEtc.

Why new architecture: Climate change Quality of network service Regulation

Asset management

Protection and control AutomationICT

DGSTATCOMDemand response Aggregator




Aggregation and utilization of active resources

Demand response

Balance management

Reserve market Price elasticity

Ancillary services Power flow management Voltage control Power quality control Frequency control Spinning reserve Damping of oscillations Back-up power




Ancillary services in distribution network

The operation of customer owned resources

A ncillary service markets (like balancing and regulation powermarket today)

A ncillary service contract between DNO and service provider

Connection requirements

Ancillary services

Reactive power support Voltage control

Power quality control

Power flow management

Occasional production curtailment (non-firm connection)

Load shedding




Goals of Active Network Management ± ANM

Ensure safe network operation in networks with DG

Increase network reliability in networks with DG Maximize the use of the existing networks with bottlenecks

caused by voltage issues

Maintain the required level of power quality despite non-predictable power production or consumption




Characteristics of ANM

Voltage control

The control of DG unit voltage instead of unity power factorrequirement will help in weak networks

The co-ordination of voltage controllers will f urther improve thesit uation which requires some additional measurements forstate estimation purposes

Green arrows = Active power flowBlue arrows = Reactive power flow




Benefits of co-ordination

0

500

1000

1500

2000

2500

3000

364 473 572 690 825 992 1174

Loading of Kasnäs feeder [kW]

N e t w o r k

t r a n s f e r c a p a b i l i t y [ k W ]

Unity power factor, Flexible

Local voltage control, Flexible

Co-ordinated control, Flexible

Unity power factor, Fixed

Local voltage control, Fixed

Co-ordinated control, Fixed





Power flow management

Normally network customers have firm network capacityavailable

Non-firm network capacity >> firm capacity

The amount of DG to be connected and operated under normalnetwork conditions will be increased

Prod

uction c

urtailment or constraints in e

xtreme conditions

The probability of extreme conditions should be low enough

To increase the firm network capacity by DG

A ctive resources should be controlled almost in real-time to reduceoverload of network when for example a DG unit disconnectssuddenly

Short-term capacity >> long-term capacity of equipments




The idea of non-firm network capacity




Example of power flow management

FG = Firm capacity Only another transformer in use, (n-1)

criteria Minimum loading condition

12 + 2 = 14 MW

NFG = Non-Firm capacity Unlimited operation during normal situation

Controlled operation during disturbances Minimum loading condition

12 + 12 + 2 ± 14 = 12 MW

RNFG = Regulated Non-Firm capacity If the production of FG or NFG isintermittent, then there exists free transfercapacity

Normal situation Maximum loading condition

Controlled operation also during normalsituations

12 + 12 +12 ± 14 ± 12 = 10 MW





Protection

Sensitivity Blinding problem

Distance protection and communication based protection

Selectivity

The co-ordination of feeder protection relays

The co-ordination of network and DG unit protection Directional over-current protection, distance protection and

communication based protection

Reclosing

The operating sequence of protection devices during a fault isimportant

Synchronous operation checking may be required




ADINE concept




U.S. Smart Grid Market Forecast: 2010-2015

Source: GTM research

Distribution Automation (DA) will grow from $2.2 billion in 2010 to $5.6 billion in 2015.




Hierarchy of Active Network Management

1. Protection2. Automatic control

(decentralized)3. A rea control

(centralized)




Protection system

The protection of distribution system should be developed to resolveselectivity and sensitivity problems caused by the connection of DG

N

ew feeder protection schemes like Directional over-current

Distance protection

Differential protection

Communication based protection

In order to avoid unnecessary disconnections of DG units there should

be proper coordination of network and DG unit protection. DG unit protection

It should be slow enough to f ulfill the FRT capability requirement, and it should be fast enough to disconnect DG units on faulty feeder.

The communication based protection scheme may be applied to speed upthe disconnection of DG unit during a fault at feeder.




