PHILIPPINE DISTRIBUTION CODE 2017 EDITION -...

PHILIPPINE DISTRIBUTION CODE

2017 EDITION

PDC 2017- Background

Revised the PDC 2001

Starts of revision in 2010

April 18 and 24, 2012 conducted a series

of expository presentation for Visayas and

Mindanao

For Luzon – May 29, 2012

For VRE – 2016

For approval by ERC

Significant Changes in the PDC

Additional Members to the DMC Board

One Representative from

the Largest Distribution

Utility

One Representative from

the Market Operator

(CRB)

2.2.2 Membership of the DMC 2.2.2.1 The DMC shall be composed of the following members who shall be

appointed by the ERC:

(a) Three members nominated by private and local government Distributors,

one each from Luzon, Visayas, and Mindanao;

(b) Three members nominated by the Electric Cooperatives, one each from

Luzon, Visayas, and Mindanao;

(c) One member nominated by the largest Distribution Utility;

(d) One member nominated by Embedded Generators;

(e) One member nominated by industrial Customers;

(f) One member nominated by commercial Customers;

(g) One member nominated by residential consumer groups;

(h) One member nominated by the Transmission Network Provider;

(i) One member nominated by the System Operator;

(j) One member nominated by the Market Operator; and

(k) One member nominated by a government-accredited professional

organization of electrical engineers. (IIEE)

Transmission Network Provider

Grid Owner –replaced by TNP

Transmission Network Provider. The party

that is responsible for maintaining adequate Grid

Capacity in accordance with the provisions of

the Philippine Grid Code.

Government Representatives

DOE

ERC

NEA

To provide guidance on government policy

and regulatory frameworks and directions

Cannot participate in any decision-making

in the formulation of recommendations to

the ERC


Restructuring of DMC Subcommittees

Distribution Technical

Standards Subcommittee

Distribution Reliability and

Protection Subcommittee

Distribution Tariff and

Framework Subcommittee

Distribution Metering and

Settlements Subcommittee

Rules Revision Subcommittee

Distribution Planning

Subcommittee

Distribution Reliability and

Protection Subcommittee

Distribution Operations

Subcommittee

Rules Review Subcommittee

Compliance Subcommittee

Subcommittees The Distribution Technical Standards Subcommittee will be

separated into two new subcommittees, the Distribution

Planning Subcommittee and the Distribution Operations

Subcommittee which will then cover the functions of the

Distribution Metering and Settlements Subcommittee.

The Distribution Reliability and Protection Subcommittee is

retained and will be given additional functions.

The Distribution Tariff Frameworks Subcommittee will be

dissolved and replaced by a new subcommittee, the

Compliance Subcommittee.

A permanent Rules Review Subcommittee is proposed.

Distribution Planning Subcommittee

Compliance Subcommittee

Rules Review Subcommittee

(a) Reviewing and revising the Distribution System planning procedures and standards;

(b) Evaluating and making recommendations on the Distribution Development Plan (DDP); and

(c) Evaluating and recommending actions on the proposed major Distribution System reinforcement and expansion projects

(a) Implementing rules and regulations pertaining to the compliance of Distribution Utilities with the Philippine Distribution Code;

(b) Evaluating and making recommendations on the Distributor’s compliance monitoring report with the Philippine Distribution Code; and

(c) Conducting actual assessment of Distributor’s compliance with the Philippine Distribution Code.

(a) Initiating proposals for appropriate revisions to the Philippine Distribution Code;

(b) Evaluating and making recommendations on the proposed revisions to the Philippine Distribution Code; and

(c) Evaluating and making recommendations on any rules and regulations to be issued by the ERC and/or other agencies.

Distribution Operations Subcommittee Distribution Reliability and Protection

Subcommittee

(a) Reviewing and revising the Distribution System operation technical standards, such as: (1) Equipment standards; (2) Standard operating procedures; (3) Performance standards; and (4) Metering standards.

(b) Reviewing and revising the Distribution System operating procedures, such as: (1) Joint purchases of common Equipment; (2) Sharing of parts inventories; (3) Mutual assistance; and (4) Emergency response.

(c) Evaluating and making recommendations on Distribution System operation reports;

(d) Evaluating and making recommendations on Significant Incidents; and

(e) Monitoring the implementation of the Philippines Small Grid Guidelines.

(a) Reviewing and revising Distribution System reliability and protection procedures and standards;

(b) Evaluating and making recommendations on Distribution reliability reports;

(c) Evaluating and making recommendations on significant Distribution System events or incidents caused by the failure of protection;

(d) Reviewing and recommending reliability performance standards; and

(e) Managing reliability data.


