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
Significant Changes in the PDC

Restructuring of DMC Subcommittees
Distribution Technical
Standards Subcommittee
Distribution Planning
Subcommittee
Distribution Reliability and
Protection Subcommittee
Distribution Reliability and
Protection Subcommittee
Distribution Tariff and
Framework Subcommittee
Distribution Operations
Subcommittee
Distribution Metering and
Settlements Subcommittee
Rules Review Subcommittee
Compliance Subcommittee
Rules Revision 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
(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
Compliance
Subcommittee
Rules Review
Subcommittee
(a) Implementing rules and (a) Initiating proposals for
regulations pertaining
appropriate revisions to
to the compliance of
the Philippine
Distribution Utilities
Distribution Code;
with the Philippine
(b) Evaluating and making
Distribution Code;
recommendations on
(b) Evaluating and making
the proposed revisions
recommendations on
to the Philippine
the Distributor’s
Distribution Code; and
compliance monitoring (c) Evaluating and making
report with the
recommendations on
Philippine Distribution
any rules and
Code; and
regulations to be issued
(c) Conducting actual
by the ERC and/or other
assessment of
agencies.
Distributor’s compliance
with the Philippine
Distribution Code.
Distribution Operations 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.
Distribution Reliability and Protection
Subcommittee
(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.
Significant Changes in the PDC

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.
Significant Changes in the PDC

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;
Significant Changes in the PDC

Addition of Formulas and Sample Computation as
Appendices in the PDC 2016 Edition; and

Redrafting of Chapter 7: Distribution Revenue Metering
Requirements.
Significant Changes in the PDC

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
Type
Power Limits
Large
P
Comments
Conventional
Usually connected to HV networks
VRE
Consistency with the PGC
Usually Connected to MV or, eventually, to HV networks.
Medium
No distinction is made between conventional and VRE generators
Usually Connected to MV
Intermediate
+
Connected to MV
No distinction made between conventional and VRE generators.
Connected to LV (eventually in MV)
Small
P < 100
Partially covered (in the case of RES) by net metering regulations
No distinction made between conventional and VRE generators.
Connected inside LV customer premises.
Micro
P
Covered (in the case of RES) by net metering regulations
No distinction made between conventional and VRE generators
Frequency Withstand Capability for
Large GeneratorsFrequency Withstand Capability
Large Generators
Same requirements for Conventional and VRE Large Generators
Conventional
VRE
Frequency
Hz
P.u.
> 62.4
> 1.04
> 61.8 – 62.4 > 1.03 – 1.04
58.2 – 61.8
0.97 - .03
57.6 - < 58.2 0.96 - < 0.97
<57.6
< 0.96
Time
Automatic disconnection allowed, is so decided
by the VRE Operator
5 minutes
Continuous Operation
60 minutes
5 seconds
14
Frequency Withstand Capability for
Medium, Small and
Micro Withstand Capability
Frequency
Medium, Intermediate and Small Generators
Medium & Intermediate
Small & Micro
Frequency
Hz
> 62.4
Time
P.u.
> 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
< 0.96
5 seconds
Frequency
Hz
58.2 – 61.8
P.u.
Time
0.97 - .03 Continuous Operation
Reactive Power Capability
Reactive Power Capability and Control
and Control
Large
Medium
Intermediate
Small & Micro
1,2
1
Power Factor at the
Connection Point within the
range of 0.98 leading – 0.98
lagging
0,8
0,6
Conventional
VRE
0,4
Power factor
not less than
0.85 lagging
0,2
0
-0,6
-0,4
-0,2
Reactive
Power
0
0,2
0,4
0,6
0,8
Reactive power decided by the Distributor
Controlled by the Developer
Performance under Network
Performance under Network Disturbances
Disturbances
Large
Medium - Intermediate
Small - Micro
20
Protection Requirements
Protection Requirements
Large, Medium &
Intermediate
Small & Micro
• Agreed and Coordinated
with the DU
• Anti-islanding
requirements for Medium
and Intermediate
generators
23
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
Procedures for connection
for for connection
Intermediate / Size
Medium
Size Generators
Intermediate/Medium
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.
Procedures for connection
forfor connection
Procedures
Intermediate/Medium
Size Generators
Intermediate / Medium
Size Generators
Medium and small generators
Allowed
Not Allowed
Procedures for connection for Small
Procedures for connection
`Small and Micro Generators
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
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.
Large VRE Embedded Generating Plants

Frequency Withstand Capability
Large VRE Embedded Generating Plants

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.
Large VRE Embedded Generating Plants

Reactive Power Control
Large VRE Embedded Generating Plants

Performance During Disturbances
Medium Embedded Generating Plants

Frequency Withstand Capability
Intermediate Embedded Generating
Plants

Frequency Withstand Capability
Small and Micro
Embedded Generating Plants

Performance Under Disturbances
Protection Requirements
Large, Medium &
Intermediate
• Agreed and Coordinated
with the DU
• Anti-islanding
requirements for Medium
and Intermediate
generators
Small & Micro
Small and Micro
Embedded Generating Plants

Protection Arrangement
Small and Micro
Embedded Generating Plants

Protection Arrangement
Small and Micro
Embedded Generating Plants

Protection Arrangement
Small and Micro
Embedded Generating Plants

Protection Arrangement
Classification of Embedded Generators
Capacity
Large
Medium
Intermediate
Small
Micro
P>10MW*
1MW>P>
10MW
100kW>P>
1MW OR
P<100kW
10kW>P>
100kW
(LV network)
(MV network)
Connection
Point
(LV network)
P<10kW
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
Distribution Impact Studies
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.
(1)
Significant Changes in the PDC

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
To be agreed with the Distribution Utility
In accordance with PDC
4.9.5
Info
Interchange
RTU is
required
RTU required will be based
on the DIS conducted
Not required
Thank You!
For Not
Sleeping