Fault-ride-through capability

Network protection schemes should be such which dont

require immediate disconnection of

DG units in every fa

ult sit uation

DG units should also withstand much greater variations involtage and frequency without tripping

benefit the balancing and stability of power system

would make possible to utilise island operation at distributionnetwork

When a DG unit has FRT capability

The settings of DG unit protection (LOM) must be loosen in orderto withstand voltage and frequency dips

This creates a safety risk if traditional network protection schemes

are applied




Fault-ride-through capability




Automatic control (decentralized)

Voltage control

Network voltage is mainly controlled by the A VC relay of on-line

tap changer of H V/M V transformer A VR of DG and ST A TCOM

Voltage droop to allow parallel operation of units in voltage control(blue)

Voltage constrained reactive power control (red), cascade control of

voltage and power factor

+100%

(Q

-100%

vnomvmin vmax

Voltage control is the most effective inweak distribution networks

Distributed reactive power compensation

A VR of on-line tap changer of M V/M V transformer separate control zone forthe problematic area




Automatic control (decentralized)

Power quality control

LV connected DG units

Reactive power control of microt urbine may be utilized to improvevoltage quality

Decoupling of public distribution network and sensitive loads bydecoupling inductance and reactive power control behind it

ST A TCOM is utilized to

Ensure grid code compliance

Provide ancillary services for a DNO

Power quality priority list (some examples)

The highest priority for the flicker elimination, (if flicker is not severe) the capacity may be utilized for harmonic filtering

Fault-ride-through capability quite seldom needed, but when it isneeded this must have the highest priority in the list (adaptability)




Area control (centralized)Protection setting co-ordination

Protection planning software is utilized to plan settings for feeder andDG unit protection relays

Checking of suitability of settings before network topology changes

and exceptional feed sit uations New settings are put in operation via Relay setting tool

Co-ordinated voltage control

Best possible setting values for voltage (reactive power) controllers

SC ADA adjusts the new setting values for controllers

Direct connection to controller settings

Change of ST A TCOM priority list to put voltage control first

Network restoration

Fault location

Automatic fault isolation and network restoration




Control center IT system

Core IT for ANM

Network Information System Distribution Management System

SC ADA

A dvanced Metering Infrastruct ure

Information system requirements

1. High integration of information systems

2. Standard software interfaces

3. Common data model for information exchange

Plug-and-play software components




Integration of automation systems is needed

Substation automation

Real-time measurements Control commands

Parameter settings Disturbance recordings

Distribution automation

Same information as above Disconnectors, reclosers,

MV/LV transformer stations,

fault indicators, etc.

Customer automation (AMI)

Energy measurement Outage information Voltage quality

L

oad control




Telecommunication

A ny communication medium

Many protocols for substation level communication

Communication to small-scale DG

Not always needed

Automatic Metering Infrastruct ure

IEC 61850-7-420 Basic communication struct ure Distributed energyresources logical nodes"

This will develop anyway No need for special smart grid communication

How existing communication techniques should be applied




Existing standards

Control center

ELCOM-90 (IEC 60870-6 /T A SE.1)

ICCP (IEC 60870-6 /T A SE.2)

Common Information Model (IEC 61970-301 & IEC 61968-11) and relatedinterface definitions

MultiSpeak

Communication between control center and substation

IEC 6

087

0-

5

DNP3

Substation

IEC 61850

Industrial standards (Modbus, SPA , LON, )




Vision of future ICT system fordistribution network management

Service Oriented A rchitect ure (SOA )

Information system integration through Enterprise Service Bus (ESB)

Platform-independent Web technologies (e.g. X ML, Web Services, )

Standard interfaces (e.g. IEC 61968)

Standard information model (e.g. CIM)




Vision of future automation system fordistribution network management

Important questions

What information is collected tocentralized systems?

What functions may be madedecentralized?

How to update information?