Addition of Derogatory Provisions in Chapter 1: Philippine

Distribution Code General Conditions;

Inclusion of “Customer Average Interruption Duration

Index” or CAIDI in the Distribution Reliability Indices

imposed upon all Distribution Utilities;

Exclusion of Major Events in the calculation of

Reliability Indices;

Chapter 4: Financial and Capability Standards for

Distribution Supply is transferred as an Appendix to the

PDC;

3.3.2 Distribution Reliability Indices

3.3.2 Distribution Reliability Indices

3.3.2.1 The following distribution Reliability indices shall be imposed on all

Distribution Utilities:

(a) System Average Interruption Frequency Index (SAIFI);

(b) System Average Interruption Duration Index (SAIDI);

(c) Customer Average Interruption Duration Index (CAIDI); and

(d) Momentary Average Interruption Frequency Index (MAIFI).

3.3.2.2 The System Average Interruption Frequency Index indicates how often the

average customer experiences a Sustained Interruption over a predefined period of

time.

3.3.2.3 The System Average Interruption Duration Index indicates the total duration

of interruption for the average customer during a predefined period of time. It is

commonly measured in customer minutes or customer hours of interruption.

3.3.2.4 The Customer Average Interruption Duration Index represents the

average time required to restore service.

3.3.2.5 The Momentary Average Interruption Frequency Index indicates the

average frequency of Momentary Interruptions.


Deletion of the section on “Distribution Code Dispute

Resolution”, and inclusion of a new section entitled

“Application and Interpretation of Distribution Code

Provisions”;

References to “Grid Owner” has been replaced with

“Transmission Network Provider”; and

Inclusion of Section 33 of the Republic Act 7920 known

as the “New Electrical Engineering Law” as an additional

compliance in the PDC 2017 Edition;


Addition of Formulas and Sample Computation as

Appendices in the PDC 2016 Edition; and

Redrafting of Chapter 7: Distribution Revenue Metering

Requirements.


Inclusion of VRE Embedded Generators

In addition to the existing requirements for conventional

embedded generators, connection and operational

requirements for variable renewable energy embedded

generators.

Embedded Generating Plants

Categories Embedded Generators categories

10

Type Power Limits Comments

Large P

Conventional Usually connected to HV networks

VRE Consistency with the PGC

Medium Usually Connected to MV or, eventually, to HV networks.

No distinction is made between conventional and VRE generators

Intermediate

+

Connected to MV

Usually Connected to MV

No distinction made between conventional and VRE generators.

Small P < 100

Connected to LV (eventually in MV)

Partially covered (in the case of RES) by net metering regulations

No distinction made between conventional and VRE generators.

Micro P

Connected inside LV customer premises.

Covered (in the case of RES) by net metering regulations

No distinction made between conventional and VRE generators

Frequency Withstand Capability for

Large Generators Frequency Withstand Capability Large Generators

14

Conventional VRE

FrequencyTime

Hz P.u.

> 62.4 > 1.04Automatic disconnection allowed, is so decidedby the VRE Operator

> 61.8 – 62.4 > 1.03 – 1.045 minutes

58.2 – 61.8 0.97 - .03Continuous Operation

57.6 - < 58.2 0.96 - < 0.9760 minutes

<57.6 < 0.965 seconds

Same requirements for Conventional and VRE Large Generators

Frequency Withstand Capability Medium, Intermediate and Small Generators

15

Medium & Intermediate Small & Micro

FrequencyTimeHz P.u.

> 62.4 > 1.04 Automatic disconnection

> 61.8 – 62.4 > 1.03 – 1.04 5 minutes

58.2 – 61.8 0.97 - .03 Continuous Operation

57.6 - < 58.2 0.96 - < 0.97 5 minutes

<57.6 < 0.965 seconds

FrequencyTimeHz P.u.

58.2 – 61.8 0.97 - .03 Continuous Operation

Frequency Withstand Capability for

Medium, Small and Micro

Reactive Power Capability

and Control Reactive Power Capability and Control

16

Large Medium Intermediate Small & Micro

Power Factor at the Connection Point within the range of 0.98 leading – 0.98

lagging

Power factor not less than 0.85 lagging

Reactive power decided by the Distributor Controlled by the Developer

0

0,2

0,4

0,6

0,8

1

1,2

-0,6 -0,4 -0,2 0 0,2 0,4 0,6 0,8Reactive Power

Conventional

VRE

Performance under Network

Disturbances Performance under Network Disturbances

20

Large Medium - Intermediate Small - Micro

Protection Requirements Protection Requirements

23

Large, Medium & Intermediate

Small & Micro

• Agreed and Coordinated with the DU

• Anti-islanding requirements for Medium and Intermediate generators

Procedures for connection for

Large Generators Procedures for connection

Large Generators

In case of Large Generators

• The User shall inform the Transmission Network Provider, about the application for connection.

• The Transmission Network Provider will evaluate the application and it will decide if:

It can be accepted;

It can be accepted subject to certain conditions or special requirements; or

It can’t be accepted, clearly indicating in this case the reasons for the rejection.

• The results shall be formally informed to the User

• The TNP may include in its recommendation any Grid or system potential restriction or network congestion, which may significantly influence the dispatch of the Large Embedded Generating Plant.

