PHILIPPINE DISTRIBUTION CODE 2017 EDITION - Electrical … · 2018-05-09 · PDC 2017- Background...
Transcript of PHILIPPINE DISTRIBUTION CODE 2017 EDITION - Electrical … · 2018-05-09 · PDC 2017- Background...
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 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.
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
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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.
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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
Procedures for connection for
Intermediate/Medium Size Generators
Procedures for connection
Intermediate / Medium Size Generators
Medium and small generators
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Allowed
Not Allowed
Procedures for connection for
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
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
23
Large, Medium & Intermediate
Small & Micro
• Agreed and Coordinated with the DU
• Anti-islanding requirements for Medium and Intermediate generators
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
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.
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
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