Practical issues

Standard interfaces Common protocols and messages Common information model

Platform-independent Webtechnologies Middlewares Service Oriented Architecture




Laboratory testing




R eal time testing in laboratory




Software in real-time simulations

SCADA

Relay

Relay Setting Tool

OPC server NIS DMS

AVR

Fault Reporting Tool

Matlab

RTDS

RS-CAD




Combined real-time simulationenvironment of RTDS/dSPACE

dSPACE is real-time simulator for control systems

(we use dSPACE to model power electronics and its control)




Simulation cases

1. Influence of DG on feeder protection

Feeder protection schemes: non-directional overcurrent, directionalovercurrent, distance protection and differential protection

Loss-Of-Mains protection: ROCOF and voltage /frequency protection

2. Co-ordination of feeder protection and DG unit protection

Automatic reclosure and LOM

Selective LOM protection based on communication

3. Protection impacts on Fault-Ride-Through of DG unit

Stability of DG unit in H V network faults

Operation of LOM protection when DG unit have FRT capability

4. Parallel operation of local voltage controllers Voltage control in LV network


5. ST A TCOM

Flicker mitigation

Voltage dip mitigation

Influence on LOM

E l f FRT i l ti




Example of FRT simulations

20 21 22 23 24 25 26-1000

-500

0

50 0

1000

Usync a

Usync b

Usync c

20 21 22 23 24 25 26-2000

-1000

0

1000

2000

iL2a

iL2b

iL2c

Fig. 8. a) Connection point voltage b) Grid current.

20 21 22 23 24 25 260

20 0

40 0

60 0

80 0

1000

1200

1400

Choppe r current A

dc-l ink vo ltage V

20 21 22 23 24 25 26-600

-400

-200

0

20 0

40 0

p ref

p

Fig. 9. a) dc-link voltage udc and chopper current during the fault. b) Instantaneous active power p and its reference value p*

20 21 22 23 24 25 26-600

-500

-400

-300

-200

-100

0

10 0

q ref

q

20 21 22 23 24 25 26-1000

-800

-600

-400

-200

0

20 0

40 0

i L1d ref

i L1d

Fig. 10. a) Reactive power q and its reference value q*. b) Active power component of the grid current iL1,d and its reference iL1,d*.

20 21 22 23 24 25 26-400

-200

0

20 0

40 0

60 0

80 0

i L1q ref

i L1q

20 21 22 23 24 25 26-700

-600

-500-400

-300

-200

-100

0

10 0

isq ref

is q

Fig. 11. a) q-component of the grid side converter current and its reference value. b) q-component of the stator current and its reference value.

20 21 22 23 24 25 26

-15000

-10000

-5000

0

Electric torque

20 21 22 23 24 25 26

35

40

45

50

Wr ref

W r

Fig. 12. a) Electrical torque of the generator. b) Rotational speed of the turbiner and its reference value r *.

Breakingchopper isactivated

Output

power reduction

Reactivepower

support

Reducingelectrical

torqueKineticenergy

increases

Pitchcontrol

activated




Non-detection zone of LOM

Operation limit Delay [s]

f < 47 Hz 0.2

f > 51 Hz 0.2

U < 90 % 10

U > 106 % 10

U << 50 % 0.1

U >> 110 % 0.05




Non-detection zone of LOM

This area was not tested

This area was not tested




Effect of load voltage dependency on LOM



ADINE is a project co-funded by the European CommissionFeeder protection auto reclosingand LOM




Selective LOM protection based on communication

XX

Incom ing feeder re lay A

G O O S E m e ssa ge

REF 615

RE D 6 1 5

RE D 6 1 5

BST message

Feeder re lay A1

Feeder re lay A2

RE F 6 1 5

Feeder re lay B1

X

C a b

l e o r O H L

CB _ B 1 X

C a b

l e o r O H L

CB _ B 1X

G

X

C a b

l e o r O H L

CB _ A 1

REF 615 or REF 543

DG re lay

Fault AFault B

Fault C

CB _ DG




Fault B without communication Communication between feederprotection and LOM

DG

trips

Fault

starts

Faulted

feeder trips

Fault

starts

Faulted

feeder trips





Substation voltage and reactivepower of DG are controlled

Basic control is used to keepthe network voltages betweenfeeder voltage limits

Restoring control is used to

normalize the voltages when thevoltage level of the wholenetwork has remained unusuallyhigh or low