26

Procedures for connection

Intermediate / Medium Size Generators

• Total installed capacity of the Embedded Generating Plant + all other existing capacity, shall not exceed 30% of the thermal capacity of the MV feeder.

Total installed capacity connected to the substation shall not exceed the Minimum Load in a year of the HV/MV transformer. In case there are no registers it will be estimated as 25% of the transformer thermal capacity.

The maximum Voltage changes at the Connection Point due to the switching operation shall not exceed 2% of the nominal voltage.

• a MV substation Total installed capacity connected to the substation shall not exceed the Minimum Load in a year of the HV/MV transformer at the substation. In case there are no registers of such minimum load, the value will be estimated as 25% of the transformer thermal capacity.

27


Intermediate/Medium Size Generators

Procedures for connection

Intermediate / Medium Size Generators

Medium and small generators

29

Allowed

Not Allowed


Intermediate/Medium Size Generators

` Procedures for connection

Small and Micro Generators

• Small - Connected to LV feeders or at the MV/LV Transformer The total installed capacity plus the aggregated capacity of all other Plants connected to the feeder shall not exceed 30% of the thermal capacity of the LV feeder.

The total installed capacity at the busbar of the MV/LV substation shall not exceed one third of the thermal capacity of the MV/LV transformer.

The maximum Voltage changes at the Connection Point due to the switching operation of the Medium or Intermediate Embedded Generating Plant shall not exceed 2% of the nominal voltage.

• Micro The equipment has to be Type Tested to assure it is safe and to cause no unwanted disturbance to the distribution system.

The Project Proponent shall submit to the Distribution Utility the Type Tests Report.

30

Procedures for connection for Small

and Micro Generators

Procedures for connection Distribution Impact Studies

• Evaluate the impact of the proposed connection on the Distribution System:

• Power flows, both in Normal State and in case of contingencies;

• Voltage control studies;

• Impact of short circuit infeed;

• Definition and coordination of protection System;

• Impact on Power Quality.

25

Large VRE Embedded Generating Plants

Frequency Withstand Capability


Reactive Power Capability

The Large VRE Embedded Generating Plant shall be capable of

supplying Reactive Power output, at its Connection Point, within

the following ranges:

• (a) ±20% of its Embedded Generating Plant Capacity as specified in the

Generation Company’s Declared Data, if its Active Power Output depending

on the availability of the primary resource, is equal to or above 58% of the

Embedded Generating Plant Installed Capacity;

• (b) Any Reactive Power value within the limits of 95% Power Factor lagging

to 95% Power Factor leading, if its Active Power Output depending on the

availability of the primary resource, is within the 10% and 58% of the

Embedded Generating Plant Installed Capacity;

• (c) No Reactive Power interchange if the Active Power Output depending on

the availability of the primary resource, is equal to or less than 10% of the

Embedded Generating Plant Installed Capacity.


Reactive Power Control


Performance During Disturbances

Medium Embedded Generating Plants


Intermediate Embedded Generating

Plants


Small and Micro


Performance Under Disturbances

Protection Requirements

23

Large, Medium & Intermediate

Small & Micro

• Agreed and Coordinated with the DU

• Anti-islanding requirements for Medium and Intermediate generators

Small and Micro


Protection Arrangement

Large Medium Intermediate Small Micro

Capacity P>10MW* 1MW>P>

10MW

100kW>P>

1MW OR

P<100kW (MV network)

10kW>P>

100kW (LV network)

P<10kW (LV network)

Connection

Point

Connected to a Voltage Level agreed between the Embedded GenCo and

the DU based on the DIS, and controlled by a CB

Frequency

Withstand 57.6 - 62.4 Hz 58.2 – 61.8 Hz

Protection To be agreed with the Distribution Utility In accordance with PDC

4.9.5

Information

Interchange

RTU is

required

RTU required will be based

on the DIS conducted Not required

Classification of Embedded Generators

Distribution Impact Studies

(1) Power flows, both in Normal State and in case of

contingencies;

(2) Voltage control studies;

(3) Impact of short circuit infeed to the Distribution

Equipment are not exceeded;

(4) Definition and coordination of protection System; and

(5) Impact of User Development on Power Quality.


Classification of Embedded Generators

Capacity

P>10MW*

1MW>P>

10MW

100kW>P>

1MW OR

P<100kW (MV network)

10kW>P>

100kW (LV network)

P<10kW (LV network)

Freq.

Withstand 57.6 - 62.4 Hz 58.2 – 61.8 Hz

Protection

Info

Interchange

To be agreed with the Distribution Utility In accordance with PDC

4.9.5

RTU is

required

RTU required will be based

on the DIS conducted Not required

Thank You!

For Not

Sleeping

PHILIPPINE DISTRIBUTION CODE 2017 EDITION -...

Documents

Transcript of PHILIPPINE DISTRIBUTION CODE 2017 EDITION -...