restore the DGs power factor set point to 1.0 when the networkstate allows it

Control is based on DMS state

estimation

110/20 kV

G

Soininkosk i hydropower p lant

Feeder Vi rrat Feeder Ri tar i

C o o r d i n a t e dv o l ta g e c o n t r o l

AVCrelay

Tap changer mechanism

Substat ionHeinäaho

V ref

AVR

co sNset

open disconnector




RTDS testing of control algorithm in Matlab



ADINE is a project co-funded by the European CommissionCo-ordinated voltage controlDG reactive power primarily controlled

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 358

0.95

1

1.05

1. 1

[ p u ]

M ax im um voltage M inim um voltage G enerator voltage

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 3581

1.05

1. 1

[ p u ]

S ubs tat io n vo ltag e V oltage s et p oint of O LTC

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 358

0.98

0.99

1. 0

Power factor set point

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 358

-0.4

-0.2

0

0. 2

[ M V A r ]

R eac tive power s et point D G reac tive power

0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 358

0

1

2

Time [s ]

[ M W ]

DG real power

Voltage limits of

restoring control

Voltage limits of basic control

AVC relay

deadband

Basic control

decreases AVC set point

Network voltages are restored

to an acceptable level

Tap changer operates

Basic control decreases

power factor set point

Restoring control increases

power factor set point




Main results of laboratory simulations

Simulation environment

Successf ul integration of RTDS, dSPA CE and SC ADA

Models Network model, hydro power, diesel, directly connected wind t urbine and

DFIG wind t urbine (RTDS)

Microt urbine, Full power converter permanent magnet wind t urbine, DFIG wind t urbine, 3-level ST A TCOM and active filters (dSPA CE)

Devices available REF 615 feeder protection

REF 630 distance protection RED 615 differential protection

REF 543 ROCOF and voltage /frequency protection

Communication link based on GOOSE and BST messages

Relay setting tools C AP 505 and PCM600

MicroSC ADA Pro SYS 600 and MicroSC ADA Pro DMS 600

ST

A TC

OMcontrol

unit





Findings

Hardware in loop simulations Ex

tension of product development between prototype and field tests

Versatile tests compared to field tests

Utilisation of the capabilities of both simulators for interaction st udiesof power system and power electronics

Protection (results based on a case st udy) Protection problems of DG exists in real life but not as often as

expected Communication based protection schemes (differential and LOM) have

extremely good results

Non-detection zone of LOM is not ortogonal in distribution network

Automatic reclosure may be still utilized at feeder protection if LOM includes ROCOF and reclosure delay is increased to 500 ms





Findings

FRT Several options of wind t urbine converter controls have been st udied to find out

a good solution for FRT

Voltage control Microt urbine may control reactive power behind a decoupling inductance and

the parallel operation of controllers is possible

Co-ordinated voltage control algorithm controls the substation voltage and the reactive power of DG based on the state of

the whole network

keeps network voltage levels within control limits

OPC provides an easy to implement interface for a third party software

ST A TCOM

ST A TCOM provides a superior solution for V A r control, voltage regulation,flicker compensation, and fault-ride through improvement .

A lso grid current harmonic filtering is possible if sufficiently high switching

frequency can be

used.




Conclusions

A ctive network management is feasible today

Several active network solutions have been developed anddemonstrated

Existing equipment and automation systems are utilized in thesedemonstrations evolution instead of revolution

Further development needed

Utilization of existing information and communication technologies

New solutions and systems for combined management of electricitynetworks and markets

Hardware in loop simulations

Extension of product development between prototype and field tests

Versatile tests compared to field tests




Thank you!

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adine anm sweden

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